UNITED STATES SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-Q

x	 	Quarterly report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934	
 	 	 	
 	 	For the Quarterly Period Ended: March 31, 2012	
 	 	 	
o	 	Transition report pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934	
Commission File Number: 001-15891
NRG Energy, Inc.
(Exact name of registrant as specified in its charter)

Delaware
(State or other jurisdiction
of incorporation or organization)	 	41-1724239
(I.R.S. Employer
Identification No.)	
 	 	 	
211 Carnegie Center, Princeton, New Jersey
(Address of principal executive offices)	 	08540
(Zip Code)	
(609) 524-4500
(Registrant’s telephone number, including area code)
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.
Yesx       Noo
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
Yesx       Noo
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer x	 	Accelerated filer o	 	Non-accelerated filer o	 	Smaller reporting company o	
 	 	 	 	(Do not check if a smaller reporting company)	 	 	
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).
Yeso       Nox
As of April 30, 2012, there were 227,719,443 shares of common stock outstanding, par value $0.01 per share.

 	

TABLE OF CONTENTS
Index

CAUTIONARY STATEMENT REGARDING FORWARD LOOKING INFORMATION	3	
GLOSSARY OF TERMS	4	
PART I — FINANCIAL INFORMATION	7	
ITEM 1 — CONDENSED CONSOLIDATED FINANCIAL STATEMENTS AND NOTES	7	
ITEM 2 — MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS	44	
ITEM 3 — QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK	68	
ITEM 4 — CONTROLS AND PROCEDURES	70	
PART II — OTHER INFORMATION	71	
ITEM 1 — LEGAL PROCEEDINGS	71	
ITEM 1A — RISK FACTORS	71	
ITEM 2 — UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS	71	
ITEM 3 — DEFAULTS UPON SENIOR SECURITIES	71	
ITEM 4 — MINE SAFETY DISCLOSURES	71	
ITEM 5 — OTHER INFORMATION	71	
ITEM 6 — EXHIBITS	72	
SIGNATURES	73	

2

CAUTIONARY STATEMENT REGARDING FORWARD LOOKING INFORMATION
This Quarterly Report on Form 10-Q includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933, as amended, or Securities Act, and Section 21E of the Exchange Act. The words "believes", "projects", "anticipates", "plans", "expects", "intends", "estimates" and similar expressions are intended to identify forward-looking statements. These forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause NRG Energy, Inc.'s actual results, performance and achievements, or industry results, to be materially different from any future results, performance or achievements expressed or implied by such forward-looking statements. These factors, risks and uncertainties include the factors described under Item 1A —  Risk Factors Related to NRG Energy, Inc. , in Part I, Item 1A of the Company's Annual Report on Form 10-K for the year ended December 31, 2011, including the following:
 	 	
•	General economic conditions, changes in the wholesale power markets and fluctuations in the cost of fuel;	
 	 	
•	Volatile power supply costs and demand for power;	
 	 	
•	Hazards customary to the power production industry and power generation operations such as fuel and electricity price volatility, unusual weather conditions, catastrophic weather-related or other damage to facilities, unscheduled generation outages, maintenance or repairs, unanticipated changes to fuel supply costs or availability due to higher demand, shortages, transportation problems or other developments, environmental incidents, or electric transmission or gas pipeline system constraints and the possibility that NRG may not have adequate insurance to cover losses as a result of such hazards;	
 	 	
•	The effectiveness of NRG's risk management policies and procedures, and the ability of NRG's counterparties to satisfy their financial commitments;	
 	 	
•	Counterparties' collateral demands and other factors affecting NRG's liquidity position and financial condition;	
 	 	
•	NRG's ability to operate its businesses efficiently, manage capital expenditures and costs tightly, and generate earnings and cash flows from its asset-based businesses in relation to its debt and other obligations;	
 	 	
•	NRG's ability to enter into contracts to sell power and procure fuel on acceptable terms and prices;	
 	 	
•	The liquidity and competitiveness of wholesale markets for energy commodities;	
 	 	
•	Government regulation, including compliance with regulatory requirements and changes in market rules, rates, tariffs and environmental laws and increased regulation of carbon dioxide and other greenhouse gas emissions;	
 	 	
•	Price mitigation strategies and other market structures employed by ISOs or RTOs that result in a failure to adequately compensate NRG's generation units for all of its costs;	
 	 	
•	NRG's ability to borrow additional funds and access capital markets, as well as NRG's substantial indebtedness and the possibility that NRG may incur additional indebtedness going forward;	
 	 	
•	NRG's ability to receive Federal loan guarantees or cash grants to support development projects;	
 	 	
•	Operating and financial restrictions placed on NRG and its subsidiaries that are contained in the indentures governing NRG's outstanding notes, in NRG's Senior Credit Facility, and in debt and other agreements of certain of NRG subsidiaries and project affiliates generally;	
 	 	
•	NRG's ability to implement its strategy of developing and building new power generation facilities, including new solar projects;	
 	 	
•	NRG's ability to implement its econrg strategy of finding ways to meet the challenges of climate change, clean air and protecting natural resources while taking advantage of business opportunities;	
 	 	
•	NRG's ability to implement its FORNRG strategy of increasing the return on invested capital through operational performance improvements and a range of initiatives at plants and corporate offices to reduce costs or generate revenues;	
 	 	
•	NRG's ability to achieve its strategy of regularly returning capital to stockholders;	
 	 	
•	NRG's ability to maintain retail market share;	
 	 	
•	NRG's ability to successfully evaluate investments in new business and growth initiatives;	
 	 	
•	NRG's ability to successfully integrate and manage any acquired businesses; and	
 	 	
•	NRG's ability to develop and maintain successful partnering relationships.	

Forward-looking statements speak only as of the date they were made, and NRG Energy, Inc. undertakes no obligation to publicly update or revise any forward-looking statements, whether as a result of new information, future events or otherwise. The foregoing review of factors that could cause NRG's actual results to differ materially from those contemplated in any forward-looking statements included in this Quarterly Report on Form 10-Q should not be construed as exhaustive.

3

GLOSSARY OF TERMS
When the following terms and abbreviations appear in the text of this report, they have the meanings indicated below:

2011 Form 10-K	 	NRG’s Annual Report on Form 10-K for the year ended December 31, 2011	
 	 	 	
2011 Revolving Credit Facility	 	The Company's $2.3 billion revolving credit facility due 2016, a component of the 2011 Senior Credit Facility	
 	 	 	
2011 Senior Credit Facility	 	As of July 1, 2011, NRG's senior secured facility, comprised of a $1.6 billion term loan facility and a $2.3 billion revolving credit facility	
 	 	 	
2011 Term Loan Facility	 	The Company's $1.6 billion term loan facility due 2018, a component of the 2011 Senior Credit Facility	
 	 	 	
316(b) Rule	 	A section of the Clean Water Act regulating cooling water intake structures	
 	 	 	
Baseload capacity	 	Coal and nuclear electric power generation capacity normally expected to serve loads on an around-the-clock basis throughout the calendar year	
 	 	 	
CAA	 	Clean Air Act	
 	 	 	
CAIR	 	Clean Air Interstate Rule	
 	 	 	
CAISO	 	California Independent System Operator	
 	 	 	
Capital Allocation Plan	 	Share repurchase and shareholder dividend program	
 	 	 	
Capital Allocation Program	 	NRG's plan of allocating capital between debt reduction, reinvestment in the business, share   repurchases and shareholder dividends through the Capital   Allocation Plan

CDWR	 	California Department of Water Resources	
 	 	 	
C&I	 	Commercial, industrial and governmental/institutional	
 	 	 	
CFTC	 	U.S. Commodity Futures Trading Commission	
 	 	 	
CO2	 	Carbon dioxide	
 	 	 	
CSAPR	 	Cross-State Air Pollution Rule	
 	 	 	
Distributed Solar	 	Solar power projects, typically less than 20 MW in size (on an alternating current, or AC, basis), that primarily sell power produced to customers for usage on site, or are interconnected to sell power into the local distribution grid	
 	 	 	
DNREC	 	Delaware Department of Natural Resources and Environmental Control	
 	 	 	
Energy Plus	 	Energy Plus Holdings LLC	
 	 	 	
ERCOT	 	Electric Reliability Council of Texas, the Independent System Operator and the regional reliability coordinator of the various electricity systems within Texas	
 	 	 	
Exchange Act	 	The Securities Exchange Act of 1934, as amended	
 	 	 	
FERC	 	Federal Energy Regulatory Commission	
 	 	 	
FFB	 	Federal Financing Bank	
 	 	 	
GHG	 	Greenhouse Gases	
 	 	 	
Green Mountain Energy	 	Green Mountain Energy Company	

4

 	
 	 	 	
GWh	 	Gigawatt hour	
 	 	 	
Heat Rate	 	A measure of thermal efficiency computed by dividing the total BTU content of the fuel burned by the resulting kWhs generated. Heat rates can be expressed as either gross or net heat rates, depending whether the electricity output measured is gross or net generation and is generally expressed as BTU per net kWh	
 	 	 	
ISO	 	Independent System Operator, also referred to as Regional Transmission Organizations, or RTO	
 	 	 	
ISO-NE	 	ISO New England Inc.	
 	 	 	
LIBOR	 	London Inter-Bank Offered Rate	
 	 	 	
LTIP	 	Long-Term Incentive Plan	
 	 	 	
Mass	 	Residential and small business	
 	 	 	
MMBtu	 	Million British Thermal Units	
 	 	 	
MW	 	Megawatts	
 	 	 	
MWh	 	Saleable megawatt hours net of internal/parasitic load megawatt-hours	
 	 	 	
NAAQS	 	National Ambient Air Quality Standards	
 	 	 	
NERC	 	North American Electric Reliability Corporation	
 	 	 	
NINA	 	Nuclear Innovation North America LLC	
 	 	 	
NOx	 	Nitrogen oxide	
 	 	 	
NPNS	 	Normal Purchase Normal Sale	
 	 	 	
NRC	 	U.S. Nuclear Regulatory Commission	
 	 	 	
NYPSC	 	New York Public Service Commission	
 	 	 	
OCI	 	Other comprehensive income	
 	 	 	
PJM	 	PJM Interconnection, LLC	
 	 	 	
PJM market	 	The wholesale and retail electric market operated by PJM primarily in all or parts of Delaware, the District of Columbia, Illinois, Maryland, New Jersey, Ohio, Pennsylvania, Virginia and West Virginia	
 	 	 	
PM 2.5	 	Particulate matter particles with a diameter of 2.5 micrometers or less	
 	 	 	
PPA	 	Power Purchase Agreement	
 	 	 	
PUCT	 	Public Utility Commission of Texas	
 	 	 	
Repowering	 	Technologies utilized to replace, rebuild, or redevelop major portions of an existing electrical generating facility, not only to achieve a substantial emissions reduction, but also to increase facility capacity, and improve system efficiency	
 	 	 	
SEC	 	United States Securities and Exchange Commission	
 	 	 	
Securities Act	 	The Securities Act of 1933, as amended	
 	 	 	
Senior Notes	 	The Company’s $6.1 billion outstanding unsecured senior notes, consisting of $1.1 billion of 7.375% senior notes due 2017, $1.2 billion of 7.625% senior notes due 2018, $700 million of 8.5% senior notes due 2019, $800 million of 7.625% senior notes due 2019, $1.1 billion of 8.25% senior notes due 2020 and $1.2 billion of 7.875% senior notes due 2021	

5

 	

SO2	 	Sulfur dioxide	
 	 	 	
STP	 	South Texas Project — nuclear generating facility located near Bay City, Texas in which NRG owns a 44% interest	
 	 	 	
Term Loan Facility	 	Prior to July 1, 2011, a senior first priority secured term loan, of which approximately $608 million would have matured on February 1, 2013, and $990 million would have matured on August 31, 2015, and was a component of NRG’s Senior Credit Facility. On July 1, 2011, NRG replaced its Senior Credit Facility, including the Term Loan Facility, with the 2011 Senior Credit Facility.	
 	 	 	
U.S.	 	United States of America	
 	 	 	
U.S. DOE	 	United States Department of Energy	
 	 	 	
U.S. EPA	 	United States Environmental Protection Agency	
 	 	 	
U.S. GAAP	 	Accounting principles generally accepted in the United States	
 	 	 	
Utility Scale Solar	 	Solar power projects, typically 20 MW or greater in size (on an alternating current, or AC, basis), that are interconnected into the transmission or distribution grid to sell power at a wholesale level	
 	 	 	
VaR	 	Value at Risk	
 	 	 	
VIE	 	Variable Interest Entity	

6

PART I — FINANCIAL INFORMATION
ITEM 1 — CONDENSED CONSOLIDATED FINANCIAL STATEMENTS AND NOTES

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS
(Unaudited)

 	 	 	 	 	 	 	 	
 	Three months ended March 31,	
(In millions, except for per share amounts)	2012	 	2011	
Operating Revenues	 	 	 	
Total operating revenues	$	1,862	
 	 	$	1,995	
 	
Operating Costs and Expenses	 	 	 	
Cost of operations	1,573	
 	 	1,324	
 	
Depreciation and amortization	230	
 	 	205	
 	
Selling, general and administrative	221	
 	 	143	
 	
Development costs	8	
 	 	9	
 	
Total operating costs and expenses	2,032	
 	 	1,681	
 	
Operating (Loss)/Income	(170	)	 	314	
 	
Other Income/(Expense)	 	 	 	
Equity in earnings/(losses) of unconsolidated affiliates	8	
 	 	(2	)	
Impairment charge on investment	(1	)	 	(481	)	
Other income, net	2	
 	 	5	
 	
Loss on debt extinguishment	—	
 	 	(28	)	
Interest expense	(165	)	 	(173	)	
Total other expense	(156	)	 	(679	)	
Loss Before Income Taxes	(326	)	 	(365	)	
Income tax benefit	(120	)	 	(105	)	
Net Loss	(206	)	 	(260	)	
Less: Net income attributable to noncontrolling interest	1	
 	 	—	
 	
Net Loss Attributable to NRG Energy, Inc.	(207	)	 	(260	)	
Dividends for preferred shares	2	
 	 	2	
 	
Loss Available for Common Stockholders	$	(209	)	 	$	(262	)	
Loss Per Share Attributable to NRG Energy, Inc. Common Stockholders	 	 	 	
Weighted average number of common shares outstanding — basic and diluted	228	
 	 	247	
 	
Net loss per weighted average common share — basic and diluted	$	(0.92	)	 	$	(1.06	)	

See accompanying notes to condensed consolidated financial statements.

7

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS
(Unaudited)

 	
 	 	 	 	 	 	 	 	
 	Three months ended March 31,	
 	2012	 	2011	
 	(In millions)	
Net Loss	$	(206	)	 	$	(260	)	
Other comprehensive income/(loss), net of tax	 	 	 	
Unrealized loss on derivatives, net of income tax benefit of $5 and $48	(9	)	 	(82	)	
Foreign currency translation adjustments, net of income tax expense of $3 and $6	6	
 	 	12	
 	
Defined benefit plans	—	
 	 	1	
 	
Other comprehensive loss	(3	)	 	(69	)	
Comprehensive loss	(209	)	 	(329	)	
Less: Comprehensive income attributable to noncontrolling interest	1	
 	 	—	
 	
Comprehensive loss attributable to NRG Energy, Inc.	(210	)	 	(329	)	
Dividends for preferred shares	2	
 	 	2	
 	
Comprehensive loss available for common stockholders	$	(212	)	 	$	(331	)	

See accompanying notes to condensed consolidated financial statements.

8

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED BALANCE SHEETS

 	March 31, 2012	 	December 31, 2011	
(In millions, except shares)	(unaudited)	 	 	
ASSETS	 	 	 	
Current Assets	 	 	 	
Cash and cash equivalents	$	1,014	
 	 	$	1,105	
 	
Funds deposited by counterparties	199	
 	 	258	
 	
Restricted cash	217	
 	 	292	
 	
Accounts receivable — trade, less allowance for doubtful accounts of $19 and $23	716	
 	 	834	
 	
Inventory	392	
 	 	308	
 	
Derivative instruments	5,150	
 	 	4,216	
 	
Cash collateral paid in support of energy risk management activities	498	
 	 	311	
 	
Prepayments and other current assets	272	
 	 	273	
 	
Total current assets	8,458	
 	 	7,597	
 	
Property, plant and equipment, net of accumulated depreciation of $4,768 and $4,570	14,376	
 	 	13,621	
 	
Other Assets	 	 	 	
Equity investments in affiliates	643	
 	 	640	
 	
Note receivable — affiliate and capital leases, less current portion	370	
 	 	342	
 	
Goodwill	1,886	
 	 	1,886	
 	
 Intangible assets, net of accumulated amortization of $1,476 and $1,452	1,340	
 	 	1,419	
 	
Nuclear decommissioning trust fund	456	
 	 	424	
 	
Derivative instruments	649	
 	 	450	
 	
Other non-current assets	352	
 	 	336	
 	
Total other assets	5,696	
 	 	5,497	
 	
Total Assets	$	28,530	
 	 	$	26,715	
 	
LIABILITIES AND STOCKHOLDERS’ EQUITY	 	 	 	
Current Liabilities	 	 	 	
Current portion of long-term debt and capital leases	$	71	
 	 	$	87	
 	
Accounts payable	1,080	
 	 	808	
 	
Derivative instruments	4,824	
 	 	3,751	
 	
Deferred income taxes	92	
 	 	127	
 	
Cash collateral received in support of energy risk management activities	199	
 	 	258	
 	
Accrued expenses and other current liabilities	619	
 	 	640	
 	
Total current liabilities	6,885	
 	 	5,671	
 	
Other Liabilities	 	 	 	
Long-term debt and capital leases	10,150	
 	 	9,745	
 	
Nuclear decommissioning reserve	340	
 	 	335	
 	
Nuclear decommissioning trust liability	279	
 	 	254	
 	
Deferred income taxes	1,300	
 	 	1,389	
 	
Derivative instruments	708	
 	 	464	
 	
Out-of-market commodity contracts	176	
 	 	183	
 	
Other non-current liabilities	810	
 	 	756	
 	
Total non-current liabilities	13,763	
 	 	13,126	
 	
Total Liabilities	20,648	
 	 	18,797	
 	
3.625% convertible perpetual preferred stock (at liquidation value, net of issuance costs)	249	
 	 	249	
 	
Commitments and Contingencies	

 	
 	
Stockholders’ Equity	 	 	 	
Common stock	3	
 	 	3	
 	
Additional paid-in capital	5,374	
 	 	5,346	
 	
Retained earnings	3,777	
 	 	3,987	
 	
Less treasury stock, at cost — 76,587,776 and 76,664,199 shares, respectively	(1,922	)	 	(1,924	)	
Accumulated other comprehensive income	71	
 	 	74	
 	
Noncontrolling interest	330	
 	 	183	
 	
Total Stockholders’ Equity	7,633	
 	 	7,669	
 	
Total Liabilities and Stockholders’ Equity	$	28,530	
 	 	$	26,715	

See accompanying notes to condensed consolidated financial statements.

9

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(Unaudited)

 	Three months ended March 31,	
 	2012	 	2011	
 	(In millions)	
Cash Flows from Operating Activities	 	 	 	
Net loss	$	(206	)	 	$	(260	)	
Adjustments to reconcile net loss to net cash (used)/provided by operating activities:	 	 	 	
Distributions and equity in earnings of unconsolidated affiliates	—	
 	 	9	
 	
Depreciation and amortization	230	
 	 	205	
 	
Provision for bad debts	7	
 	 	8	
 	
Amortization of nuclear fuel	6	
 	 	11	
 	
Amortization of financing costs and debt discount/premiums	8	
 	 	8	
 	
Amortization of intangibles and out-of-market commodity contracts	42	
 	 	48	
 	
Changes in deferred income taxes and liability for uncertain tax benefits	(129	)	 	(109	)	
Changes in nuclear decommissioning trust liability	8	
 	 	10	
 	
Changes in derivative instruments	187	
 	 	(130	)	
Changes in collateral deposits supporting energy risk management activities	(187	)	 	176	
 	
Impairment charge on investment	—	
 	 	481	
 	
Cash used by changes in other working capital	(42	)	 	(241	)	
Net Cash (Used)/Provided by Operating Activities	(76	)	 	216	
 	
Cash Flows from Investing Activities	 	 	 	
Capital expenditures	(639	)	 	(219	)	
Increase in restricted cash, net	(20	)	 	(5	)	
Decrease in restricted cash to support equity requirements for U.S. DOE funded projects	95	
 	 	—	
 	
(Increase)/decrease in notes receivable	(7	)	 	12	
 	
Investments in nuclear decommissioning trust fund securities	(126	)	 	(105	)	
Proceeds from sales of nuclear decommissioning trust fund securities	119	
 	 	95	
 	
Proceeds from renewable energy grants	28	
 	 	—	
 	
Other	7	
 	 	(6	)	
Net Cash Used by Investing Activities	(543	)	 	(228	)	
Cash Flows from Financing Activities	 	 	 	
Payment of dividends to preferred stockholders	(2	)	 	(2	)	
Payment for treasury stock	—	
 	 	(130	)	
Net payments for settlement of acquired derivatives that include financing elements	(20	)	 	(17	)	
Sale proceeds and other contributions from noncontrolling interests in subsidiaries	178	
 	 	—	
 	
Proceeds from issuance of long-term debt	415	
 	 	1,286	
 	
Payment of debt issuance and hedging costs	(10	)	 	(8	)	
Payments for short and long-term debt	(34	)	 	(1,361	)	
Net Cash Provided/(Used) by Financing Activities	527	
 	 	(232	)	
Effect of exchange rate changes on cash and cash equivalents	1	
 	 	4	
 	
Net Decrease in Cash and Cash Equivalents	(91	)	 	(240	)	
Cash and Cash Equivalents at Beginning of Period	1,105	
 	 	2,951	
 	
Cash and Cash Equivalents at End of Period	$	1,014	
 	 	$	2,711	

See accompanying notes to condensed consolidated financial statements.

10

NRG ENERGY, INC. AND SUBSIDIARIES
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS
(Unaudited)

Note 1 — Basis of Presentation

NRG Energy, Inc., or NRG or the Company, is an integrated wholesale power generation and retail electricity company that aspires to be a leader in the way the industry and consumers think about, use, produce and deliver energy and energy services in major competitive power markets in the United States. First, NRG is a wholesale power generator engaged in the ownership and operation of power generation facilities; the trading of energy, capacity and related products; and the transacting in and trading of fuel and transportation services. Second, NRG is a retail electricity company engaged in the supply of electricity, energy services, and cleaner energy products to retail electricity customers in deregulated markets through its Retail businesses, which include Reliant Energy, Green Mountain Energy and Energy Plus. Finally, NRG is focused on the deployment and commercialization of potential disruptive technologies, like electric vehicles, Distributed Solar and smart meter technology, which have the potential to change the nature of the power supply industry.

The accompanying unaudited interim condensed consolidated financial statements have been prepared in accordance with the Securities and Exchange Commission's, or 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 Company's financial statements in its Annual Report on Form 10-K for the year ended December 31, 2011, or 2011 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 March 31, 2012, and the results of operations, comprehensive loss and cash flows for the three months ended March 31, 2012, and 2011.

Use of Estimates

The preparation of consolidated financial statements in accordance with generally accepted accounting principles requires management to make estimates and assumptions. These estimates and assumptions impact the reported amount of assets and liabilities and disclosures of contingent assets and liabilities as of the date of the consolidated financial statements. They also impact the reported amount of net earnings during the reporting period. Actual results could be different from these estimates.

Note 2 — Summary of Significant Accounting Policies 

Other Cash Flow Information

NRG’s investing activities exclude capital expenditures of $327 million which were accrued and unpaid at March 31, 2012, primarily for solar projects under construction.

Tax Credits

NRG accounts for income taxes in accordance with Accounting Standards Codification, or ASC, 740, Income Taxes, or ASC 740, which requires that the Company use the asset and liability method of accounting for deferred income taxes and provide deferred income taxes for all significant temporary differences, as further described in Note 2,  Summary of Significant Accounting Policies , to the Company's 2011 Form 10-K. NRG reduces its current income tax expense in the consolidated statement of operations for any investment tax credits, or ITCs, that are not convertible into cash grants, as well as other tax credits, in the period the tax credit is generated. ITCs that are convertible into cash grants, as well as the deferred income tax benefit generated by the difference in the financial statement and tax bases of the related assets, are recorded as a reduction to the carrying value of the underlying property and subsequently amortized to earnings on a straight-line basis over the useful life of each underlying property.

11

Recent Accounting Developments

Effective January 1, 2012, the Company adopted the provisions of Accounting Standards Update, or ASU, No. 2011-05, Comprehensive Income (Topic 220) Presentation of Comprehensive Income , or ASU No. 2011-05, and began presenting the total of comprehensive income, the components of net income and the components of other comprehensive income in two separate but consecutive statements.  The provisions of ASU No. 2011-05 are required to be adopted retroactively.  As this guidance provides only presentation requirements, the adoption of this standard did not impact the Company's results of operations, cash flows or financial position.

Note 3 — Business Acquisitions and Dispositions 

2012 Disposition

Agua Caliente— On January 18, 2012, the Company completed the sale of a 49% interest in NRG Solar AC Holdings LLC, the indirect owner of the Agua Caliente project, to MidAmerican Energy Holdings Company, or MidAmerican. A majority of the $122 million of cash consideration received at closing represented 49% of construction costs funded by NRG's equity contributions. The excess of the consideration over the carrying value of the divested interest was recorded to additional paid-in capital. MidAmerican will fund its proportionate share of future equity contributions and other credit support for the project. NRG continues to hold a majority interest in and consolidate the project. MidAmerican's non-controlling interest on the Company's balance sheet as of March 31, 2012 represents its capital contributions.

2011 Acquisitions

The Company's acquisitions that are considered business combinations are accounted for under the acquisition method of accounting in accordance with ASC 805,  Business Combinations , or ASC 805, with identifiable assets acquired and liabilities assumed provisionally recorded at their estimated fair values on the acquisition date. The provisional amounts recognized are subject to revision until the evaluations are completed and to the extent that additional information is obtained about the facts and circumstances that existed as of the acquisition date, are required to be finalized within a measurement period not to exceed one year. The Company made several acquisitions in 2011, which were recorded as business combinations under ASC 805, for which the accounting was not finalized as of December 31, 2011. See Note 3,  Business Acquisitions and Dispositions  and Note 12,  Debt and Capital Leases , in the Company's 2011 Form 10-K, for additional information related to these acquisitions.

The accounting for the acquisitions of Energy Plus, California Valley Solar Ranch, or CVSR, Agua Caliente and Ivanpah were completed as of March 31, 2012, at which point the provisional fair values became final with no material changes recorded in the first quarter 2012.

Note 4 — Nuclear Innovation North America LLC, or NINA, Impairment Charge 

As discussed in detail in Note 4, Nuclear Innovation North America LLC Developments, including Impairment Charge, to the Company's 2011 Form 10-K, NRG deconsolidated NINA as of March 31, 2011, and recorded an impairment charge of $481 million in the quarter ended March 31, 2011 for the full amount of its investment.

12

Note 5 — Fair Value of Financial Instruments 

This footnote should be read in conjunction with the complete description under Note 5, Fair Value of Financial Instruments , to the Company's 2011 Form 10-K.

For cash and cash equivalents, funds deposited by counterparties, restricted cash, cash collateral paid and received in support of energy risk management activities, and restricted cash supporting the funded letter of credit facility, the carrying amount approximates fair value because of the short-term maturity of those instruments. Debt securities, equity securities, 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 estimated carrying values and fair values of NRG's recorded financial instruments not carried at fair market value are as follows:

 	As of March 31, 2012	 	As of December 31, 2011	
 	Carrying Amount	 	Fair Value	 	Carrying Amount	 	Fair Value	
 	(In millions)	
Assets:	 	 	 	 	 	 	 	
Notes receivable	$	182	
 	 	$	187	
 	 	$	156	
 	 	$	161	
 	
Liabilities:	 	 	 	 	 	 	 	
Long-term debt, including current portion	10,118	
 	 	10,073	
 	 	9,729	
 	 	9,716	

The fair value of the Company's Level 1 publicly-traded long-term debt is based on quoted market prices. The fair value of the Company's Level 3 notes receivable, debt securities and non publicly-traded long-term debt are based on expected future cash flows discounted at market interest rates, or current interest rates for similar instruments with equivalent credit quality.

Recurring Fair Value Measurements

For cash and cash equivalents, funds deposited by counterparties, restricted cash, and cash collateral paid and received in support of energy risk management activities, the carrying amount approximates fair value because of the nature and short-term maturity of those instruments and are classified as Level 1 within the fair value hierarchy.

13

The following tables present assets and liabilities measured and recorded at fair value on the Company's condensed consolidated balance sheet on a recurring basis and their level within the fair value hierarchy:

 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	As of March 31, 2012	
 	Fair Value	
 	Level 1	 	Level 2	 	Level 3	 	Total	
 	(In millions)	
Investment in available-for-sale securities (classified within other
    non-current assets):	 	 	 	 	 	 	 	
Debt securities	$	—	
 	 	$	—	
 	 	$	8	
 	 	$	8	
 	
Marketable equity securities	1	
 	 	—	
 	 	—	
 	 	1	
 	
Trust fund investments:	 	 	 	 	 	 	 	
Cash and cash equivalents	2	
 	 	—	
 	 	—	
 	 	2	
 	
U.S. government and federal agency obligations	36	
 	 	—	
 	 	—	
 	 	36	
 	
Federal agency mortgage-backed securities	—	
 	 	60	
 	 	—	
 	 	60	
 	
Commercial mortgage-backed securities	—	
 	 	7	
 	 	—	
 	 	7	
 	
Corporate debt securities	—	
 	 	65	
 	 	—	
 	 	65	
 	
Equity securities	236	
 	 	—	
 	 	46	
 	 	282	
 	
Foreign government fixed income securities	—	
 	 	5	
 	 	—	
 	 	5	
 	
Derivative assets:	 	 	 	 	 	 	 	
Commodity contracts	3,365	
 	 	2,258	
 	 	176	
 	 	5,799	
 	
Total assets	$	3,640	
 	 	$	2,395	
 	 	$	230	
 	 	$	6,265	
 	
Derivative liabilities:	 	 	 	 	 	 	 	
Commodity contracts	$	3,457	
 	 	$	1,847	
 	 	$	133	
 	 	$	5,437	
 	
Interest rate contracts	—	
 	 	95	
 	 	—	
 	 	95	
 	
Total liabilities	$	3,457	
 	 	$	1,942	
 	 	$	133	
 	 	$	5,532	

 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	As of December 31, 2011	
 	Fair Value	
 	Level 1	 	Level 2	 	Level 3	 	Total	
 	(In millions)	
Investment in available-for-sale securities (classified within other
non-current assets):	 	 	 	 	 	 	 	
Debt securities	$	—	
 	 	$	—	
 	 	$	7	
 	 	$	7	
 	
Marketable equity securities	1	
 	 	—	
 	 	—	
 	 	1	
 	
Trust fund investments:	 	 	 	 	 	 	 	
Cash and cash equivalents	2	
 	 	—	
 	 	—	
 	 	2	
 	
U.S. government and federal agency obligations	44	
 	 	—	
 	 	—	
 	 	44	
 	
Federal agency mortgage-backed securities	—	
 	 	63	
 	 	—	
 	 	63	
 	
Commercial mortgage-backed securities	—	
 	 	7	
 	 	—	
 	 	7	
 	
Corporate debt securities	—	
 	 	54	
 	 	—	
 	 	54	
 	
Equity securities	209	
 	 	—	
 	 	42	
 	 	251	
 	
Foreign government fixed income securities	—	
 	 	4	
 	 	—	
 	 	4	
 	
Derivative assets:	 	 	 	 	 	 	 	
Commodity contracts	2,661	
 	 	1,930	
 	 	75	
 	 	4,666	
 	
Total assets	$	2,917	
 	 	$	2,058	
 	 	$	124	
 	 	$	5,099	
 	
Derivative liabilities:	 	 	 	 	 	 	 	
Commodity contracts	$	2,757	
 	 	$	1,283	
 	 	$	67	
 	 	$	4,107	
 	
Interest rate contracts	—	
 	 	108	
 	 	—	
 	 	108	
 	
Total liabilities	$	2,757	
 	 	$	1,391	
 	 	$	67	
 	 	$	4,215	

14

There were no transfers during the three months ended March 31, 2012, and 2011, between Levels 1 and 2. The following tables reconcile, for the three months ended March 31, 2012, and 2011, 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:

 	Three months ended March 31, 2012	 	
 	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)	 	
 	Debt Securities	 	Trust Fund Investments	 	 	 	 	 	
 	 	 	 	 	Derivatives(a)	 	Total	 	 	 	 	 	 	 	
 	(In millions)	 	 	 	 	 	 	 	
Beginning balance as of January 1, 2012	$	7	
 	 	$	42	
 	 	$	8	
 	 	$	57	
 	 	 	 	 	 	 	 	
Total gains - realized/unrealized:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Included in earnings	—	
 	 	—	
 	 	17	
 	 	17	
 	 	 	 	 	 	 	 	
Included in OCI	1	
 	 	—	
 	 	—	
 	 	1	
 	 	 	 	 	 	 	 	
Included in nuclear decommissioning obligations	—	
 	 	4	
 	 	—	
 	 	4	
 	 	 	 	 	 	 	 	
Purchases	—	
 	 	—	
 	 	(4	)	 	(4	)	 	 	 	 	 	 	 	
Transfers into Level 3 (b)	—	
 	 	—	
 	 	10	
 	 	10	
 	 	 	 	 	 	 	 	
Transfers out of Level 3 (b)	—	
 	 	—	
 	 	12	
 	 	12	
 	 	 	 	 	 	 	 	
Ending balance as of March 31, 2012	$	8	
 	 	$	46	
 	 	$	43	
 	 	$	97	
 	 	 	 	 	 	 	 	
The amount of the total gains for the period included in earnings attributable to the change in unrealized gains relating to assets still held as of March 31, 2012	$	—	
 	 	$	—	
 	 	$	18	
 	 	$	18	

 	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Three months ended March 31, 2011	 	
 	Fair Value Measurement Using Significant Unobservable Inputs (Level 3)	 	
 	Debt Securities	 	Trust Fund Investments	 	 	 	 	 	
 	 	 	 	 	Derivatives(a)	 	Total	 	 	 	 	 	 	 	
 	(In millions)	 	 	 	 	 	 	 	
Beginning balance as of January 1, 2011	$	8	
 	 	$	39	
 	 	$	(27	)	 	$	20	
 	 	 	 	 	 	 	 	
Total gains/(losses) - realized/unrealized:	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Included in earnings	—	
 	 	—	
 	 	9	
 	 	9	
 	 	 	 	 	 	 	 	
Included in OCI	1	
 	 	—	
 	 	—	
 	 	1	
 	 	 	 	 	 	 	 	
Included in nuclear decommissioning obligations	—	
 	 	1	
 	 	—	
 	 	1	
 	 	 	 	 	 	 	 	
Purchases	—	
 	 	—	
 	 	3	
 	 	3	
 	 	 	 	 	 	 	 	
Transfers into Level 3 (b)	—	
 	 	—	
 	 	(18	)	 	(18	)	 	 	 	 	 	 	 	
Transfers out of Level 3 (b)	—	
 	 	—	
 	 	22	
 	 	22	
 	 	 	 	 	 	 	 	
Ending balance as of March 31, 2011	$	9	
 	 	$	40	
 	 	$	(11	)	 	$	38	
 	 	 	 	 	 	 	 	
The amount of the total gains for the period included in earnings attributable to the change in unrealized gains relating to assets still held as of March 31, 2011	$	—	
 	 	$	—	
 	 	$	2	
 	 	$	2	

(a)	Consists of derivatives 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 the energy derivatives are recorded in operating revenues and cost of operations.

15

Derivative fair value measurements
 
The majority of NRG's contracts are exchange-traded contracts with readily available quoted market prices. A portion 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. For the majority of NRG markets, the Company receives quotes from multiple sources. To the extent that NRG receives multiple quotes, the Company's prices reflect the average of the bid-ask mid-point prices obtained from all sources that NRG believes provide the most liquid market for the commodity. If the Company receives one quote, then the mid-point of the bid-ask spread for that quote is used. The terms for which such price information is available vary by commodity, region and product. A significant portion of the fair value of the Company's derivative portfolio is based on price quotes from brokers in active markets who regularly facilitate those transactions and the Company believes such price quotes are executable. The Company does not use third party sources that derive price based on proprietary models or market surveys. 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. Contracts valued with prices provided by models and other valuation techniques make up 3% of the total derivative assets and 2% 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. To the extent that NRG's net exposure under a specific master agreement is an asset, the Company uses the counterparty's default swap rate. If the exposure under a specific master agreement is a liability, the Company uses NRG's default swap rate. The credit reserve is added to the discounted fair value to reflect the exit price that a market participant would be willing to receive to assume NRG's liabilities or that a market participant would be willing to pay for NRG's assets. As of March 31, 2012, the credit reserve resulted in an $8 million increase in fair value which is composed of a $1 million gain in Other Comprehensive Income, or OCI, and a $7 million gain in operating revenue and cost of operations. As of March 31, 2011, the credit reserve resulted in a $1 million decrease in fair value which is composed of a $1 million gain in OCI and a $2 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 2011 Form 10-K, the following item 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 monitors and manages counterparty credit risk through credit policies that include: (i) an established credit approval process; (ii) daily monitoring of counterparties' credit limits; (iii) the use of credit mitigation measures such as margin, collateral, prepayment arrangements, or volumetric limits; (iv) the use of payment netting arrangements; and (v) the use of master netting agreements that allow for the netting of positive and negative exposures of various contracts associated with a single counterparty. Risk surrounding counterparty performance and credit could ultimately impact the amount and timing of expected cash flows. The Company seeks to mitigate counterparty credit risk with a diversified portfolio of counterparties. The Company also has credit protection within various agreements to call on additional collateral support if and when necessary. Cash margin is collected and held at NRG to cover the credit risk of the counterparty until positions settle.

As of March 31, 2012, counterparty credit exposure to a significant portion of the Company's counterparties was $1.1 billion and NRG held collateral (cash and letters of credit) against those positions of $204 million, resulting in a net exposure of $917 million. Counterparty credit exposure is discounted at the risk free rate. The following table highlights the counterparty credit quality and the net counterparty credit exposure by industry sector. 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 Normal Purchase Normal Sale, or NPNS, and non-derivative transactions. The exposure is shown net of collateral held, and includes amounts net of receivables or payables.

16

 	
 	 	 	
 	Net Exposure (a)	
Category	(% of Total)	
Financial institutions	54	%	
Utilities, energy merchants, marketers and other	43	
 	
Coal and emissions	1	
 	
Independent System Operators, or ISOs	2	
 	
Total as of March 31, 2012	100	%	

 	
 	 	 	
 	Net Exposure (a)	
Category	(% of Total)	
Investment grade	78	%	
Non-Investment grade	1	
 	
Non-rated (b)	21	
 	
Total as of March 31, 2012	100	%	
 	 	
(a)	Counterparty credit exposure excludes uranium and coal transportation contracts because of the unavailability of market prices.	
 	 	
(b)	For non-rated counterparties, the majority 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 representing more than 10% of total net exposure discussed above and the aggregate of such counterparties was $269 million. Approximately 92% of NRG's positions relating to this credit risk roll-off by the end of 2013. 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, solar Power Purchase Agreements, or PPAs, and a coal supply agreement. As external sources or observable market quotes are not available to estimate such exposure, the Company valued 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 March 31, 2012, credit risk exposure to these counterparties allocable to NRG's ownership interests was approximately $939 million for the next five years. This amount excludes potential credit exposures for projects with long term PPAs that have not reached commercial operations. Many of these power contracts are with utilities or public power entities that have strong credit quality and specific public utility commission or other regulatory support. In the case of the coal supply agreement, NRG holds a lien against the underlying asset. These factors significantly reduce the risk of loss.

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, or C&I, customers and the Residential and small business, or Mass, market. Retail credit risk results when a customer fails to pay for 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 March 31, 2012, the Company's retail customer credit exposure was diversified across many customers and various industries, with a significant portion of the exposure with government entities.

17

Note 6 — Nuclear Decommissioning Trust Fund 

NRG's nuclear decommissioning trust fund assets, which are for its portion of the decommissioning of the South Texas Project, or STP Units 1 & 2, 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 , or ASC 980, because the Company's nuclear decommissioning activities are subject to approval by the Public Utility Commission of Texas, or 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 the 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 March 31, 2012	 	As of December 31, 2011	
(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	$	2	
 	 	$	—	
 	 	$	—	
 	 	—	
 	 	$	2	
 	 	$	—	
 	 	$	—	
 	 	—	
 	
U.S. government and federal agency obligations	35	
 	 	2	
 	 	—	
 	 	11	
 	 	43	
 	 	3	
 	 	—	
 	 	10	
 	
Federal agency mortgage-backed securities	60	
 	 	2	
 	 	—	
 	 	23	
 	 	63	
 	 	3	
 	 	—	
 	 	23	
 	
Commercial mortgage-backed securities	7	
 	 	—	
 	 	—	
 	 	30	
 	 	7	
 	 	—	
 	 	—	
 	 	28	
 	
Corporate debt securities	65	
 	 	3	
 	 	1	
 	 	10	
 	 	54	
 	 	3	
 	 	1	
 	 	10	
 	
Equity securities	282	
 	 	141	
 	 	—	
 	 	—	
 	 	251	
 	 	113	
 	 	1	
 	 	—	
 	
Foreign government fixed income securities	5	
 	 	—	
 	 	—	
 	 	7	
 	 	4	
 	 	—	
 	 	—	
 	 	8	
 	
Total	$	456	
 	 	$	148	
 	 	$	1	
 	 	 	 	$	424	
 	 	$	122	
 	 	$	2	

The following tables summarize 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.

 	Three months ended March 31,	
 	2012	 	2011	
 	(In millions)	
Realized gains	$	3	
 	 	$	2	
 	
Realized losses	2	
 	 	2	
 	
Proceeds from sale of securities	119	
 	 	95	

18

Note 7 — Accounting for Derivative Instruments and Hedging Activities 

This footnote should be read in conjunction with the complete description under Note 6, Accounting for Derivative Instruments and Hedging Activities , to the Company's 2011 Form 10-K.

Energy-Related Commodities

As of March 31, 2012, NRG had energy-related derivative financial instruments extending through 2015, which are designated as cash flow hedges.

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 March 31, 2012, NRG had interest rate derivative instruments on recourse debt extending through 2013 and on non-recourse debt extending through 2029, 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 March 31, 2012, and December 31, 2011. 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	
Commodity	Units	March 31, 2012	 	December 31, 2011	
 	 	(In millions)	
Emissions	Short Ton	(2	)	 	(2	)	
Coal	Short Ton	30	
 	 	37	
 	
Natural Gas	MMBtu	(232	)	 	13	
 	
Oil	Barrel	1	
 	 	1	
 	
Power	MWh	6	
 	 	4	
 	
Interest	Dollars	$	2,175	
 	 	$	2,121	

19

Fair Value of Derivative Instruments

The following table summarizes the fair value within the derivative instrument valuation on the balance sheet:

 	Fair Value	
 	Derivative Assets	 	Derivative Liabilities	
(In millions)	March 31, 2012	 	December 31, 2011	 	March 31, 2012	 	December 31,
2011	
Derivatives Designated as Cash Flow or Fair Value Hedges:	 	 	 	 	 	 	 	
Interest rate contracts current	$	—	
 	 	$	—	
 	 	$	17	
 	 	$	39	
 	
Interest rate contracts long-term	—	
 	 	—	
 	 	52	
 	 	68	
 	
Commodity contracts current	269	
 	 	318	
 	 	2	
 	 	—	
 	
Commodity contracts long-term	—	
 	 	—	
 	 	3	
 	 	1	
 	
Total Derivatives Designated as Cash Flow or Fair Value Hedges	269	
 	 	318	
 	 	74	
 	 	108	
 	
Derivatives Not Designated as Cash Flow or Fair Value Hedges:	 	 	 	 	 	 	 	
Interest rate contracts current	—	
 	 	—	
 	 	22	
 	 	—	
 	
Interest rate contracts long-term	—	
 	 	—	
 	 	4	
 	 	1	
 	
Commodity contracts current	4,881	
 	 	3,898	
 	 	4,783	
 	 	3,712	
 	
Commodity contracts long-term	649	
 	 	450	
 	 	649	
 	 	394	
 	
Total Derivatives Not Designated as Cash Flow or
Fair Value Hedges	5,530	
 	 	4,348	
 	 	5,458	
 	 	4,107	
 	
Total Derivatives	$	5,799	
 	 	$	4,666	
 	 	$	5,532	
 	 	$	4,215	

Accumulated Other Comprehensive Income

The following table summarizes the effects of ASC 815, Derivatives and Hedging, or ASC 815, on NRG’s accumulated OCI balance attributable to cash flow hedge derivatives, net of tax:

 	Three months ended March 31, 2012	 	Three months ended March 31, 2011	
(In millions)	Energy Commodities	 	Interest Rate	 	Total	 	Energy Commodities	 	Interest Rate	 	Total	
Accumulated OCI beginning balance	$	188	
 	 	$	(56	)	 	$	132	
 	 	$	488	
 	 	$	(47	)	 	$	441	
 	
Reclassified from accumulated OCI to income:	

 	 	
 	 	 	
Due to realization of previously deferred amounts	(31	)	 	3	
 	 	(28	)	 	(98	)	 	11	
 	 	(87	)	
Mark-to-market of cash flow hedge accounting contracts	13	
 	 	6	
 	 	19	
 	 	2	
 	 	3	
 	 	5	
 	
Accumulated OCI ending balance, net of $82 and $220 tax, respectively	$	170	
 	 	$	(47	)	 	$	123	
 	 	$	392	
 	 	$	(33	)	 	$	359	
 	
Gains/(losses) expected to be realized from OCI during the next 12 months, net of $66 and $154 tax respectively	$	137	
 	 	$	(23	)	 	$	114	
 	 	$	265	
 	 	$	(2	)	 	$	263	
 	
(Losses)/gains recognized in income from the ineffective portion of cash flow hedges	$	(1	)	 	$	(2	)	 	$	(3	)	 	$	3	
 	 	$	(1	)	 	$	2	

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.

20

Impact of Derivative Instruments on the Statement 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 NRG's statement of operations. These amounts are included within operating revenues and cost of operations.

 	Three months ended March 31,	
 	2012	 	2011	
 	(In millions)	
Unrealized mark-to-market results	 	 	 	
Reversal of previously recognized unrealized gains on settled positions related to economic hedges	$	(41	)	 	$	(2	)	
Reversal of loss positions acquired as part of the Reliant Energy and Green Mountain Energy acquisitions	14	
 	 	41	
 	
Net unrealized (losses)/gains on open positions related to economic hedges	(137	)	 	91	
 	
(Losses)/gains on ineffectiveness associated with open positions treated as
    cash flow hedges	(1	)	 	3	
 	
Total unrealized mark-to-market (losses)/gains for economic hedging activities	(165	)	 	133	
 	
Reversal of previously recognized unrealized (gains)/losses on settled positions related to trading activity	(30	)	 	14	
 	
Net unrealized gains on open positions related to trading activity	28	
 	 	—	
 	
Total unrealized mark-to-market (losses)/gains for trading activity	(2	)	 	14	
 	
Total unrealized (losses)/gains	$	(167	)	 	$	147	

 	
 	 	 	 	 	 	 	 	
 	Three months ended March 31,	
 	2012	 	2011	
 	(In millions)	
Revenue from operations — energy commodities	$	38	
 	 	$	13	
 	
Cost of operations	(205	)	 	134	
 	
Total impact to statement of operations	$	(167	)	 	$	147	

The reversal of loss positions acquired as part of the Reliant Energy and Green Mountain Energy acquisitions were valued based upon the forward prices on the acquisition dates. The roll off amounts were offset by realized losses at the settled prices and are reflected in the cost of operations during the same period.

For the three months ended March 31, 2012, the unrealized loss from open economic hedge positions was the result of a decrease in value of forward purchases of coal, due to decreases in forward coal prices along with a decrease in value of forward purchases and sales of natural gas and electricity, due to a decrease in forward power and gas prices and increases in Electric Reliability Council of Texas, or ERCOT, heat rates.

For the three months ended March 31, 2011, the unrealized gain from open economic hedge positions was the result of an increase in value of forward purchases and sales of natural gas, electricity and fuel due to an increase in forward power and gas prices.

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 March 31, 2012, was $119 million. The collateral required for contracts with credit rating contingent features was $42 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 $45 million as of March 31, 2012.

See Note 5, Fair Value of Financial Instruments, to this Form 10-Q for discussion regarding concentration of credit risk.

21

Note 8 — 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 2011 Form 10-K.

Long-term debt and capital leases consisted of the following:

 	 	March 31, 2012	 	December 31, 2011	 	Interest rate % (a)	
 	 	(In millions, except rates)	
NRG Recourse Debt:	 	 	 	 	 	 	
Senior notes, due 2021	 	$	1,200	
 	 	$	1,200	
 	 	7.875	
Senior notes, due 2020	 	1,100	
 	 	1,100	
 	 	8.250	
Senior notes, due 2019	 	800	
 	 	800	
 	 	7.625	
Senior notes, due 2019	 	692	
 	 	691	
 	 	8.500	
Senior notes, due 2018	 	1,200	
 	 	1,200	
 	 	7.625	
Senior notes, due 2017	 	1,090	
 	 	1,090	
 	 	7.375	
Term loan facility, due 2018	 	1,584	
 	 	1,588	
 	 	L+3.00	
Indian River Power LLC, tax-exempt bonds, due 2040	 	57	
 	 	57	
 	 	6.000	
Indian River Power LLC, tax-exempt bonds, due 2045	 	157	
 	 	148	
 	 	5.375	
Dunkirk Power LLC, tax-exempt bonds, due 2042	 	59	
 	 	59	
 	 	5.875	
Subtotal NRG Recourse Debt	 	7,939	
 	 	7,933	
 	 	 	
NRG Non-Recourse Debt:	 	 	 	 	 	 	
Ivanpah Financing:	 	 	 	 	 	 	
Solar Partners I, due 2014 and 2033	 	351	
 	 	290	
 	 	1.126 - 3.991	
Solar Partners II, due 2014 and 2038	 	377	
 	 	314	
 	 	1.116 - 4.195	
Solar Partners VIII, due 2014 and 2038	 	321	
 	 	270	
 	 	1.381 - 4.256	
NRG Peaker Finance Co. LLC, bonds, due 2019	 	191	
 	 	190	
 	 	L+1.07	
Agua Caliente Solar, LLC, due 2037	 	233	
 	 	181	
 	 	2.730 - 3.256	
NRG West Holdings LLC, term loan, due 2023	 	198	
 	 	159	
 	 	L+2.25 - 2.75	
NRG Energy Center Minneapolis LLC, senior secured notes,
   due 2013, 2017 and 2025	 	147	
 	 	151	
 	 	5.95 - 7.31	
CVSR - High Plains Ranch II LLC, due 2037	 	138	
 	 	—	
 	 	0.61 - 0.68	
South Trent Wind LLC, financing agreement, due 2020	 	75	
 	 	75	
 	 	L+2.50	
Solar Power Partners - SPP Fund II/IIB LLC term loans, due 2017	 	17	
 	 	17	
 	 	L+3.50	
Solar Power Partners - SPP Fund III LLC term loan, due 2024	 	42	
 	 	42	
 	 	L+3.50	
NRG Solar Roadrunner LLC, due 2031	 	47	
 	 	61	
 	 	L+2.01	
NRG Solar Blythe LLC, credit agreement, due 2028	 	27	
 	 	27	
 	 	L+2.50	
Other	 	15	
 	 	19	
 	 	various	
Subtotal NRG Non-Recourse Debt	 	2,179	
 	 	1,796	

Subtotal long-term debt	 	10,118	
 	 	9,729	
 	 	 	
Capital leases:	 	 	 	 	 	 	
Saale Energie GmbH, Schkopau capital lease, due 2021	 	103	
 	 	103	
 	 	 	
Subtotal	 	10,221	
 	 	9,832	
 	 	 	
Less current maturities	 	71	
 	 	87	
 	 	 	
Total long-term debt and capital leases	 	$	10,150	
 	 	$	9,745	
 	 	 	
(a) L+ equals LIBOR plus x%.

22

NRG Repowering Holdings LLC

On January 25, 2012, NRG Repowering Holdings LLC, or NRG Repowering, terminated its revolving credit facility, repaid the $5 million then outstanding, and a supporting letter of credit issued by NRG was returned.

On January 25, 2012, NRG Repowering entered into a Credit and Reimbursement Agreement which provides for a $10 million working capital facility that can be used for general corporate purposes or to issue letters of credit, and an $80 million letter of credit facility. Interest on the letters of credit accrues at 3.5% and on loans under the working capital facility at the London Inter-Bank Offered Rate, or LIBOR, plus 3.50%. The facility is secured by NRG Repowering's investments in GenConn Energy, LLC and South Trent Wind LLC, and matures January 25, 2015. As of March 31, 2012, NRG Repowering had issued $10 million letter of credit under the working capital facility and $80 million in letters of credit under the letter of credit facility.

Alpine Financing
 
On March 16, 2012, NRG, through its wholly-owned subsidiary, NRG Solar Alpine LLC, or Alpine, entered into a credit agreement with a group of lenders, or the Alpine Financing Agreement, for a $166 million construction loan that will convert to a term loan upon completion of the project and a $68 million cash grant loan. The construction loan has an interest rate of LIBOR plus an applicable margin of 2.50% and the cash grant loan has an interest rate of LIBOR plus an applicable margin of 2.25%. The term loan has an interest rate of LIBOR plus an applicable margin of 2.50%, which escalates 0.25% on the fifth anniversary of the term conversion. The term loan, which is secured by all the assets of Alpine, matures on the 10 th  anniversary of the term conversion and amortizes based upon a predetermined schedule. The cash grant loan matures upon the earlier of the receipt of the cash grant or February 2013. The Alpine Financing Agreement also includes a letter of credit facility on behalf of Alpine of up to $37 million. Alpine pays an availability fee of 100% of the applicable margin on issued letters of credit. As of March 31, 2012, $2 million was outstanding under the construction loan, nothing was outstanding under the cash grant loans, and $18 million in letters of credit in support of the project were issued.
 
Also related to the Alpine Financing Agreement, on March 16, 2012, Alpine entered into a series of fixed for floating interest rate swaps for at least 85% of the outstanding term loan amount, intended to hedge the risks associated with floating interest rates. Alpine will pay its counterparty the equivalent of a 2.74% fixed interest payment on a predetermined notional value, and Alpine will receive quarterly the equivalent of a floating interest payment based on a one month LIBOR calculated on the same notional value through December 31, 2012 and based on a three month LIBOR from December 31, 2012 through the term loan maturity date. All interest rate swap payments by Alpine and its counterparty are made monthly through December 31, 2012, and quarterly thereafter and the LIBOR rate is determined in advance of each interest period. The original notional amount of the swap, which became effective March 31, 2012, and matures on December 31, 2029, was $3 million and will increase and amortize in proportion to the loan.

Roadrunner Financing

On March 20, 2012, NRG, through its wholly-owned subsidiary, NRG Roadrunner LLC, or Roadrunner, received proceeds of $21 million under its cash grant application. These proceeds were used to repay Roadrunner's cash grant loan of $17 million plus accrued interest. The remaining cash was returned to NRG under the terms of the accounts agreement.

CVSR Financing
On March 9, 2012, NRG, through its wholly-owned subsidiary, High Plains Ranch II LLC, completed its first borrowing of $138 million under the CVSR Financing Agreement with the Federal Financing Bank. As of March 31, 2012, $138 million was outstanding under the loan.

23

Note 9 — Variable Interest Entities, or VIEs 

NRG has interests in entities that are considered Variable Interest Entities, or 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 subsidiary, NRG Connecticut Peaking Development LLC, NRG owns a 50% interest in GenConn, a limited liability company which owns and operates two 200 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 $131 million as of March 31, 2012.

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 $98 million as of March 31, 2012.

Texas Coastal Ventures, LLC— NRG owns 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 equity investment, which was $49 million as of March 31, 2012.

Note 10 — Changes in Capital Structure 
As of March 31, 2012, and December 31, 2011, the Company had 500,000,000 shares of common stock authorized. The following table reflects the changes in NRG's common shares issued and outstanding:

 	Issued	 	Treasury	 	Outstanding	
Balance as of December 31, 2011	304,183,720	
 	 	(76,664,199	)	 	227,519,521	
 	
Shares issued under LTIP	89,563	
 	 	—	
 	 	89,563	
 	
Shares issued under ESPP	—	
 	 	76,423	
 	 	76,423	
 	
Balance as of March 31, 2012	304,273,283	
 	 	(76,587,776	)	 	227,685,507	

Employee Stock Purchase Plan —On April 25, 2012, NRG shareholders approved an increase of 1,000,000 shares available for issuance under the NRG Energy, Inc. Employee Stock Purchase Plan, or ESPP. Subsequent to this approval, 1,100,928 shares of treasury stock are available for issuance under the ESPP.

24

Note 11 — Loss Per Share 

Basic and diluted loss per common share is computed by dividing the net loss less accumulated preferred stock dividends by the weighted average number of common shares outstanding. Shares issued and treasury shares repurchased during the period are weighted for the portion of the period that they were outstanding.

The reconciliation of NRG's basic and diluted loss per share is shown in the following table:

 	 	 	 	 	 	 	 	
 	Three months ended March 31,	
(In millions, except per share data)	2012	 	2011	
Basic and diluted loss per share attributable to NRG common stockholders	 	 	 	
Numerator:	 	 	 	
Net loss attributable to NRG Energy, Inc.	$	(207	)	 	$	(260	)	
Preferred stock dividends	(2	)	 	(2	)	
Net loss attributable to NRG Energy, Inc. available to common stockholders	$	(209	)	 	$	(262	)	
Denominator:	 	 	 	
Weighted average number of common shares outstanding	228	
 	 	247	
 	
Basic and diluted loss per share:	 	 	 	
Net loss attributable to NRG Energy, Inc.	$	(0.92	)	 	$	(1.06	)	

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 per share:

 	Three months ended March 31,	
(In millions of shares)	2012	 	2011	
Equity compensation plans	9	
 	 	7	
 	
Embedded derivative of 3.625% redeemable perpetual preferred stock	16	
 	 	16	
 	
Total	25	
 	 	23	

25

Note 12 — Segment Reporting 

Effective in fiscal year 2012, NRG's segment structure and its allocation of corporate expenses were updated to reflect how management currently makes financial decisions and allocates resources. The Company has recast the 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 businesses, conventional power generation, alternative energy businesses and corporate activities.  Within NRG's conventional power generation operations, there are distinct components with separate operating results and management structures for the following geographical regions: Texas, Northeast, South Central, West and Other, which includes its international businesses, thermal and chilled water business and maintenance services.  The Company's alternative energy businesses include solar and wind assets, electric vehicle services and carbon capture business.  Intersegment sales are accounted for at market.

 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
(In millions)	 	 	Conventional Power Generation	 	 	 	 	 	 	 	 	
Three months ended March 31, 2012	Retail	 	Texas(a)	 	Northeast(b)	 	South
Central	 	West	 	Other (c)	 	Alternative Energy (d)	 	Corporate	 	Elimination	 	Total	
Operating revenues	$	1,166	
 	 	$	458	
 	 	$	148	
 	 	$	173	
 	 	$	42	
 	 	$	94	
 	 	$	22	
 	 	$	3	
 	 	$	(244	)	 	$	1,862	
 	
Depreciation and amortization	41	
 	 	114	
 	 	32	
 	 	23	
 	 	2	
 	 	4	
 	 	11	
 	 	3	
 	 	—	
 	 	230	
 	
Equity in earnings/(losses) of unconsolidated affiliates	—	
 	 	—	
 	 	5	
 	 	—	
 	 	(2	)	 	3	
 	 	2	
 	 	—	
 	 	—	
 	 	8	
 	
Income/(loss) before income taxes	7	
 	 	(74	)	 	(43	)	 	(30	)	 	(14	)	 	10	
 	 	(11	)	 	(171	)	 	—	
 	 	(326	)	
Net income/(loss) attributable to NRG Energy, Inc.	$	7	
 	 	$	(74	)	 	$	(43	)	 	$	(30	)	 	$	(14	)	 	$	8	
 	 	$	(12	)	 	$	(49	)	 	$	—	
 	 	$	(207	)	
Total assets	$	2,280	
 	 	$	13,681	
 	 	$	1,923	
 	 	$	1,270	
 	 	$	661	
 	 	$	1,073	
 	 	$	4,095	
 	 	$	20,541	
 	 	$	(16,994	)	 	$	28,530	

(a)	Includes inter-segment revenues of $182 million.	
 	 	
(b)	Includes inter-segment revenues of $35 million.	
 	 	
(c)	Includes inter-segment revenues of $20 million.	
 	 	
(d)	Includes inter-segment revenues of $4 million.	

 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
(In millions)	 	 	Conventional Power Generation	 	 	 	 	 	 	 	 	
Three months ended March 31, 2011	Retail	 	Texas(e)	 	Northeast	 	South
Central	 	West	 	Other(f)	 	Alternative Energy	 	Corporate(g)	 	Elimination	 	Total	
Operating revenues	$	1,126	
 	 	$	523	
 	 	$	226	
 	 	$	189	
 	 	$	40	
 	 	$	84	
 	 	$	9	
 	 	$	1	
 	 	$	(203	)	 	$	1,995	
 	
Depreciation and amortization	26	
 	 	115	
 	 	29	
 	 	20	
 	 	2	
 	 	3	
 	 	6	
 	 	4	
 	 	—	
 	 	205	
 	
Equity in earnings/(losses) of unconsolidated affiliates	—	
 	 	—	
 	 	2	
 	 	—	
 	 	—	
 	 	4	
 	 	(8	)	 	—	
 	 	—	
 	 	(2	)	
Income/(loss) before income taxes	294	
 	 	27	
 	 	(34	)	 	12	
 	 	13	
 	 	10	
 	 	(18	)	 	(669	)	 	—	
 	 	(365	)	
Net income/(loss) attributable to
NRG Energy, Inc.	$	297	
 	 	$	27	
 	 	$	(34	)	 	$	12	
 	 	$	13	
 	 	$	8	
 	 	$	(18	)	 	$	(565	)	 	$	—	
 	 	$	(260	)	
(e)    Includes inter-segment revenues of $196 million.
(f)    Includes inter-segment revenues of $6 million.
(g)    Includes impairment charge on investment of $481 million and loss on debt extinguishment of $28 million.

 	

 	

26

Note 13 — Income Taxes 
Effective Tax Rate
The income tax provision consisted of the following:

 	Three months ended March 31,	
(In millions except otherwise noted)	2012	 	2011	
Income tax benefit	$	(120	)	 	$	(105	)	
Effective tax rate	36.8	%	 	28.8	%	

For the three months ended March 31, 2012, NRG recorded an income tax benefit on a pre-tax loss of $326 million. NRG's overall effective tax rate was different than the statutory rate of 35% primarily due to the generation of ITCs from the Company's Agua Caliente solar project in Arizona.

For the three months ended March 31, 2011, NRG's overall effective tax rate was different than the statutory rate of 35% primarily due to the change in the valuation allowance resulting from capital losses generated in the quarter for which there were no projected capital gains or available tax planning strategies.

Uncertain tax benefits

As of March 31, 2012, NRG has recorded a non-current tax liability of $62 million for uncertain tax benefits from positions taken on various state tax returns, including accrued interest. NRG has accrued interest related to these uncertain tax benefits of $1 million for the three months ended March 31, 2012, and has accrued $13 million of interest and penalties since adoption. The Company recognizes interest and penalties related to uncertain tax benefits in income tax expense.

The Company will continue to be under examination by various state and foreign tax jurisdictions for multiple years.

Tax Receivable and Payable

As of March 31, 2012, NRG recorded a current domestic tax receivable of $31 million, of which $18 million is related to property tax refunds as a result of the New York State Empire Zone program and $11 million relates to Federal income tax refunds for prior year tax return filings. As of March 31, 2012, NRG has a current tax payable of $20 million that represents a tax liability due for domestic state taxes of $18 million, as well as foreign taxes payable of $2 million.

27

Note 14 — Commitments and Contingencies 

First Lien Structure
NRG has granted first liens to certain counterparties on substantially all of the Company's assets 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 March 31, 2012, all hedges under the first liens were in-the-money for NRG on a counterparty aggregate basis.

Contingencies
Set forth below is a description of the Company's material legal proceedings. The Company believes that it has valid defenses to these legal proceedings and intends to defend them vigorously. Pursuant to the requirements of ASC 450, Contingencies  and related guidance, 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.

California Department of Water Resources
This matter concerns, among other contracts and other defendants, the California Department of Water Resources, or CDWR, and its wholesale power contract with subsidiaries of WCP (Generation) Holdings, Inc., or WCP. The case originated with a February 2002 complaint filed by the State of California alleging that many parties, including WCP subsidiaries, overcharged the State of California. For WCP, the alleged overcharges totaled approximately $940 million for 2001 and 2002. The complaint demanded that the Federal Energy Regulatory Commission, or FERC, abrogate the CDWR contract and sought refunds associated with revenues collected under the contract. In 2003, the FERC rejected this complaint, denied rehearing, and the case was appealed to the U.S. Court of Appeals for the Ninth Circuit where oral argument was held on December 8, 2004.

On December 19, 2006, the Ninth Circuit decided that in FERC's review of the contracts at issue, FERC could not rely on the  Mobile-Sierra  standard presumption of just and reasonable rates, where such contracts were not reviewed by the FERC with full knowledge of the then existing market conditions. WCP and others sought review by the U.S. Supreme Court. WCP's appeal was not selected, but instead held by the Supreme Court. In the appeal that was selected by the Supreme Court, on June 26, 2008, the Supreme Court ruled: (i) that the  Mobile-Sierra  public interest standard of review applied to contracts made under a seller's market-based rate authority; (ii) that the public interest “bar” required to set aside a contract remains a very high one to overcome; and (iii) that the  Mobile-Sierra  presumption of contract reasonableness applies when a contract is formed during a period of market dysfunction unless (a) such market conditions were caused by the illegal actions of one of the parties or (b) the contract negotiations were tainted by fraud or duress. In this related case, the U.S. Supreme Court affirmed the Ninth Circuit's decision agreeing that the case should be remanded to the FERC to clarify the FERC's 2003 reasoning regarding its rejection of the original complaint relating to the financial burdens under the contracts at issue and to alleged market manipulation at the time these contracts were formed. As a result, the U.S. Supreme Court then reversed and remanded the WCP CDWR case to the Ninth Circuit for treatment consistent with its June 26, 2008, decision in the related case. On October 20, 2008, the Ninth Circuit asked the parties in the remanded CDWR case, including WCP and the FERC, whether that Court should answer a question the U.S. Supreme Court did not address in its June 26, 2008, decision; whether the  Mobile-Sierra  doctrine applies to a third-party that was not a signatory to any of the wholesale power contracts, including the CDWR contract, at issue in that case. Without answering that reserved question, on December 4, 2008, the Ninth Circuit vacated its prior opinion and remanded the WCP CDWR case back to the FERC for proceedings consistent with the U.S. Supreme Court's June 26, 2008, decision. On December 15, 2008, WCP and the other seller-defendants filed with the FERC a Motion for Order Governing Proceedings on Remand. On January 14, 2009, the Public Utilities Commission of the State of California, or CPUC, filed an Answer and Cross Motion for an Order Governing Procedures on Remand and on January 28, 2009, WCP and the other seller-defendants filed their reply. At this time, the FERC has not acted on remand.

28

On January 14, 2010, the U.S. Supreme Court issued its decision in an unrelated proceeding involving the Mobile-Sierra doctrine that will affect the standard of review applied to the CDWR contract on remand before the FERC. In  NRG Power Marketing v. Maine Public Utilities Commission , the Supreme Court held that the  Mobile-Sierra  presumption regarding the reasonableness of contract rates does not depend on the identity of the complainant who seeks a FERC investigation/refund.

As part of the 2006 acquisition of Dynegy's 50% ownership interest in WCP, WCP and NRG assumed responsibility for any risk of loss arising from this case, unless any such loss was deemed to have resulted from certain acts of gross negligence or willful misconduct on the part of Dynegy, in which case any such loss would be shared equally between WCP and Dynegy.

On March 22, 2012, NRG reached an agreement in principle with the CPUC to settle and resolve this matter, including all related claims, on behalf of NRG and on behalf of Dynegy. The agreement in principle was announced by the Company on March 23, 2012, as well as by the CPUC and by the California Governor's Office. The documented agreement was executed and submitted to FERC on April 27, 2012 for its approval. The settlement agreement contains three material elements to be fulfilled over a four to six year period, depending upon several factors. First, the settlement agreement includes a $20 million cash payment due 30 days after FERC approval. Second, it includes the construction and operation of a fee-based charging network, to be owned and operated by NRG subsidiary, eVgo, which will consist of at least 200 publicly available fast-charging electric vehicle stations installed at locations across California. Last, it calls for the wiring and associated work required to improve at least 10,000 individual parking spaces to allow for the charging of electric vehicles in at least 1,000 multi-family complexes, worksites, and public interest locations such as community colleges, public universities, and public or non-profit hospitals. Although these improved newly wired parking spaces will continue to be owned by the local property owner, eVgo will have an 18-month exclusive right to obtain customers from these locations starting from the date of each completed installation. The expected $20 million cash payment was accrued and expensed in the statement of operations for the three months ended March 31, 2012. In addition, the Company expects to spend approximately $100 million over the next four to six year period, during which the Company will fulfill the other elements of the settlement, and will capitalize a substantial majority of the costs as property, plant and equipment, representing the costs to construct the charging network and the wiring, which will be productive assets. The Company will expense the costs to operate the assets as incurred. FERC approval is expected in the second or third quarter of 2012.

Louisiana Generating, LLC

On February 11, 2009, the U.S. Department of Justice, or U.S. DOJ, acting at the request of the U.S. Environmental Protection Agency, or U.S. EPA, commenced a lawsuit against Louisiana Generating, LLC, or LaGen, in federal district court in the Middle District of Louisiana alleging violations of the Clean Air Act, or CAA, at the Big Cajun II power plant. This is the same matter for which Notices of Violation, or NOVs, were issued to LaGen on February 15, 2005, and on December 8, 2006. Specifically, it is alleged that in the late 1990's, several years prior to NRG's acquisition of the Big Cajun II power plant from the Cajun Electric bankruptcy and several years prior to the NRG bankruptcy, modifications were made to Big Cajun II Units 1 and 2 by the prior owners without appropriate or adequate permits and without installing and employing the best available control technology, or BACT, to control emissions of nitrogen oxides and/or sulfur dioxides. The relief sought in the complaint includes a request for an injunction to: (i) preclude the operation of Units 1 and 2 except in accordance with the CAA; (ii) order the installation of BACT on Units 1 and 2 for each pollutant subject to regulation under the CAA; (iii) obtain all necessary permits for Units 1 and 2; (iv) order the surrender of emission allowances or credits; (v) conduct audits to determine if any additional modifications have been made which would require compliance with the CAA's Prevention of Significant Deterioration program; (vi) award to the U.S. DOJ its costs in prosecuting this litigation; and (vii) assess civil penalties of up to $27,500 per day for each CAA violation found to have occurred between January 31, 1997, and March 15, 2004, up to $32,500 for each CAA violation found to have occurred between March 15, 2004, and January 12, 2009, and up to $37,500 for each CAA violation found to have occurred after January 12, 2009.

On April 27, 2009, LaGen filed an objection in the Cajun Electric Cooperative Power, Inc.'s bankruptcy proceeding in the U.S. Bankruptcy Court for the Middle District of Louisiana to seek to prevent the bankruptcy from closing. LaGen also filed a complaint, or adversary proceeding, in the same bankruptcy proceeding, seeking a judgment that: (i) it did not assume liability from Cajun Electric for any claims or other liabilities under environmental laws with respect to Big Cajun II that arose, or are based on activities that were undertaken, prior to the closing date of the acquisition; (ii) it is not otherwise the successor to Cajun Electric with respect to environmental liabilities arising prior to the acquisition; and (iii) Cajun Electric and/or the Bankruptcy Trustee are exclusively liable for any of the violations alleged in the February 11, 2009 lawsuit to the extent that such claims are determined to have merit. On April 15, 2010, the bankruptcy court signed an order granting LaGen's stipulation of voluntary dismissal without prejudice of the adversary proceeding. The bankruptcy proceeding has since closed.

29

On August 24, 2009, LaGen filed a motion to dismiss this lawsuit, and on September 25, 2009, the U.S. DOJ filed its opposition to the motion. Thereafter, on February 18, 2010, the Louisiana Department of Environmental Quality, or LDEQ, filed a motion to intervene in the above lawsuit and a complaint against LaGen for alleged violations of Louisiana's Prevention of Significant Deterioration, or PSD, regulations and Louisiana's Title V operating permit program. LDEQ seeks substantially similar relief to that requested by the U.S. DOJ. On February 19, 2010, the district court granted LDEQ's motion to intervene. On April 26, 2010, LaGen filed a motion to dismiss the LDEQ complaint. On July 21, 2010, the motions to dismiss the U.S. DOJ and LDEQ complaints were argued to the district court. On August 20, 2010, the parties submitted proposed findings of fact and conclusions of law, and thereafter submitted additional briefing on emerging jurisprudence from other jurisdictions touching on the issues at stake in the lawsuit. Having not ruled on the motion to dismiss, on February 4, 2011, LaGen filed motions for summary judgment requesting that the court dismiss all of the U.S. DOJ's claims. Also on February 4, 2011, the U.S. DOJ filed three motions for partial summary judgment. Additional summary judgment briefing was filed by the parties on April 4, 2011. On November 2, 2011, the court heard oral argument on three motions for summary judgment. On December 1, 2011, the court issued an order denying two of LaGen's motions for summary judgment addressing potential legal defenses to CAA liability. In the same order, the court also granted, in part, the U.S. DOJ's motion for summary judgment on its successor liability theory. The court held that LaGen could be found to have assumed liability for alleged PSD violations under the terms of the agreement through which LaGen acquired Big Cajun II in 2000, but ruled that the facts necessary to determine whether any such liabilities were actually assumed must be determined at a liability-phase trial, if necessary. In its December 1, 2011 decision, the court also ruled that any potential civil penalties would not be available for the periods prior to the five year period preceding the filing of the lawsuit on February 11, 2009.

Three additional motions for summary judgment and multiple motions in limine, including motions that could result in dismissal of the government's claims before trial if resolved in LaGen's favor, remain pending before the court; some of these motions were argued on March 21 and 22, 2012. On January 17, 2012, LaGen filed a demand for a jury trial. On January 20, 2012, the court scheduled a liability-phase trial for October 15, 2012, should the case proceed to that stage, and a remedy-phase trial set to occur at a later date to be determined in the event of an adverse decision in a liability-phase trial. Because of the inherent uncertainty of litigation, including the fact that no determination of liability has yet been made by the Court, NRG cannot predict the impact, at this time, that this matter may have on the Company's business, results of operations, financial position, or cash flows.

In a related matter, soon after the filing of the above referenced U.S. DOJ lawsuit, LaGen sought insurance coverage from its insurance carrier, Illinois Union Insurance Company, or ILU. ILU denied coverage and thereafter LaGen filed a lawsuit (which was consolidated with a prior suit filed by ILU) seeking a declaration that ILU must provide coverage to LaGen for the defense costs incurred in defending the U.S. DOJ lawsuit.  LaGen and ILU both filed motions for summary judgment and on January 30, 2012, the court issued an order granting LaGen's motion finding that ILU has a duty to defend LaGen. On February 27, 2012, ILU filed a motion for new trial or, in the alternative, for an interlocutory appeal. LaGen filed an opposition to this motion on March 19, 2012.

Wise v. Energy Plus Holdings, LLC

On October 18, 2011, plaintiff filed a purported class action lawsuit on behalf of New York consumers against Energy Plus in the U.S. District Court for the Southern District of New York.  Claiming statutory damages in excess of $5 million, the plaintiff alleges violations of New York business laws as well as unjust enrichment. Specifically, the plaintiff claims that Energy Plus misrepresents that its rates are competitive in the market; fails to disclose that its rates are substantially higher than those in the market and that Energy Plus has engaged in deceptive practices in its marketing of energy services. Plaintiff seeks that this matter be certified as a class action, with treble damages, interest, costs, attorneys' fees, and any other relief that the court deems just and proper. On January 11, 2012, plaintiff filed an amended complaint in which they added another co-plaintiff, made additional claims as to how they became customers of Energy Plus and made some additional allegations as to alleged representations on the Energy Plus website. On February 1, 2012, Energy Plus filed a motion to dismiss the amended complaint. On March 23, 2012, an order was entered dismissing the plaintiffs' claims for unjust enrichment and that Energy Plus's disclosure of its variable rate is inadequate. The purported class action is now limited to plaintiffs' claims of potential misrepresentation in Energy Plus's advertising of its products.

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Note 15 — Regulatory Matters 

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 Independent System Operator, or ISO, 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.

California — On May 4, 2010, in Southern California Edison Company v. FERC, the U.S. Court of Appeals for the D.C. Circuit vacated FERC's acceptance of station power rules for the California Independent System Operator, or CAISO, market, and remanded the case for further proceedings at FERC. On August 30, 2010, FERC issued an Order on Remand effectively disclaiming jurisdiction over how the states impose retail station power charges. Due to reservation-of-rights language in the California utilities' state-jurisdictional station power tariffs, FERC's ruling arguably requires 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 February 28, 2011, FERC issued an order denying rehearing. The Company, together with other generators, filed an appeal and briefing of the case is currently underway. On November 18, 2011, Southern California Edison Company 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. The Company has filed a protest with the CPUC objecting to Southern California Edison's filing. The Company believes it has established an appropriate reserve.

Retail (Replacement Reserve)—On November 14, 2006, Constellation Energy Commodities Group, or Constellation, filed a complaint with the PUCT alleging that ERCOT misapplied the Replacement Reserve Settlement, or RPRS, Formula contained in the ERCOT protocols from April 10, 2006, through September 27, 2006.  Specifically, Constellation disputed approximately $4 million in under-scheduling charges for capacity insufficiency asserting that ERCOT applied the wrong protocol.  Retail Electric Providers, or REPS, other market participants, ERCOT, and PUCT staff opposed Constellation's complaint.  On January 25, 2008, the PUCT entered an order finding that ERCOT correctly settled the capacity insufficiency charges for the disputed dates in accordance with ERCOT protocols and denied Constellation's complaint.  On April 9, 2008, Constellation appealed the PUCT order to the Civil District Court of Travis County, Texas and on June 19, 2009, the court issued a judgment reversing the PUCT order, finding that the ERCOT protocols were in irreconcilable conflict with each other.  Under the PUCT ordered formula, Qualified Scheduling Entities, or QSEs, who under-scheduled capacity within any of ERCOT's four congestion zones were assessed under-scheduling charges which defrayed the costs incurred by ERCOT for RPRS that would otherwise be spread among all load-serving QSEs.  Under the Court's decision, all RPRS costs would be assigned to all load-serving QSEs based upon their load ratio share without assessing any separate charge to those QSEs who under-scheduled capacity.  If under-scheduling charges for capacity insufficient QSEs were not used to defray RPRS costs, REPS's share of the total RPRS costs allocated to QSEs would increase.  On July 20, 2009, REPS filed an appeal to the Third Court of Appeals in Travis County, Texas, thereby staying the effect of the trial court's decision.  On October 6, 2010, the parties argued the appeal before the Court of Appeals for the Third District in Austin, Texas.  On September 28, 2011, the Court of Appeals reversed the trial court decision, reinstating the PUCT's order, consistent with REPS' position. On January 13, 2012, Constellation filed a Petition for Review in the Supreme Court of Texas asking the Court to grant review of and reverse the Court of Appeals decision. The Texas Supreme Court requested that a response to Constellation's petition be filed. The response is due May 16, 2012.   

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Retail (Midwest ISO SECA) — Green Mountain Energy previously provided competitive retail energy supply in the Midwest ISO region during the relevant period of January 1, 2002, to December 31, 2005. By order dated November 18, 2004, FERC eliminated certain regional through-and-out transmission rates charged by transmission owners in the regional electric grids operated by the Midwest Independent Transmission Systems Operator, Inc., or MISO, and PJM Interconnection, L.L.C., or PJM. In order to temporarily compensate the transmission owners for revenue lost as a result of the elimination of the through-and-out transmission rates, FERC also ordered MISO, PJM and their respective transmission owners to provide for the recovery of certain Seams Elimination Charge/Cost Adjustments/Assignments, or SECA, charges effective December 1, 2004, through March 31, 2006, based on usage during 2002 and 2003. The tariff amendments filed by MISO and the MISO transmission owners allocated certain SECA charges to various zones and sub-zones within MISO, including a sub-zone called the Green Mountain Energy Company Sub-zone. Over the last several years, there has been extensive litigation before FERC relating to these charges, seeking, among other things, to recover monies from Green Mountain Energy, and before the federal appellate courts. Green Mountain Energy has not paid any asserted SECA charges.

On May 21, 2010, FERC issued two orders. In its Order on Rehearing, FERC denied all requests for rehearing of its past orders directing and accepting the SECA compliance filings of MISO, PJM, and the transmission owners. In its Order on Initial Decision, FERC: (1) affirmed an order by the Administrative Law Judge granting Green Mountain Energy partial summary judgment and holding Green Mountain Energy not liable for SECA charges for January  -  March 2006; and (2) reversed an August 2006 determination by the Administrative Law Judge that Green Mountain Energy could be held directly liable for some amount of SECA charges. The Order on Initial Decision also directed that the two Regional Transmission Organizations, or RTOs, and their respective transmission owners submit further compliance filings, which were filed on August 19, 2010. FERC has not yet ruled on those compliance filings.

With regard to the SECA charges that had been invoiced to Green Mountain Energy, FERC determined that most of those charges, approximately $22 million plus interest, were owed not by Green Mountain Energy but rather by BP Energy  — one of Green Mountain Energy's suppliers during the period at issue. On August 19, 2010, the transmission owners and MISO made compliance filings in accordance with FERC's Orders allocating SECA charges to a BP Energy Sub-zone, and making no allocation to a Green Mountain Energy sub-zone. BP Energy has not asserted any contractual claims against Green Mountain Energy. The Company believes it has established an appropriate reserve.

On September 30, 2011, FERC issued orders denying BP Energy's request for rehearing of the May 2010 Order on Rehearing, denying all requests for rehearing of the Order on Initial Decision, and again determined that SECA charges were not owed by Green Mountain Energy. Numerous parties have sought judicial review of FERC's Order on Initial Decision, and BP Energy has sought judicial review of the May 2010 Order on Rehearing. These appeals have been consolidated with previous appeals of orders relating to the SECA before the U.S. Court of Appeals for the DC Circuit. Green Mountain Energy has been granted intervenor status in the consolidated appeals. A briefing schedule has not yet been set.

32

Note 16 — Environmental Matters 

NRG is subject to a wide range of environmental regulations across a broad number of jurisdictions in the development, ownership, construction and operation of domestic and international projects. These laws and regulations 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 will face new requirements to address air emissions, climate change, combustion byproducts and water use. In general, future laws and regulations are expected to require the addition of emission controls or other environmental quality equipment or the imposition of certain restrictions on the operations of the Company's facilities. NRG expects that future liability under, or compliance with, environmental requirements could have a material effect on the Company's operations or competitive position.

Environmental Capital Expenditures
 
Based on current rules, technology and plans as well as preliminary plans based on proposed rules, NRG has estimated that environmental capital expenditures from 2012 through 2016 to meet NRG's regulatory environmental commitments will be approximately $553 million. These costs are primarily associated with mercury controls to satisfy the Mercury and Air Toxics Standards, or MATS, on the Company's Big Cajun II, W.A. Parish and Limestone facilities and a number of intake modification projects across the fleet under state or proposed federal 316(b) rules. NRG continues to explore cost effective compliance alternatives to reduce costs. While this estimate reflects anticipated schedules and controls related to the proposed 316(b) Rule, the full impact on the scope and timing of environmental retrofits from any new or revised regulations cannot be determined until these rules are final and any legal challenges are reviewed. However, NRG believes it is positioned to meet more stringent environmental regulations through its planned capital expenditures, existing controls, and increasing generation from renewable resources.
 
NRG's current contracts with the Company's rural electric cooperative customers in the South Central region allow for recovery of a portion of the region's environmental capital costs incurred as the result of complying with any change in environmental law. Cost recoveries begin once the environmental equipment becomes operational and include a capital return. The actual recoveries will depend, among other things, on the timing of the completion of the capital projects and the remaining duration of the contracts.

Northeast Region
 
In January 2006, NRG's Indian River Operations, Inc. received a letter of informal notification from Delaware Department of Natural Resources and Environmental Control, or DNREC, stating that it may be a potentially responsible party with respect to Burton Island Old Ash Landfill, a historic captive landfill located at the Indian River facility. On October 1, 2007, NRG signed an agreement with DNREC to investigate the site through the Voluntary Clean-up Program. On February 4, 2008, DNREC issued findings that no further action is required in relation to surface water and that a previously planned shoreline stabilization project would satisfactorily address shoreline erosion. The landfill itself will require a further Remedial Investigation and Feasibility Study to determine the type and scope of any additional work required. Until the Remedial Investigation and Feasibility Study is approved, the Company is unable to predict the impact of any required remediation. On May 29, 2008, DNREC requested that NRG's Indian River Operations, Inc. participate in the development and performance of a Natural Resource Damage Assessment, or NRDA, at the Burton Island Old Ash Landfill. NRG is currently working with DNREC and other trustees to close out the assessment phase.
  
South Central Region
 
On February 11, 2009, the U.S. DOJ acting at the request of the U.S. EPA commenced a lawsuit against LaGen in federal district court in the Middle District of Louisiana alleging violations of the CAA at the Big Cajun II power plant. This is the same matter for which NOVs were issued to LaGen on February 15, 2005, and on December 8, 2006. Further discussion on this matter can be found in Note 14,  Commitments and Contingencies  -  Louisiana Generating, LLC.

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Note 17 — Condensed Consolidating Financial Information 

As of March 31, 2012, the Company had outstanding $6.1 billion of Senior Notes due from 2017 - 2021, as shown in Note 8,  Debt and Capital Leases . These Senior Notes are guaranteed by certain of NRG's current and future wholly-owned domestic subsidiaries, or guarantor subsidiaries. The non-guarantor subsidiaries include all of NRG's foreign subsidiaries and certain domestic subsidiaries.

Unless otherwise noted below, each of the following guarantor subsidiaries fully and unconditionally guaranteed the Senior Notes as of March 31, 2012:

Arthur Kill Power LLC	NEO Freehold-Gen LLC	NRG Power Marketing LLC	
Astoria Gas Turbine Power LLC	NEO Power Services Inc.	NRG Retail LLC	
Cabrillo Power I LLC	New Genco GP, LLC	NRG Rockford Acquisition LLC	
Cabrillo Power II LLC	Norwalk Power LLC	NRG Saguaro Operations Inc.	
Carbon Management Solutions LLC	NRG Affiliate Services Inc.	NRG Services Corporation	
Clean Edge Energy LLC	NRG Artesian Energy LLC	NRG Simply Smart Solutions LLC	
Conemaugh Power LLC	NRG Arthur Kill Operations Inc.	NRG South Central Affiliate Services Inc.	
Connecticut Jet Power LLC	NRG Astoria Gas Turbine Operations Inc.	NRG South Central Generating LLC	
Cottonwood Development LLC	NRG Bayou Cove LLC	NRG South Central Operations Inc.	
Cottonwood Energy Company LP	NRG Cabrillo Power Operations Inc.	NRG South Texas LP	
Cottonwood Generating Partners I LLC	NRG California Peaker Operations LLC	NRG Texas LLC	
Cottonwood Generating Partners II LLC	NRG Cedar Bayou Development Company, LLC	NRG Texas C&I Supply LLC	
Cottonwood Generating Partners III LLC	NRG Connecticut Affiliate Services Inc.	NRG Texas Holding Inc.	
Cottonwood Technology Partners LP	NRG Construction LLC	NRG Texas Power LLC	
Devon Power LLC	NRG Development Company Inc.	NRG West Coast LLC	
Dunkirk Power LLC	NRG Devon Operations Inc.	NRG Western Affiliate Services Inc.	
Eastern Sierra Energy Company	NRG Dunkirk Operations, Inc.	O'Brien Cogeneration, Inc. II	
El Segundo Power LLC	NRG El Segundo Operations Inc.	ONSITE Energy, Inc.	
El Segundo Power II, LLC	NRG Energy Labor Services LLC	Oswego Harbor Power LLC	
Elbow Creek Wind Project LLC	NRG Energy Services Group LLC	RE Retail Receivables LLC	
Energy Plus Holdings LLC	NRG Energy Services LLC	Reliant Energy Northeast LLC	
Energy Plus Natural Gas LLC	NRG Generation Holdings Inc.	Reliant Energy Power Supply LLC	
Energy Protection Insurance Company	NRG Huntley Operations Inc.	Reliant Energy Retail Holdings LLC	
Everything Energy LLC	NRG Ilion Limited Partnership	Reliant Energy Retail Services LLC	
GCP Funding Company, LLC	NRG Ilion LP LLC	RERH Holdings, LLC	
Green Mountain Energy Company	NRG International LLC	Saguaro Power LLC	
Huntley Power LLC	NRG Maintenance Services LLC	Somerset Operations Inc.	
Independence Energy Alliance LLC	NRG Mextrans Inc.	Somerset Power LLC	
Independence Energy Group LLC	NRG MidAtlantic Affiliate Services Inc.	Texas Genco Financing Corp.	
Independence Energy Natural Gas LLC	NRG Middletown Operations Inc.	Texas Genco GP, LLC	
Indian River Operations Inc.	NRG Montville Operations Inc.	Texas Genco Holdings, Inc.	
Indian River Power LLC	NRG New Jersey Energy Sales LLC	Texas Genco LP, LLC	
Keystone Power LLC	NRG New Roads Holdings LLC	Texas Genco Operating Services LLC	
Langford Wind Power, LLC	NRG North Central Operations Inc.	Texas Genco Services, LP	
Louisiana Generating LLC	NRG Northeast Affiliate Services Inc.	US Retailers LLC	
Meriden Gas Turbines LLC	NRG Norwalk Harbor Operations Inc.	Vienna Operations Inc.	
Middletown Power LLC	NRG Operating Services, Inc.	Vienna Power LLC	
Montville Power LLC	NRG Oswego Harbor Power Operations Inc.	WCP (Generation) Holdings LLC	
NEO Corporation	NRG PacGen Inc.	West Coast Power LLC	

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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. Except for NRG Bayou Cove, LLC, which is subject to certain restrictions under the Company's Peaker financing agreements, there are no restrictions on the ability of any of the guarantor subsidiaries to transfer funds to NRG. In addition, 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 Securities and Exchange Commission's 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.

35

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Three Months Ended March 31, 2012 

 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Guarantor Subsidiaries	 	Non-Guarantor Subsidiaries	 	NRG Energy, Inc.
(Note Issuer)	 	Eliminations(a)	 	Consolidated Balance	
 	(In millions)	
Operating Revenues	 	 	 	 	 	 	 	 	 	
Total operating revenues	$	1,778	
 	 	$	101	
 	 	$	—	
 	 	$	(17	)	 	$	1,862	
 	
Operating Costs and Expenses	 	 	 	 	 	 	 	 	 	
Cost of operations	1,522	
 	 	60	
 	 	6	
 	 	(15	)	 	1,573	
 	
Depreciation and amortization	214	
 	 	13	
 	 	3	
 	 	—	
 	 	230	
 	
Selling, general and administrative	132	
 	 	10	
 	 	81	
 	 	(2	)	 	221	
 	
Development costs	—	
 	 	—	
 	 	8	
 	 	—	
 	 	8	
 	
Total operating costs and expenses	1,868	
 	 	83	
 	 	98	
 	 	(17	)	 	2,032	
 	
Operating (Loss)/Income	(90	)	 	18	
 	 	(98	)	 	—	
 	 	(170	)	
Other Income/(Expense)	 	 	 	 	 	 	 	 	 	
Equity in earnings/(losses) of consolidated subsidiaries	6	
 	 	(2	)	 	(20	)	 	16	
 	 	—	
 	
Equity in (losses)/earnings of unconsolidated affiliates	(2	)	 	10	
 	 	—	
 	 	—	
 	 	8	
 	
Impairment charge on investment	(1	)	 	—	
 	 	—	
 	 	—	
 	 	(1	)	
Other income, net	—	
 	 	1	
 	 	1	
 	 	—	
 	 	2	
 	
Interest expense	(5	)	 	(14	)	 	(146	)	 	—	
 	 	(165	)	
Total other (expense)/income	(2	)	 	(5	)	 	(165	)	 	16	
 	 	(156	)	
(Loss)/Income Before Income Taxes	(92	)	 	13	
 	 	(263	)	 	16	
 	 	(326	)	
Income tax benefit	(28	)	 	(36	)	 	(56	)	 	—	
 	 	(120	)	
Net (Loss)/Income	(64	)	 	49	
 	 	(207	)	 	16	
 	 	(206	)	
Less: Net income attributable to noncontrolling interest	—	
 	 	1	
 	 	—	
 	 	—	
 	 	1	
 	
Net (Loss)/Income attributable to
NRG Energy, Inc.	$	(64	)	 	$	48	
 	 	$	(207	)	 	$	16	
 	 	$	(207	)	
 	 	
(a)	All significant intercompany transactions have been eliminated in consolidation.	

 	

36

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE (LOSS)/INCOME
For the Three Months Ended March 31, 2012 

 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Guarantor Subsidiaries	 	Non-Guarantor Subsidiaries	 	NRG Energy, Inc.
(Note Issuer)	 	Eliminations(a)	 	Consolidated Balance	
 	(In millions)	
Net (Loss)/ Income	$	(64	)	 	$	49	
 	 	$	(207	)	 	$	16	
 	 	$	(206	)	
Other comprehensive (loss)/income, net of tax	 	 	 	 	 	 	 	 	 	
Unrealized (loss)/gain on derivatives, net	(13	)	 	7	
 	 	(3	)	 	—	
 	 	(9	)	
Foreign currency translation adjustments, net	—	
 	 	6	
 	 	—	
 	 	—	
 	 	6	
 	
Other comprehensive (loss)/income	(13	)	 	13	
 	 	(3	)	 	—	
 	 	(3	)	
Comprehensive (loss)/income	(77	)	 	62	
 	 	(210	)	 	16	
 	 	(209	)	
Less: Comprehensive income attributable to noncontrolling interest	—	
 	 	1	
 	 	—	
 	 	—	
 	 	1	
 	
Comprehensive (loss)/income attributable to NRG Energy, Inc.	(77	)	 	61	
 	 	(210	)	 	16	
 	 	(210	)	
Dividends for preferred shares	—	
 	 	—	
 	 	2	
 	 	—	
 	 	2	
 	
Comprehensive (loss)/income available for common stockholders	$	(77	)	 	$	61	
 	 	$	(212	)	 	$	16	
 	 	$	(212	)	
 	 	
(a)	All significant intercompany transactions have been eliminated in consolidation.	

37

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEETS
March 31, 2012 

 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Guarantor Subsidiaries	 	Non-Guarantor Subsidiaries	 	NRG Energy, Inc.
(Note Issuer)	 	Eliminations(a)	 	Consolidated Balance	
 	(In millions)	
ASSETS	 	 	 	 	 	 	 	 	 	
Current Assets	 	 	 	 	 	 	 	 	 	
Cash and cash equivalents	$	53	
 	 	$	90	
 	 	$	871	
 	 	$	—	
 	 	$	1,014	
 	
Funds deposited by counterparties	199	
 	 	—	
 	 	—	
 	 	—	
 	 	199	
 	
Restricted cash	9	
 	 	179	
 	 	29	
 	 	—	
 	 	217	
 	
Accounts receivable, net	669	
 	 	47	
 	 	—	
 	 	—	
 	 	716	
 	
Inventory	383	
 	 	9	
 	 	—	
 	 	—	
 	 	392	
 	
Derivative instruments	5,150	
 	 	—	
 	 	—	
 	 	—	
 	 	5,150	
 	
Cash collateral paid in support of energy risk management activities	498	
 	 	—	
 	 	—	
 	 	—	
 	 	498	
 	
Prepayments and other current assets	137	
 	 	78	
 	 	57	
 	 	—	
 	 	272	
 	
Total current assets	7,098	
 	 	403	
 	 	957	
 	 	—	
 	 	8,458	
 	
Net property, plant and equipment	10,326	
 	 	3,992	
 	 	76	
 	 	(18	)	 	14,376	
 	
Other Assets	 	 	 	 	 	 	 	 	 	
Investment in subsidiaries	327	
 	 	119	
 	 	16,196	
 	 	(16,642	)	 	—	
 	
Equity investments in affiliates	31	
 	 	612	
 	 	—	
 	 	—	
 	 	643	
 	
Notes receivable – affiliate and capital leases, less current portion	1	
 	 	369	
 	 	167	
 	 	(167	)	 	370	
 	
Goodwill	1,886	
 	 	—	
 	 	—	
 	 	—	
 	 	1,886	
 	
Intangible assets, net	1,264	
 	 	84	
 	 	30	
 	 	(38	)	 	1,340	
 	
Nuclear decommissioning trust fund	456	
 	 	—	
 	 	—	
 	 	—	
 	 	456	
 	
Derivative instruments	649	
 	 	—	
 	 	—	
 	 	—	
 	 	649	
 	
Other non-current assets	59	
 	 	81	
 	 	212	
 	 	—	
 	 	352	
 	
Total other assets	4,673	
 	 	1,265	
 	 	16,605	
 	 	(16,847	)	 	5,696	
 	
Total Assets	$	22,097	
 	 	$	5,660	
 	 	$	17,638	
 	 	$	(16,865	)	 	$	28,530	
 	
LIABILITIES AND STOCKHOLDERS’ EQUITY	 	 	 	 	 	 	 	 	 	
Current Liabilities	 	 	 	 	 	 	 	 	 	
Current portion of long-term debt and capital leases	$	—	
 	 	$	56	
 	 	$	15	
 	 	$	—	
 	 	$	71	
 	
Accounts payable	(1,419	)	 	495	
 	 	2,004	
 	 	—	
 	 	1,080	
 	
Derivative instruments	4,780	
 	 	23	
 	 	21	
 	 	—	
 	 	4,824	
 	
Deferred income taxes	464	
 	 	(39	)	 	(333	)	 	—	
 	 	92	
 	
Cash collateral received in support of energy risk management activities	199	
 	 	—	
 	 	—	
 	 	—	
 	 	199	
 	
Accrued expenses and other current liabilities	392	
 	 	27	
 	 	200	
 	 	—	
 	 	619	
 	
Total current liabilities	4,416	
 	 	562	
 	 	1,907	
 	 	—	
 	 	6,885	
 	
Other Liabilities	 	 	 	 	 	 	 	 	 	
Long-term debt and capital leases	273	
 	 	2,394	
 	 	7,650	
 	 	(167	)	 	10,150	
 	
Nuclear decommissioning reserve	340	
 	 	—	
 	 	—	
 	 	—	
 	 	340	
 	
Nuclear decommissioning trust liability	279	
 	 	—	
 	 	—	
 	 	—	
 	 	279	
 	
Deferred income taxes	986	
 	 	231	
 	 	83	
 	 	—	
 	 	1,300	
 	
Derivative instruments	652	
 	 	56	
 	 	—	
 	 	—	
 	 	708	
 	
Out-of-market commodity contracts	201	
 	 	6	
 	 	—	
 	 	(31	)	 	176	
 	
Other non-current liabilities	553	
 	 	141	
 	 	116	
 	 	—	
 	 	810	
 	
Total non-current liabilities	3,284	
 	 	2,828	
 	 	7,849	
 	 	(198	)	 	13,763	
 	
Total liabilities	7,700	
 	 	3,390	
 	 	9,756	
 	 	(198	)	 	20,648	
 	
3.625% convertible perpetual preferred stock	—	
 	 	—	
 	 	249	
 	 	—	
 	 	249	
 	
Stockholders’ Equity	14,397	
 	 	2,270	
 	 	7,633	
 	 	(16,667	)	 	7,633	
 	
Total Liabilities and Stockholders’ Equity	$	22,097	
 	 	$	5,660	
 	 	$	17,638	
 	 	$	(16,865	)	 	$	28,530	

(a)	All significant intercompany transactions have been eliminated in consolidation.	

38

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2012

 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Guarantor Subsidiaries	 	Non-Guarantor Subsidiaries	 	NRG Energy, Inc.
(Note Issuer)	 	Eliminations(a)	 	Consolidated Balance	
 	(In millions)	
Cash Flows from Operating Activities	 	 	 	 	 	 	 	 	 	
Net (loss)/income	$	(64	)	 	$	49	
 	 	$	(207	)	 	$	16	
 	 	$	(206	)	
Adjustments to reconcile net (loss)/income to net cash provided/(used) by operating activities:	 	 	 	 	 	 	 	 	 	
Distributions and equity in losses/(earnings) of unconsolidated affiliates and consolidated subsidiaries	9	
 	 	(5	)	 	(17	)	 	13	
 	 	—	
 	
Depreciation and amortization	214	
 	 	13	
 	 	3	
 	 	—	
 	 	230	
 	
Provision for bad debts	7	
 	 	—	
 	 	—	
 	 	—	
 	 	7	
 	
Amortization of nuclear fuel	6	
 	 	—	
 	 	—	
 	 	—	
 	 	6	
 	
Amortization of financing costs and debt discount/premiums	—	
 	 	2	
 	 	6	
 	 	—	
 	 	8	
 	
Amortization of intangibles and out-of-market commodity contracts	42	
 	 	—	
 	 	—	
 	 	—	
 	 	42	
 	
Changes in deferred income taxes and liability for uncertain tax benefits	(29	)	 	(44	)	 	(56	)	 	—	
 	 	(129	)	
Changes in nuclear decommissioning trust liability	8	
 	 	—	
 	 	—	
 	 	—	
 	 	8	
 	
Changes in derivative instruments	186	
 	 	—	
 	 	1	
 	 	—	
 	 	187	
 	
Changes in collateral deposits supporting energy risk management activities	(187	)	 	—	
 	 	—	
 	 	—	
 	 	(187	)	
Cash provided/(used) by changes in other working capital	104	
 	 	33	
 	 	(147	)	 	(32	)	 	(42	)	
Net Cash Provided/(Used) by Operating Activities	296	
 	 	48	
 	 	(417	)	 	(3	)	 	(76	)	
Cash Flows from Investing Activities	 	 	 	 	 	 	 	 	 	
Intercompany loans to subsidiaries	(201	)	 	—	
 	 	108	
 	 	93	
 	 	—	
 	
Capital expenditures	(69	)	 	(554	)	 	(16	)	 	—	
 	 	(639	)	
Increase in restricted cash, net	(1	)	 	(19	)	 	—	
 	 	—	
 	 	(20	)	
Decrease in restricted cash - U.S. DOE projects	—	
 	 	71	
 	 	24	
 	 	—	
 	 	95	
 	
Increase in notes receivable	—	
 	 	(7	)	 	—	
 	 	—	
 	 	(7	)	
Investments in nuclear decommissioning trust fund securities	(126	)	 	—	
 	 	—	
 	 	—	
 	 	(126	)	
Proceeds from sales of nuclear decommissioning trust fund securities	119	
 	 	—	
 	 	—	
 	 	—	
 	 	119	
 	
Proceeds from renewable energy grants	—	
 	 	28	
 	 	—	
 	 	—	
 	 	28	
 	
Other	2	
 	 	4	
 	 	1	
 	 	—	
 	 	7	
 	
Net Cash (Used)/Provided by Investing Activities	(276	)	 	(477	)	 	117	
 	 	93	
 	 	(543	)	
Cash Flows from Financing Activities	 	 	 	 	 	 	 	 	 	
Proceeds from intercompany loans	—	
 	 	(108	)	 	201	
 	 	(93	)	 	—	
 	
Payment of dividends to preferred stockholders	—	
 	 	—	
 	 	(2	)	 	—	
 	 	(2	)	
Payments of intercompany dividends	—	
 	 	(3	)	 	—	
 	 	3	
 	 	—	
 	
Net payments for settlement of acquired derivatives that include financing elements	(20	)	 	—	
 	 	—	
 	 	—	
 	 	(20	)	
Proceeds from issuance of long-term debt	9	
 	 	406	
 	 	—	
 	 	—	
 	 	415	
 	
Sale proceeds and other contributions from noncontrolling interest in subsidiaries	—	
 	 	178	
 	 	—	
 	 	—	
 	 	178	
 	
Payment of debt issuance costs	—	
 	 	(10	)	 	—	
 	 	—	
 	 	(10	)	
Payments for short and long-term debt	—	
 	 	(30	)	 	(4	)	 	—	
 	 	(34	)	
Net Cash (Used)/Provided by Financing Activities	(11	)	 	433	
 	 	195	
 	 	(90	)	 	527	
 	
Effect of exchange rate changes on cash and cash equivalents	—	
 	 	1	
 	 	—	
 	 	—	
 	 	1	
 	
Net Increase/(Decrease) in Cash and Cash Equivalents	9	
 	 	5	
 	 	(105	)	 	—	
 	 	(91	)	
Cash and Cash Equivalents at Beginning of Period	44	
 	 	85	
 	 	976	
 	 	—	
 	 	1,105	
 	
Cash and Cash Equivalents at End of Period	$	53	
 	 	$	90	
 	 	$	871	
 	 	$	—	
 	 	$	1,014	

(a)	All significant intercompany transactions have been eliminated in consolidation.	

39

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
For the Three Months Ended March 31, 2011 

 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Guarantor Subsidiaries	 	Non-Guarantor Subsidiaries	 	NRG Energy, Inc.
(Note Issuer)	 	Eliminations(a)	 	Consolidated Balance	
 	(In millions)	
Operating Revenues	 	 	 	 	 	 	 	 	 	
Total operating revenues	$	1,904	
 	 	$	104	
 	 	$	—	
 	 	$	(13	)	 	$	1,995	
 	
Operating Costs and Expenses	 	 	 	 	 	 	 	 	 	
Cost of operations	1,253	
 	 	72	
 	 	5	
 	 	(6	)	 	1,324	
 	
Depreciation and amortization	192	
 	 	10	
 	 	3	
 	 	—	
 	 	205	
 	
Selling, general and administrative	81	
 	 	5	
 	 	57	
 	 	—	
 	 	143	
 	
Development costs	—	
 	 	(1	)	
 	10	
 	 	—	
 	 	9	
 	
Total operating costs and expenses	1,526	
 	 	86	
 	 	75	
 	 	(6	)	 	1,681	
 	
Operating Income/(Loss)	378	
 	 	18	
 	 	(75	)	 	(7	)	 	314	
 	
Other Income/(Expense)	 	 	 	 	 	 	 	 	 	
Equity in earnings of consolidated subsidiaries	9	
 	 	(1	)	 	(78	)	 	70	
 	 	—	
 	
Equity in losses of unconsolidated affiliates	—	
 	 	(2	)	 	—	
 	 	—	
 	 	(2	)	
Impairment charge on investment	(481	)	 	—	
 	 	—	
 	 	—	
 	 	(481	)	
Other income, net	—	
 	 	4	
 	 	1	
 	 	—	
 	 	5	
 	
Loss on debt extinguishment	—	
 	 	—	
 	 	(28	)	 	—	
 	 	(28	)	
Interest expense	(9	)	 	(13	)	 	(151	)	 	—	
 	 	(173	)	
Total other (expense)/income	(481	)	 	(12	)	 	(256	)	 	70	
 	 	(679	)	
(Loss)/Income Before Income Taxes	(103	)	 	6	
 	 	(331	)	 	63	
 	 	(365	)	
Income tax (benefit)/expense	(36	)	 	2	
 	 	(71	)	 	—	
 	 	(105	)	
Net (Loss)/Income attributable to NRG Energy, Inc.	$	(67	)	 	$	4	
 	 	$	(260	)	 	$	63	
 	 	$	(260	)	
 	 	
(a)	All significant intercompany transactions have been eliminated in consolidation.	

 	

40

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE (LOSS)/INCOME
For the Three Months Ended March 31, 2011 

 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Guarantor Subsidiaries	 	Non-Guarantor Subsidiaries	 	NRG Energy, Inc.
(Note Issuer)	 	Eliminations(a)	 	Consolidated Balance	
 	(In millions)	
Net (Loss)/Income	$	(67	)	 	$	4	
 	 	$	(260	)	 	$	63	
 	 	$	(260	)	
Other comprehensive (loss)/income, net of tax	 	 	 	 	 	 	 	 	 	
Unrealized (loss)/gain on derivatives, net	(86	)	 	3	
 	 	(69	)	 	70	
 	 	(82	)	
Foreign currency translation adjustments, net	—	
 	 	12	
 	 	—	
 	 	—	
 	 	12	
 	
Defined benefit plan	1	
 	 	—	
 	 	—	
 	 	—	
 	 	1	
 	
Other comprehensive (loss)/income	(85	)	 	15	
 	 	(69	)	 	70	
 	 	(69	)	
Comprehensive (loss)/income attributable to NRG Energy, Inc.	(152	)	 	19	
 	 	(329	)	 	133	
 	 	(329	)	
Dividends for preferred shares	—	
 	 	—	
 	 	2	
 	 	—	
 	 	2	
 	
Comprehensive (loss)/income available for common stockholders	$	(152	)	 	$	19	
 	 	$	(331	)	 	$	133	
 	 	$	(331	)	
 	 	
(a)	All significant intercompany transactions have been eliminated in consolidation.	

41

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEETS
December 31, 2011 

 	Guarantor Subsidiaries	 	Non-Guarantor Subsidiaries	 	NRG Energy, Inc.
(Note Issuer)	 	Eliminations(a)	 	Consolidated Balance	
 	(In millions)	
ASSETS	 	 	 	 	 	 	 	 	 	
Current Assets	 	 	 	 	 	 	 	 	 	
Cash and cash equivalents	$	44	
 	 	$	85	
 	 	$	976	
 	 	$	—	
 	 	$	1,105	
 	
Funds deposited by counterparties	258	
 	 	—	
 	 	—	
 	 	—	
 	 	258	
 	
Restricted cash	8	
 	 	231	
 	 	53	
 	 	—	
 	 	292	
 	
Accounts receivable-trade, net	789	
 	 	45	
 	 	—	
 	 	—	
 	 	834	
 	
Inventory	300	
 	 	8	
 	 	—	
 	 	—	
 	 	308	
 	
Derivative instruments	4,222	
 	 	—	
 	 	—	
 	 	(6	)	 	4,216	
 	
Cash collateral paid in support of energy risk management activities	311	
 	 	—	
 	 	—	
 	 	—	
 	 	311	
 	
Prepayments and other current assets	1,229	
 	 	28	
 	 	(983	)	 	(1	)	 	273	
 	
Total current assets	7,161	
 	 	397	
 	 	46	
 	 	(7	)	 	7,597	
 	
Net Property, Plant and Equipment	10,456	
 	 	3,116	
 	 	67	
 	 	(18	)	 	13,621	
 	
Other Assets	 	 	 	 	 	 	 	 	 	
Investment in subsidiaries	225	
 	 	491	
 	 	16,169	
 	 	(16,885	)	 	—	
 	
Equity investments in affiliates	33	
 	 	607	
 	 	—	
 	 	—	
 	 	640	
 	
Capital leases and notes receivable, less current portion	1	
 	 	341	
 	 	172	
 	 	(172	)	 	342	
 	
Goodwill	1,886	
 	 	—	
 	 	—	
 	 	—	
 	 	1,886	
 	
Intangible assets, net	1,340	
 	 	84	
 	 	33	
 	 	(38	)	 	1,419	
 	
Nuclear decommissioning trust fund	424	
 	 	—	
 	 	—	
 	 	—	
 	 	424	
 	
Derivative instruments	450	
 	 	—	
 	 	—	
 	 	—	
 	 	450	
 	
Other non-current assets	55	
 	 	72	
 	 	209	
 	 	—	
 	 	336	
 	
Total other assets	4,414	
 	 	1,595	
 	 	16,583	
 	 	(17,095	)	 	5,497	
 	
Total Assets	$	22,031	
 	 	$	5,108	
 	 	$	16,696	
 	 	$	(17,120	)	 	$	26,715	
 	
LIABILITIES AND STOCKHOLDERS’ EQUITY	 	 	 	 	 	 	 	 	 	
Current Liabilities	 	 	 	 	 	 	 	 	 	
Current portion of long-term debt and capital leases	$	—	
 	 	$	72	
 	 	$	15	
 	 	$	—	
 	 	$	87	
 	
Accounts payable	(407	)	 	122	
 	 	1,093	
 	 	—	
 	 	808	
 	
Derivative instruments	3,712	
 	 	23	
 	 	22	
 	 	(6	)	 	3,751	
 	
Deferred income taxes	534	
 	 	(51	)	 	(356	)	 	—	
 	 	127	
 	
Cash collateral received in support of energy risk management activities	258	
 	 	—	
 	 	—	
 	 	—	
 	 	258	
 	
Accrued expenses and other current liabilities	371	
 	 	23	
 	 	247	
 	 	(1	)	 	640	
 	
Total current liabilities	4,468	
 	 	189	
 	 	1,021	
 	 	(7	)	 	5,671	
 	
Other Liabilities	 	 	 	 	 	 	 	 	 	
Long-term debt and capital leases	264	
 	 	1,999	
 	 	7,654	
 	 	(172	)	 	9,745	
 	
Nuclear decommissioning reserve	335	
 	 	—	
 	 	—	
 	 	—	
 	 	335	
 	
Nuclear decommissioning trust liability	254	
 	 	—	
 	 	—	
 	 	—	
 	 	254	
 	
Deferred income taxes	950	
 	 	273	
 	 	166	
 	 	—	
 	 	1,389	
 	
Derivative instruments	394	
 	 	66	
 	 	4	
 	 	—	
 	 	464	
 	
Out-of-market commodity contracts	208	
 	 	6	
 	 	—	
 	 	(31	)	 	183	
 	
Other non-current liabilities	544	
 	 	96	
 	 	116	
 	 	—	
 	 	756	
 	
Total non-current liabilities	2,949	
 	 	2,440	
 	 	7,940	
 	 	(203	)	 	13,126	
 	
Total liabilities	7,417	
 	 	2,629	
 	 	8,961	
 	 	(210	)	 	18,797	
 	
3.625% Preferred Stock	—	
 	 	—	
 	 	249	
 	 	—	
 	 	249	
 	
Stockholders’ Equity	14,614	
 	 	2,479	
 	 	7,486	
 	 	(16,910	)	 	7,669	
 	
Total Liabilities and Stockholders’ Equity	$	22,031	
 	 	$	5,108	
 	 	$	16,696	
 	 	$	(17,120	)	 	$	26,715	

(a)	All significant intercompany transactions have been eliminated in consolidation.	

42

NRG ENERGY, INC. AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
For the Three Months Ended March 31, 2011 

 	Guarantor Subsidiaries	 	Non-Guarantor Subsidiaries	 	NRG Energy, Inc.
(Note Issuer)	 	Eliminations(a)	 	Consolidated Balance	
 	(In millions)	
Cash Flows from Operating Activities	 	 	 	 	 	 	 	 	 	
Net (loss)/income	$	(67	)	 	$	4	
 	 	$	(260	)	 	$	63	
 	 	$	(260	)	
Adjustments to reconcile net (loss)/income to net cash provided/(used) by operating activities:	 	 	 	 	 	 	 	 	 	
Distributions and equity in (earnings)/losses of unconsolidated affiliates and consolidated subsidiaries	(9	)	 	10	
 	 	78	
 	 	(70	)	 	9	
 	
Depreciation and amortization	192	
 	 	10	
 	 	3	
 	 	—	
 	 	205	
 	
Provision for bad debts	8	
 	 	—	
 	 	—	
 	 	—	
 	 	8	
 	
Amortization of nuclear fuel	11	
 	 	—	
 	 	—	
 	 	—	
 	 	11	
 	
Amortization of financing costs and debt discount/premiums	—	
 	 	1	
 	 	7	
 	 	—	
 	 	8	
 	
Amortization of intangibles and out-of market commodity contracts	48	
 	 	—	
 	 	—	
 	 	—	
 	 	48	
 	
Changes in deferred income taxes and liability for uncertain tax benefits	(145	)	 	(14	)	 	50	
 	 	—	
 	 	(109	)	
Changes in nuclear decommissioning trust liability	10	
 	 	—	
 	 	—	
 	 	—	
 	 	10	
 	
Changes in derivative instruments	(130	)	 	—	
 	 	—	
 	 	—	
 	 	(130	)	
Changes in collateral deposits supporting energy risk management activities	176	
 	 	—	
 	 	—	
 	 	—	
 	 	176	
 	
Impairment charge on investment	481	
 	 	—	
 	 	—	
 	 	—	
 	 	481	
 	
Cash provided/(used) by changes in other working capital	46	
 	 	2	
 	 	(296	)	 	7	
 	 	(241	)	
Net Cash Provided/(Used) by Operating Activities	621	
 	 	13	
 	 	(418	)	 	—	
 	 	216	
 	
Cash Flows from Investing Activities	 	 	 	 	 	 	 	 	 	
Intercompany loans to subsidiaries	(705	)	 	(13	)	 	(158	)	 	876	
 	 	—	
 	
Capital expenditures	(86	)	 	(115	)	 	(18	)	 	—	
 	 	(219	)	
Increase in restricted cash, net	—	
 	 	(5	)	 	—	
 	 	—	
 	 	(5	)	
Decrease in notes receivable	—	
 	 	12	
 	 	—	
 	 	—	
 	 	12	
 	
Investments in nuclear decommissioning trust fund securities	(105	)	 	—	
 	 	—	
 	 	—	
 	 	(105	)	
Proceeds from sales of nuclear decommissioning trust fund securities	95	
 	 	—	
 	 	—	
 	 	—	
 	 	95	
 	
Other	9	
 	 	(5	)	 	(10	)	 	—	
 	 	(6	)	
Net Cash (Used)/Provided by Investing Activities	(792	)	 	(126	)	 	(186	)	 	876	
 	 	(228	)	
Cash Flows from Financing Activities	 	 	 	 	 	 	 	 	 	
Proceeds from intercompany loans	38	
 	 	120	
 	 	718	
 	 	(876	)	 	—	
 	
Payment of dividends to preferred stockholders	—	
 	 	—	
 	 	(2	)	 	—	
 	 	(2	)	
Payment for treasury stock	—	
 	 	—	
 	 	(130	)	 	—	
 	 	(130	)	
Net payment for settlement of acquired derivatives that include financing elements	(17	)	 	—	
 	 	—	
 	 	—	
 	 	(17	)	
Proceeds from issuance of long-term debt	66	
 	 	20	
 	 	1,200	
 	 	—	
 	 	1,286	
 	
Payment of debt issuance and hedging costs	—	
 	 	(2	)	 	(6	)	 	—	
 	 	(8	)	
Payments for short and long-term debt	—	
 	 	(6	)	 	(1,355	)	 	—	
 	 	(1,361	)	
Other	—	
 	 	(1	)	 	1	
 	 	—	
 	 	—	
 	
Net Cash Provided/(Used) by Financing Activities	87	
 	 	131	
 	 	426	
 	 	(876	)	 	(232	)	
Effect of exchange rate changes on cash and cash equivalents	—	
 	 	4	
 	 	—	
 	 	—	
 	 	4	
 	
Net (Decrease)/Increase in Cash and Cash Equivalents	(84	)	 	22	
 	 	(178	)	 	—	
 	 	(240	)	
Cash and Cash Equivalents at Beginning of Period	168	
 	 	111	
 	 	2,672	
 	 	—	
 	 	2,951	
 	
Cash and Cash Equivalents at End of Period	$	84	
 	 	$	133	
 	 	$	2,494	
 	 	$	—	
 	 	$	2,711	

(a)	All significant intercompany transactions have been eliminated in consolidation.	

43

ITEM 2 — MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
As you read this discussion and analysis, refer to NRG's Condensed Consolidated Statements of Operations to this Form 10-Q, which present the results of operations for the three months ended March 31, 2012, and 2011. Also refer to NRG's Annual Report on Form 10-K for the year ended December 31, 2011, or 2011 Form 10-K, which includes detailed discussions of various items impacting the Company's business, results of operations and financial condition, including: Introduction and Overview section which provides a description of NRG's business segments; Strategy section; Business Environment section, including how regulation, weather, and other factors affect NRG's business; and Critical Accounting Policies and Estimates section. As described in Note 12,  Segment Reporting , NRG updated its segment structure to reflect how management currently makes its financial decisions and allocates resources, based on the Retail businesses, conventional power generation, alternative energy businesses and corporate activities.
The discussion and analysis below has been organized as follows:
 	 	
•	Executive summary, including introduction and overview, business strategy, and changes to the business environment during the period including regulatory and environmental matters;	
 	 	
•	Results of operations;	
 	 	
•	Financial condition, addressing liquidity position, sources and uses of liquidity, capital resources and requirements, commitments, and off-balance sheet arrangements; and	
 	 	
•	Known trends that may affect NRG’s results of operations and financial condition in the future.	

44

Executive Summary

Introduction and Overview

NRG Energy, Inc., or NRG or the Company, is an integrated wholesale power generation and retail electricity company that aspires to be a leader in the way the industry and consumers think about, use, produce and deliver energy and energy services in major competitive power markets in the United States. First, NRG is a wholesale power generator engaged in the ownership and operation of power generation facilities; the trading of energy, capacity and related products; and the transacting in and trading of fuel and transportation services. Second, NRG is a retail electricity company engaged in the supply of electricity, energy services, and cleaner energy products to retail electricity customers in deregulated markets through its Retail businesses. Finally, NRG is focused on the deployment and commercialization of potential disruptive technologies, like electric vehicles, Distributed Solar and smart meter technology, which have the potential to change the nature of the power supply industry.

NRG's Business Strategy

NRG's business strategy is intended to maximize stockholder value through the production and sale of safe, reliable and affordable power to its customers in the markets served by the Company, while aggressively positioning the Company to meet the market's increasing demand for sustainable and low carbon energy solutions. This strategy is designed to enhance the Company's core business of competitive power generation and mitigate the risk of declining power prices. The Company expects to become a leading provider of sustainable energy solutions that promotes national energy security, while utilizing the Company's Retail businesses to complement and advance both initiatives.

The Company's core business is focused on: (i) excellence in safety and operating performance of its existing assets; (ii) serving the energy needs of end-use residential, commercial and industrial customers in the Company's core markets with a retail energy product that is differentiated either by premium service (Reliant), sustainability (Green Mountain Energy) or loyalty/affinity programs (Energy Plus); (iii) optimal hedging of baseload generation and retail load operations, while retaining optionality on the Company's peaking facilities; (iv) repowering of power generation assets at premium sites; (v) investment in, and deployment of, alternative energy technologies both in its wholesale and, particularly, in and around its Retail businesses and their customers; (vi) pursuing selective acquisitions, joint ventures, divestitures and investments; and (vii) engaging in a proactive capital allocation plan focused on achieving the regular return of and on stockholder capital within the dictates of prudent balance sheet management.

Moreover, the Company believes that the American energy industry is going to be increasingly impacted by the long-term societal trend towards sustainability which is both generational and irreversible. This trend is further influenced by the information technology-driven revolution, which has enabled greater and easier personal choice in other sectors of the consumer economy and will do the same in the American energy sector over the years to come. As a result, energy consumers will have increasing personal control over from whom they buy their energy, how that energy is generated and used and what environmental impact these individual choices will have. The Company's initiatives in this area of future growth are focused on: (i) renewables, with a concentration in solar development; (ii) electric vehicle ecosystems; (iii) customer-facing energy products and services including smart grid services, nationwide retail green electricity, unique retail sales channels involving loyalty and affinity programs and custom design; and (iv) the construction of other forms of on-site clean power generation. The Company's advances in each of these areas are driven by select acquisitions, joint ventures, and investments that are more fully described in Item 1,  Business - New and On-going Company Initiatives and Development Projects  of the Company's 2011 Form 10-K, and this Form 10-Q.

45

Environmental Matters

Environmental Regulatory Landscape

In 2011, a number of U.S. EPA air regulations were finalized providing more clarity to the impact on electric generating units. A number of regulations with the potential for impact are still in development or under review by the U.S. EPA: New Source Performance Standards, or NSPS, for Greenhouse Gases, or GHGs, National Ambient Air Quality Standards, or NAAQS, revisions, coal combustion byproducts, and once-through cooling. While most of these regulations have been considered for some time, the outcomes and any resulting impact on NRG cannot be fully predicted until the rules are finalized. The timing and stringency of these regulations will contribute to a framework for the retrofit of existing fossil plants and deployment of new, cleaner technologies in the next decade. See discussion below for more detail.

Air — The U.S. EPA released the Cross-State Air Pollution Rule, or CSAPR, on July 7, 2011, with additional proposed updates on October 6, 2011. CSAPR was scheduled to replace the Clean Air Interstate Rule, or CAIR, on January 1, 2012. It was designed to bring states into attainment with PM 2.5 and ozone NAAQS, reducing SO 2  and NO x  emissions from power plants. The U.S. Court of Appeals for the District of Columbia Circuit stayed the rule on December 30, 2011, pending resolution of the numerous petitions for judicial review and leaving CAIR in effect during the stay. On February 8, 2012, the U.S. EPA finalized the incremental state allowance budgets and resulting company allocations proposed in October 2011 and added additional allowance in certain states under the Direct Final Rule. NRG benefited from both rounds of allocation increases. The Company is unable to predict the final outcome of the court proceeding. There is no material impact to NRG related to the stay.

On February 16, 2012, the U.S. EPA finalized MATS, to control emissions of hazardous air pollutants from coal and oil fired electric generating units. Requirements include meeting the standards for mercury, acid gases, and certain metals (such as particulate matter) by April 16, 2015 on a plantwide basis with the potential for a one year extension. NRG does not anticipate any plant impairments or capital expenditures beyond the current environmental capital expenditures schedule.

On March 8, the EPA affirmed the continued use of modified trigger levels through 2016 for GHG emissions in the Tailoring Rule. This rule maintains the current level at which projects must be permitted. While most repowering projects still trigger the permitting, the higher limit provides relief to smaller projects like the installation of back-end controls to meet other regulations.

The U.S. EPA published the proposed New Source Performance Standards, or NSPS, for GHGs on April 13, 2012. The new standard, 1,000 tons of CO 2  per MWh gross, applies only to new electric generating units greater than 25 MW and provides averaging options for new units expected to install carbon capture. An exclusion for existing units minimizes the impact to NRG's coal plants.

Regulatory Matters

As operators of power plants and participants in wholesale and retail energy markets, certain NRG entities are subject to regulation by various federal and state government agencies. These include the Commodities Futures Trading Commission, or CFTC, FERC, Nuclear Regulatory Commission, or NRC, and PUCT, as well as other public utility commissions in certain states where NRG's generating, thermal, or distributed generation assets are located. In addition, NRG is subject to the market rules, procedures and protocols of the various ISO markets in which it participates. Likewise, certain NRG entities participating in the retail markets are subject to rules and regulations established by the states in which NRG entities are licensed to sell at retail. NRG must also comply with the mandatory reliability requirements imposed by the North American Electric Reliability Corporation, or NERC, and the regional reliability entities in the regions where the Company operates.

NRG's operations within the ERCOT footprint are not subject to rate regulation by the FERC, as they are deemed to operate solely within the ERCOT market and not in interstate commerce. These operations are subject to regulation by PUCT, as well as to regulation by the NRC with respect to the Company's ownership interest in STP.

Texas Region

NRC Task Force Report — On March 11, 2012, the NRC issued Tier 1 requirements in response to the Near-Term Task Force report. Specifically, the NRC issued rules governing installation of spent fuel pool instrumentation and established mitigation strategies for beyond-design-basis external events. Additionally, the NRC issued requests for information regarding the re-evaluation of seismic and flooding hazards and the development of staffing strategies necessary for responding to an extended station blackout multi-unit event. The Company anticipates being able to comply in a timely manner with all announced new requirements.

46

ERCOT System-Wide Offer Caps — On April 12, 2012, the PUCT issued two proposed rulemakings relating to resource adequacy concerns. The first rulemaking proposes to raise the current ERCOT system-wide energy and ancillary service offer cap from $3,000 to $4,500/MWh beginning August 1, 2012. The second rulemaking proposes to raise the system-wide offer cap on June 1, 2013 to $5,000/MWh, escalating to $9,000/MWh on June 1, 2015. The ERCOT ISO is expected to shift the Power Balance Penalty Curve, or PBPC, to match these offer cap levels. An increase in the system-wide offer cap could have a material impact on NRG's retail and wholesale operations. Over the past several months, at the urging of the PUCT, the ERCOT ISO has implemented a number of measures intended to ensure that prompt energy prices accurately reflect supply scarcity conditions, such as requiring energy from reliability services (such as responsive reserves and reliability unit commitments) be offered at the system-wide offer cap, implementing floor prices during the deployment of non-spinning reserve services, and shifting 500 MWs of non-spinning reserves to responsive reserves procurement by the ISO.

Northeast Region

New England — On January 19, 2012, FERC issued an order largely denying rehearing of its prior decision addressing proposed amendments submitted by ISO New England Inc., or ISO-NE, to its Forward Capacity Market, or FCM, design, as well as two pending complaints. On March 16, 2012, the Company and other generators with interests in New England appealed FERC's decision to the DC Circuit Court of Appeals.

New York
New Financial Reporting Rules in New York —On March 23, 2012, the New York Public Service Commission, or NYPSC, issued an order addressing its policy of applying “lightened” regulation to wholesale generators. The order proposed to subject wholesale generators, which would include NRG entities operating in New York, to more stringent financial reporting rules, including a requirement for generators to make an annual submission of “receipts and expenditures” to the NYPSC. Comments on the proposed financial reporting forms are due to the NYPSC by May 29, 2012.

Dunkirk Power LLC Mothball Notice —On March 14, 2012, Dunkirk Power LLC filed a notice with the New York Department of Public Service, or DPS, of its intent to mothball the Dunkirk facility no later than September 10, 2012.  The effects of the mothball on electric system reliability will be reviewed by the DPS.  The Company expects that the proposed mothball may have a negative impact on the reliability of the New York transmission system and that portions of the Dunkirk facility may be retained for reliability purposes via a non-market compensation arrangement. 

CFTC — Dodd-Frank Act Developments

On April 27, 2012, the CFTC published its final rules for the definitions of “swap dealer,” “major swap participant” and “eligible contract participant” and for commodity options under the Dodd-Frank Wall Street Reform and Consumer Protection Act.  The Company is reviewing these rules and evaluating whether any of them may apply to its business.

Changes in Accounting Standards

See Note 2, Summary of Significant Accounting Policies, to this Form 10-Q as found in Item 1 for a discussion of recent accounting developments.

47

Consolidated Results of Operations
The following table provides selected financial information for the Company:

 	Three months ended March 31,	
(In millions except otherwise noted)	2012	 	2011	 	Change %	
Operating Revenues	 	 	 	 	 	
Energy revenue (a)	$	434	
 	 	$	598	
 	 	(27	)%	
Capacity revenue (a)	174	
 	 	185	
 	 	(6	)	
Retail revenue	1,196	
 	 	1,180	
 	 	1	
 	
Mark-to-market for economic hedging activities	40	
 	 	(1	)	 	N/A	
 	
Contract amortization	(31	)	 	(47	)	 	34	
 	
Other revenues (b)	49	
 	 	80	
 	 	(39	)	
Total operating revenues	1,862	
 	 	1,995	
 	 	(7	)	
Operating Costs and Expenses	 	 	 	 	 	
Generation cost of sales (a)	448	
 	 	556	
 	 	(19	)	
Retail cost of sales (a)	608	
 	 	609	
 	 	—	
 	
Mark-to-market for economic hedging activities	205	
 	 	(134	)	 	(253	)	
Contract and emissions credit amortization (c)	7	
 	 	10	
 	 	(30	)	
Other cost of operations	305	
 	 	283	
 	 	8	
 	
Total cost of operations	1,573	
 	 	1,324	
 	 	19	
 	
Depreciation and amortization	230	
 	 	205	
 	 	12	
 	
Selling, general and administrative	221	
 	 	143	
 	 	55	
 	
Development costs	8	
 	 	9	
 	 	(11	)	
Total operating costs and expenses	2,032	
 	 	1,681	
 	 	21	
 	
Operating (Loss)/Income	(170	)	 	314	
 	 	(154	)	
Other Income/(Expense)	 	 	 	 	 	
Equity in earnings/(losses) of unconsolidated affiliates	8	
 	 	(2	)	 	N/A	
 	
Impairment charge on investment	(1	)	 	(481	)	 	(100	)	
Other income, net	2	
 	 	5	
 	 	(60	)	
Loss on debt extinguishment	—	
 	 	(28	)	 	(100	)	
Interest expense	(165	)	 	(173	)	 	(5	)	
Total other expense	(156	)	 	(679	)	 	(77	)	
Loss before income tax expense	(326	)	 	(365	)	 	(11	)	
Income tax benefit	(120	)	 	(105	)	 	14	
 	
Net Loss	(206	)	 	(260	)	 	(21	)	
Less: Net income attributable to noncontrolling interest	1	
 	 	—	
 	 	100	
 	
Net Loss Attributable to NRG Energy, Inc.	$	(207	)	 	$	(260	)	 	(20	)	
Business Metrics	 	 	 	 	 	
Average natural gas price — Henry Hub ($/MMBtu)	2.74	
 	 	4.11	
 	 	(33	)%	
 	 	
(a)	Includes realized gains and losses from financially settled transactions.	
 	 	
(b)	Includes unrealized trading gains and losses.	
 	 	
(c)	Includes amortization of SO2  and NOx credits and excludes amortization of Regional Greenhouse Gas Initiative, or RGGI, credits.	
N/A - Not Applicable

48

Management’s discussion of the results of operations for the three months ended March 31, 2012, and 2011

Loss before income tax expense —The pre-tax loss of $326 million for the three months ended March 31, 2012, compared to a pre-tax loss of $365 million for the three months ended March 31, 2011, primarily reflects:
 	 	
•	in the current year, a decrease in operating income of $484 million as compared to the prior year period, which reflects:	

◦	a decrease in net mark-to-market for economic hedging activities of $298 million and	

◦	a $72 million decrease in Conventional Generation gross margin driven primarily by planned and unplanned outages as well as coal to gas switching and increased operating costs;	

•	offset in the prior year by:	

◦a $481 million loss on the impairment of NRG's investment in NINA, and

◦a $28 million loss on the extinguishment of the 2014 Senior Notes.
   
Net loss — The decrease in net loss of $54 million primarily reflects the drivers discussed above offset by an income tax benefit for the three months ended March 31, 2012, of $120 million, compared with an income tax benefit of $105 million in the comparable period.

Conventional Generation gross margin

The following is a discussion of gross margin for NRG's Conventional Generation businesses, adjusted to eliminate intersegment activity, primarily with the Retail businesses.

 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Three months ended March 31, 2012	
 	Conventional Generation	 	 	 	 	 	 	 	 	
(In millions except otherwise noted)	Texas	 	Northeast	 	South Central	 	West	 	Other	 	Subtotal	 	Alternative Energy	 	Eliminations	 	Consolidated Total	
Energy revenue	$	479	
 	 	$	87	
 	 	$	111	
 	 	$	22	
 	 	$	16	
 	 	$	715	
 	 	$	19	
 	 	$	(300	)	 	$	434	
 	
Capacity revenue	18	
 	 	57	
 	 	61	
 	 	29	
 	 	17	
 	 	182	
 	 	—	
 	 	(8	)	 	174	
 	
Other revenue	8	
 	 	6	
 	 	(4	)	 	(3	)	 	61	
 	 	68	
 	 	1	
 	 	(20	)	 	49	
 	
Generation revenue	505	
 	 	150	
 	 	168	
 	 	48	
 	 	94	
 	 	965	
 	 	20	
 	 	$	(328	)	 	$	657	
 	
Generation cost of sales	(192	)	 	(82	)	 	(114	)	 	(14	)	 	(46	)	 	(448	)	 	—	
 	 	 	 	 	
Generation gross margin	$	313	
 	 	$	68	
 	 	$	54	
 	 	$	34	
 	 	$	48	
 	 	$	517	
 	 	$	20	

Business Metrics	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
MWh sold (in thousands)	8,324	
 	 	1,296	
 	 	4,127	
 	 	371	
 	 	 	 	 	 	426	
 	 	 	 	 	
MWh generated (in thousands)	6,320	
 	 	900	
 	 	4,263	
 	 	371	
 	 	 	 	 	 	426	
 	 	 	 	 	
Average on-peak market power prices ($/MWh) (a)(b)	$	25.32	
 	 	$	35.87	
 	 	$	24.41	
 	 	$	27.22	
 	 	 	 	 	 	N/A	

49

 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Three months ended March 31, 2011	
 	Conventional Generation	 	 	 	 	 	 	 	 	
(In millions except otherwise noted)	Texas	 	Northeast	 	South Central	 	West	 	Other	 	Subtotal	 	Alternative Energy	 	Eliminations	 	Consolidated Total	
Energy revenue	$	593	
 	 	$	151	
 	 	$	112	
 	 	$	4	
 	 	$	16	
 	 	$	876	
 	 	$	9	
 	 	$	(287	)	 	$	598	
 	
Capacity revenue	5	
 	 	74	
 	 	61	
 	 	29	
 	 	18	
 	 	187	
 	 	—	
 	 	(2	)	 	185	
 	
Other revenue	31	
 	 	(1	)	 	3	
 	 	3	
 	 	50	
 	 	86	
 	 	—	
 	 	(6	)	 	80	
 	
Generation revenue	629	
 	 	224	
 	 	176	
 	 	36	
 	 	84	
 	 	1,149	
 	 	9	
 	 	$	(295	)	 	$	863	
 	
Generation cost of sales	(243	)	 	(145	)	 	(121	)	 	(2	)	 	(49	)	 	(560	)	 	—	
 	 	 	 	 	
Generation gross margin	$	386	
 	 	$	79	
 	 	$	55	
 	 	$	34	
 	 	$	35	
 	 	$	589	
 	 	$	9	

Business Metrics	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
MWh sold (in thousands)	11,085	
 	 	2,558	
 	 	3,846	
 	 	21	
 	 	 	 	 	 	285	
 	 	 	 	 	
MWh generated (in thousands)	10,388	
 	 	2,032	
 	 	3,997	
 	 	21	
 	 	 	 	 	 	285	
 	 	 	 	 	
Average on-peak market power prices ($/MWh) (a)(b)	$	50.46	
 	 	$	57.91	
 	 	$	36.46	
 	 	$	35.36	
 	 	 	 	 	 	N/A	

(a) Average on-peak market power prices calculated based on average settled market prices in the following zones: for Texas region, in ERCOT - Houston and ERCOT - North; for Northeast region, in NYISO - West, NYISO - New York City, ISO - NE - Mass Hub, PJM - West Hub and PJM - DPL; and for West region, in CAISO - NP15 and CAISO - SP15.	 	 	 	 	
(b) Average on-peak market power prices for South Central region are calculated based on average day ahead market prices for "into Entergy" as published in the Platts Megawatt Daily report.	 	 	 	 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Three months ended March 31,	 	 	 	 	 	 	 	 	 	 	
Weather Metrics	Texas	 	Northeast	 	South Central	 	West	 	 	 	 	 	 	 	 	 	 	
2012	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
CDDs (c)	157	
 	 	—	
 	 	77	
 	 	—	
 	 	 	 	 	 	 	 	 	 	 	
HDDs (c)	686	
 	 	3,047	
 	 	1,113	
 	 	1,416	
 	 	 	 	 	 	 	 	 	 	 	
2011	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
CDDs	137	
 	 	—	
 	 	9	
 	 	2	
 	 	 	 	 	 	 	 	 	 	 	
HDDs	1,108	
 	 	3,169	
 	 	1,866	
 	 	1,481	
 	 	 	 	 	 	 	 	 	 	 	
30 year average	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
CDDs	95	
 	 	—	
 	 	46	
 	 	7	
 	 	 	 	 	 	 	 	 	 	 	
HDDs	1,132	
 	 	3,127	
 	 	1,649	
 	 	1,434	

(c)	National Oceanic and Atmospheric Administration-Climate Prediction Center - A Cooling Degree Day, or CDD, represents the number of degrees that the mean temperature for a particular day is above 65 degrees Fahrenheit in each region. A Heating Degree Day, or HDD, represents the number of degrees that the mean temperature for a particular day is below 65 degrees Fahrenheit in each region. The CDDs/HDDs for a period of time are calculated by adding the CDDs/HDDs for each day during the period.	

50

Conventional Generation gross margin — decreased by $72 million, including intercompany sales, during the three months ended March 31, 2012, compared to the same period in 2011, due to:

Decrease in Texas region	$	(73	)	
Decrease in Northeast region	(11	)	
Decrease in South Central region	(1	)	
Other (a)	13	
 	
 	$	(72	)	
 	 	
(a)	Other gross margin primarily represents revenues from the maintenance services business, which are eliminated in consolidation.	

The decrease in gross margin in the Texas region was driven by:

Lower gross margin from a 36% decrease in coal generation which was driven by higher planned and unplanned outages	$	(29	)	
Lower gross margin from a 51% decrease in nuclear generation which related primarily to an unplanned outage at STP	(24	)	
Lower gross margin driven by lower average realized energy prices	(9	)	
Decrease in unrealized trading activities	(13	)	
Other	2	
 	
 	$	(73	)	

The decrease in gross margin in the Northeast region was driven by:

Lower gross margin from coal plants due to a 16% decrease in realized energy prices	$	(7	)	
Lower gross margin from coal plants due to a 64% decrease in generation, resulting from the region's power generation switching from coal to gas plants due to continuing declines in gas prices	(12	)	
Lower capacity revenue due to 19% lower hedged prices and slightly lower volumes	(16	)	
Higher gross margin from an increase in the margins realized on certain load-serving contracts as a result of more favorable pricing, as well as the addition of intercompany sales under load contracts with Energy Plus	20	
 	
Other	4	
 	
 	$	(11	)	

The decrease in gross margin in the South Central region was driven by:

Higher gross margin from higher utilization of gas generation due to lower gas prices and higher overall sales volumes	$	37	
 	
Lower gross margin from a decrease in coal generation, due to some of the region's power switching from coal to gas generation	(18	)	
Lower gross margin from a decrease in average realized prices	(11	)	
Other	(9	)	
 	$	(1	)	

In addition to these decreases, gross margin in the West region remained flat compared to the prior year driven by:

Higher energy margin from increased run time at Encina driven by competitor's plant outages in the region	$	6	
 	
Decrease in unrealized trading activities	(6	)	
 	$	—	

51

Retail gross margin

The following is a detailed discussion of retail gross margin for NRG's Retail business segment.

Selected Income Statement Data

 	Three months ended March 31,	
(In millions except otherwise noted)	2012	 	2011	
Operating Revenues	 	 	 	
Mass revenues	$	730	
 	 	$	702	
 	
Commercial and Industrial revenues	441	
 	 	448	
 	
Supply management revenues	26	
 	 	30	
 	
Retail operating revenues (a)(b)	1,197	
 	 	1,180	
 	
Retail cost of sales (c)	917	
 	 	895	
 	
Retail gross margin	$	280	
 	 	$	285	

Business Metrics	 	 	 	
Electricity sales volume — GWh	 	 	 	
Mass	5,607	
 	 	5,378	
 	
Commercial and Industrial (a)	6,512	
 	 	6,191	
 	
Electricity sales volume — GWh	 	 	 	
Texas	11,066	
 	 	11,472	
 	
All other regions	1,053	
 	 	97	
 	
Average retail customers count (in thousands, metered locations)	 	 	 	
Mass	2,077	
 	 	1,812	
 	
Commercial and Industrial (a)	96	
 	 	78	
 	
Retail customers count (in thousands, metered locations)	 	 	 	
Mass	2,087	
 	 	1,819	
 	
Commercial and Industrial (a)	98	
 	 	79	

Weather Metrics	 	 	 	
CDDs (d)	200	
 	 	151	
 	
HDDs (d)	590	
 	 	960	

(a)	Includes customers of the Texas General Land Office for which the Company provides services, as well as sales to utility partner customers.	
 	 	
(b)	Excludes eliminations of $1 million, representing sales from Retail to the Texas region for the three months ended March 31, 2012.	
 	 	
(c)	Includes intercompany purchases of $289 million and $286 million, respectively.	
 	 	
(d)	The CDDs/HDDs amounts are representative of the Coast and North Central Zones within the ERCOT market in which Retail serves its customerbase.	

52

 	 	
•	Retail gross margin — Retail gross margin decreased $5 million for the three months ended March 31, 2012, compared to the same period in 2011, driven by:	

 	 	 	 	
Acquisition of Energy Plus in September 2011	$	29	
 	
Unfavorable impact of lower volume from mild winter weather in Texas in 2012, as well as increased risk management activities	(25	)	
Decrease from lower revenues due to lower pricing on C&I acquisitions and renewals consistent with competitive offers, partially offset by lower supply costs due to lower natural gas prices and by increased customer counts	(9	)	
 	$	(5	)	

•	Trends — Customer counts increased by approximately 31,000 since December 31, 2011, which was primarily due to expansion into new territories and marketing efforts. While cooling and heating degree days in both periods resulted in higher than normal customer usage, weather in 2011 was colder than in 2012. The weather resulted in higher customer usage of 2% and 11% in 2012 and 2011, respectively, when compared to ten-year normal weather. In addition, there were increases in Transmission and Distribution Service Provider rates for transition costs and tariff filings that will remain in effect for several years. These costs are passed through to Retail customers.	

Alternative Energy gross margin

NRG's Alternative Energy business segment, which is comprised mainly of the solar and wind businesses, had gross margin of $20 million for the three months ended March 31, 2012, compared to gross margin of $9 million for the same period in 2011. The increase in gross margin primarily resulted in the addition of the Roadrunner facility, which began commercial operations in late 2011, the addition of the first two blocks of Agua Caliente, which reached commercial operations in January and February 2012, and an increase in gross margin from Distributed Solar.

Mark-to-market for Economic Hedging Activities
Mark-to-market for economic hedging activities includes asset-backed hedges that have not been designated as cash flow hedges and ineffectiveness on cash flow hedges. Total net mark-to-market results decreased by $298 million during the three months ended March 31, 2012, compared to the same period in 2011.
The breakdown of gains and losses included in operating revenues and operating costs and expenses by region was as follows:

 	Three months ended March 31, 2012	
 	Retail	 	Texas	 	Northeast	 	South
Central	 	West	 	Alternative Energy	 	Elimination(a)	 	Total	
 	(In millions)	
Mark-to-market results in operating revenues	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Reversal of previously recognized unrealized (gains)/losses on settled positions related to economic hedges	$	(2	)	 	$	(188	)	 	$	(2	)	 	$	10	
 	 	$	1	
 	 	$	—	
 	 	$	62	
 	 	$	(119	)	
Net unrealized gains/(losses) on open positions related to economic hedges	6	
 	 	141	
 	 	—	
 	 	(10	)	 	(7	)	 	3	
 	 	26	
 	 	159	
 	
Total mark-to-market gains/(losses) in operating revenues	$	4	
 	 	$	(47	)	 	$	(2	)	 	$	—	
 	 	$	(6	)	 	$	3	
 	 	$	88	
 	 	$	40	
 	
Mark-to-market results in operating costs and expenses	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Reversal of previously recognized unrealized losses/(gains) on settled positions related to economic hedges	$	129	
 	 	$	6	
 	 	$	3	
 	 	$	2	
 	 	$	—	
 	 	$	—	
 	 	$	(62	)	 	$	78	
 	
Reversal of loss positions acquired as part of the Reliant Energy and Green Mountain Energy acquisitions	14	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	14	
 	
Net unrealized losses on open positions related to economic hedges	(176	)	 	(48	)	 	(13	)	 	(34	)	 	—	
 	 	—	
 	 	(26	)	 	(297	)	
Total mark-to-market losses in operating costs and expenses	$	(33	)	 	$	(42	)	 	$	(10	)	 	$	(32	)	 	$	—	
 	 	$	—	
 	 	$	(88	)	 	$	(205	)	
 	 	
(a)	Represents the elimination of the intercompany activity between the Retail businesses and the Conventional Generation regions and Alternative Energy.	

53

 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Three months ended March 31, 2011	
 	Retail	 	Texas	 	Northeast	 	South
Central	 	West	 	Alternative Energy	 	Elimination(a)	 	Total	
 	(In millions)	
Mark-to-market results in operating revenues	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Reversal of previously recognized unrealized (gains)/losses on settled positions related to economic hedges	$	—	
 	 	$	(59	)	 	$	8	
 	 	$	6	
 	 	$	—	
 	 	$	—	
 	 	$	38	
 	 	$	(7	)	
Net unrealized (losses)/gains on open positions related to economic hedges	(2	)	 	(47	)	 	(6	)	 	2	
 	 	4	
 	 	—	
 	 	55	
 	 	6	
 	
Total mark-to-market (losses)/gains in operating revenues	$	(2	)	 	$	(106	)	 	$	2	
 	 	$	8	
 	 	$	4	
 	 	$	—	
 	 	$	93	
 	 	$	(1	)	
Mark-to-market results in operating costs and expenses	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Reversal of previously recognized unrealized losses/(gains) on settled positions related to economic hedges	$	45	
 	 	$	1	
 	 	$	(2	)	 	$	(1	)	 	$	—	
 	 	$	—	
 	 	$	(38	)	 	$	5	
 	
Reversal of loss positions acquired as part of the Reliant Energy and Green Mountain Energy acquisitions	41	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	—	
 	 	41	
 	
Net unrealized gains/(losses) on open positions related to economic hedges	125	
 	 	10	
 	 	3	
 	 	5	
 	 	—	
 	 	—	
 	 	(55	)	 	88	
 	
Total mark-to-market gains/(losses) in operating costs and expenses	$	211	
 	 	$	11	
 	 	$	1	
 	 	$	4	
 	 	$	—	
 	 	$	—	
 	 	$	(93	)	 	$	134	

(a)	Represents the elimination of the intercompany activity between the Retail businesses and the Conventional Generation regions.	

Mark-to-market results consist of unrealized gains and losses. The settlement of these transactions is reflected in the same caption as the items being hedged.

For the three months ended March 31, 2012, the net losses on open positions were due to a decrease in forward coal and power prices and increases in ERCOT heat rates.

For the three months ended March 31, 2011, the gains on open positions were due to an increase in forward power and gas prices. The reversal of loss positions acquired as part of the Reliant Energy and Green Mountain Energy acquisitions were valued using forward prices on the acquisition dates. The roll-off amounts were offset by realized losses at the settled prices and higher costs of physical power which are reflected in operating costs and expenses during the same period.

In accordance with ASC 815, the following table represents the results of the Company's financial and physical trading of energy commodities for the three months ended March 31, 2012, and 2011. The realized financial and physical trading results are included in operating revenue and the unrealized financial and physical trading results are included in other revenue. The Company's trading activities are subject to limits within the Company's Risk Management Policy.

 	 	 	 	 	 	 	 	
 	Three months ended March 31,	
(In millions)	2012	 	2011	
Trading gains/(losses)	 	 	 	
Realized	$	11	
 	 	$	(3	)	
Unrealized	(2	)	 	14	
 	
Total trading gains	$	9	
 	 	$	11	

Contract Amortization Revenue

Contract amortization represents the roll-off of in-market customer contracts valued under purchase accounting and the favorable change of $16 million as compared to the prior period in 2011 related primarily to lower contract amortization for Reliant Energy of $12 million and $4 million for Green Mountain Energy.

54

Other Operating Costs

 	Retail	 	Texas	 	Northeast	 	South
Central	 	West	 	Other	 	Alternative Energy	 	Corporate	 	Total	
 	(In millions)	
Three months ended March 31, 2012	$57	 	$144	 	$53	 	$20	 	$14	 	$27	 	$5	 	$(15)	 	$305	
Three months ended March 31, 2011	$47	 	$121	 	$59	 	$20	 	$18	 	$17	 	$3	 	$(2)	 	$283	

Other operating costs increased by $22 million for the three months ended March 31, 2012, compared to the same period in 2011, due to:

Increase in Texas region operations and maintenance expense	$	23	
 	
Increase in Retail operations and maintenance expense	9	
 	
Decrease in Northeast region operations and maintenance expense	(2	)	
Decrease in West region operations and maintenance expense	(4	)	
Gain on sale of plant assets in current quarter	(4	)	
 	$	22	

 	 	
◦	Texas operations and maintenance— increased primarily due to outage work in 2012 at coal plants, including Limestone and W.A. Parish, and increased maintenance spending at gas plants including the costs to remove two units from mothball status in preparation for the summer.	
 	 	
◦	Retail operations and maintenance expense — increased primarily due to the acquisition of Energy Plus in September 2011 as well as increased customer billing costs from an increase in customer counts.	
 	 	
◦	Northeast operations and maintenance expense— decreased in part because the prior year reflects incremental costs associated with headcount reductions.	
 	 	
◦	West operations and maintenance expense— decreased due to timing of maintenance work at Encina.	

Depreciation and Amortization Expense

Depreciation and amortization expense increased by $25 million for the three months ended March 31, 2012, compared to the same period in 2011. This was primarily due to additional depreciation related to solar facilities which commenced commercial operations in late 2011 and early 2012, as well as the amortization of the intangibles acquired in connection with the acquisition of Energy Plus.

Selling, General and Administrative Expenses

Selling, general and administrative expenses increased by $78 million for the three months ended March 31, 2012, compared to the same period in 2011, which was due primarily to the following:

◦Selling, general and administrative costs of $20 million for Energy Plus which was acquired in September 2011;

◦Expected cash payment related to CDWR settlement of $20 million expensed during the quarter;

◦Transaction costs of $8 million associated with the sale of 49% of Agua Caliente;
 	 	
◦	Increase in marketing costs of $14 million associated with additional marketing costs for the Retail businesses from increased customer counts and marketing efforts as well as new sponsorship agreements; and	

◦Increase in labor costs of $5 million for additional solar projects and acquired solar distribution businesses.

Equity in Earnings of Unconsolidated Affiliates

NRG's equity earnings from unconsolidated affiliates were $8 million for the three months ended March 31, 2012, compared to equity losses of $2 million for the same period in 2011 primarily due to an increase in the earnings from Sherbino driven by favorable valuation of hedged positions and an increase in earnings from GenConn as the Middletown facility reached commercial operations in June 2011.

55

Impairment Charge on Investment
 
As discussed in more detail in Note 4, Nuclear Innovation North America LLC Developments, Including Impairment Charge , of the Company's 2011 Form 10-K, the devastating March 2011 earthquake and tsunami in Japan, which in turn, triggered a nuclear incident at the Fukushima Daiichi Nuclear Power Station, caused NRG to evaluate its investment in NINA for impairment. Consequently, NRG deconsolidated its investment in NINA and took an impairment charge in the first quarter of 2011 equal to the balance of its investment in NINA, or $481 million.

Loss on Debt Extinguishment

A loss on debt extinguishment of the 2014 Senior Notes of $28 million was recorded in the three months ended March 31, 2011, which primarily consisted of the premiums paid on redemption and the write-off of previously deferred financing costs.

Interest Expense

NRG's interest expense decreased by $8 million for the three months ended March 31, 2012, compared to the same period in 2011 due to the following:

Increase/(decrease) in interest expense	(In millions)	
Decrease for 2016 Senior Notes redeemed in May and June 2011	$	(44	)	
Increase for 2019 and 2021 Senior Notes issued in May 2011	39	
 	
Increase for project financings	11	
 	
Decrease for 2014 Senior Notes redeemed in January and February 2011	(8	)	
Increase for 2018 Senior Notes issued in January 2011	6	
 	
Decrease for capitalized interest	(5	)	
Decrease for reduction in revolving credit facility	(7	)	
Total	$	(8	)	

Income Tax Benefit

For the three months ended March 31, 2012, NRG recorded an income tax benefit of $120 million on a pre-tax loss of $326 million. For the same period in 2011, NRG recorded an income tax benefit of $105 million on a pre-tax loss of $365 million. The effective tax rate was 36.8% and 28.8% for the three months ended March 31, 2012, and 2011, respectively.

For the three months ended March 31, 2012, NRG's overall effective tax rate was different than the statutory rate of 35% primarily due to the generation of ITCs from the Company's Agua Caliente solar project in Arizona.

For the three months ended March 31, 2011, NRG's overall effective tax rate was different than the statutory rate of 35% primarily due to the change in the valuation allowance resulting from capital losses generated in the quarter for which there were no projected capital gains or available tax planning strategies.

56

Liquidity and Capital Resources

Liquidity Position

As of March 31, 2012, and December 31, 2011, NRG's liquidity, excluding collateral received, was approximately $2.4 billion and $2.1 billion, respectively, comprised of the following:

(In millions)	March 31,
2012	 	December 31,
2011	
Cash and cash equivalents	$	1,014	
 	 	$	1,105	
 	
Funds deposited by counterparties	199	
 	 	258	
 	
Restricted cash	217	
 	 	292	
 	
Total	1,430	
 	 	1,655	
 	
2011 Revolving Credit Facility availability	1,141	
 	 	673	
 	
Total liquidity	2,571	
 	 	2,328	
 	
Less: Funds deposited as collateral by hedge counterparties	(199	)	 	(258	)	
Total liquidity, excluding collateral received	$	2,372	
 	 	$	2,070	

For the three months ended March 31, 2012, total liquidity, excluding collateral received, increased by $302 million due to higher 2011 Revolving Credit Facility availability, offset by lower cash and cash equivalent and restricted cash balances. The increase in the 2011 Revolving Credit Facility availability was primarily due to a $304 million reduction in letters of credit due to the sale of a 49% interest in Agua Caliente in January 2012 to MidAmerican, and the addition of the NRG Repowering credit facility in January 2012 as discussed in Note 8,  Debt and Capital Leases , to this Form 10-Q. Changes in cash and cash equivalent balances are further discussed hereinafter under the heading  Cash Flow Discussion . Cash and cash equivalents and funds deposited by counterparties at March 31, 2012 were predominantly held in money market funds invested in treasury securities, treasury repurchase agreements or government agency debt.

Included in restricted cash is $121 million of cash and cash equivalents held in controlled accounts as collateral to support the Company's equity funding obligations for the Ivanpah, Agua Caliente, and CVSR projects, as required by the U.S. DOE, which guarantees the Agua Caliente, Ivanpah, and CVSR debt. This collateral can be replaced, at the Company's discretion, with a letter of credit in order to utilize such cash for other purposes. The Company's total liquidity excluding such amounts is $2.3 billion.

The line item "Funds deposited by counterparties" represents the amounts that are held by NRG as a result of collateral posting obligations from the Company's counterparties due to positions in the Company's hedging program. These amounts are segregated into separate accounts that are not contractually restricted but, based on the Company's intention, are not available for the payment of NRG's general corporate obligations. Depending on market fluctuation and the settlement of the underlying contracts, the Company will refund this collateral to the counterparties pursuant to the terms and conditions of the underlying trades. Since collateral requirements fluctuate daily and the Company cannot predict if any collateral will be held for more than 12 months, the funds deposited by counterparties are classified as a current asset on the Company's balance sheet, with an offsetting liability for this cash collateral received within current liabilities.

Management believes that the Company's liquidity position and cash flows from operations will be adequate to finance operating and maintenance capital expenditures, to fund dividends to NRG's preferred stockholders, and other liquidity commitments. Management continues to regularly monitor the Company's ability to finance the needs of its operating, financing and investing activity within the dictates of prudent balance sheet management.

57

SOURCES OF LIQUIDITY

The principal sources of liquidity for NRG's future operating and capital expenditures are expected to be derived from new and existing financing arrangements, existing cash on hand and cash flows from operations. As described in Note 8,  Debt and Capital Leases , to this Form 10-Q and Note 12,  Debt and Capital Leases , to the Company's 2011 Form 10-K, the Company's financing arrangements consist mainly of the 2011 Senior Credit Facility, the Senior Notes, and project-related financings.

In addition, NRG has granted first liens to certain counterparties on substantially all of the Company's assets. NRG uses the first lien structure 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. To the extent that the underlying hedge positions for a counterparty are in-the-money to NRG, the counterparty would have no claim under the lien program. The lien program limits the volume that can be hedged, not the value of underlying out-of-the-money positions. The first lien program does not require NRG to post collateral above any threshold amount of exposure. Within the first lien structure, the Company can hedge up to 80% of its baseload capacity and 10% of its non-baseload assets with these counterparties for the first 60 months and then declining thereafter. Net exposure to a counterparty on all trades must be positively correlated to the price of the relevant commodity for the first lien to be available to that counterparty. The first lien structure is not subject to unwind or termination upon a ratings downgrade of a counterparty and has no stated maturity date.

The Company's lien counterparties may have a claim on its assets to the extent market prices exceed the hedged prices. As of March 31, 2012, all hedges under the first liens were in-the-money on a counterparty aggregate basis.

The following table summarizes the amount of MWs hedged against the Company's baseload assets and as a percentage relative to the Company's baseload capacity under the first lien structure as of March 31, 2012:

 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
Equivalent Net Sales Secured by First Lien Structure (a)	2012	 	2013	 	2014	 	2015	 	2016	
In MW (b)	1,864	
 	 	1,768	
 	 	1,793	
 	 	541	
 	 	635	
 	
As a percentage of total net baseload capacity (c)	28	%	 	26	%	 	27	%	 	8	%	 	10	%	
 	 	
(a)	Equivalent Net Sales include natural gas swaps converted using a weighted average heat rate by region.	
 	 	
(b)	2012 MW value consists of May through December positions only.	
 	 	
(c)	Net baseload capacity under the first lien structure represents 80% of the Company’s total baseload assets.	

USES OF LIQUIDITY

The Company's requirements for liquidity and capital resources, other than for operating its facilities, can generally be categorized by the following: (i) commercial operations activities; (ii) debt service obligations; (iii) capital expenditures, including repowering and renewable development, and environmental; and (iv) corporate financial transactions including return of capital to stockholders.

Commercial Operations

NRG's commercial operations activities require a significant amount of liquidity and capital resources. These liquidity requirements are primarily driven by: (i) margin and collateral posted with counterparties; (ii) margin and collateral required to participate in physical markets and commodity exchanges; (iii) timing of disbursements and receipts (i.e. buying fuel before receiving energy revenues); (iv) initial collateral for large structured transactions; and (v) collateral for project development. As of March 31, 2012, commercial operations had total cash collateral outstanding of $495 million, and $707 million outstanding in letters of credit to third parties primarily to support its commercial activities for both wholesale and retail transactions (includes a $51 million letter of credit relating to deposits at the PUCT that cover outstanding customer deposits and residential advance payments). As of March 31, 2012, total collateral held from counterparties was $199 million in cash, and $9 million of letters of credit.

Future liquidity requirements may change based on the Company's hedging activities and structures, fuel purchases, and future market conditions, including forward prices for energy and fuel and market volatility. In addition, liquidity requirements are dependent on NRG's credit ratings and general perception of its creditworthiness.

58

Capital Expenditures

The following tables and descriptions summarize the Company's capital expenditures, including accruals, for maintenance, environmental, and growth investments for the three months ended March 31, 2012, and the estimated capital expenditure and growth investments forecast for the remainder of 2012. 

 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Maintenance	 	Environmental	 	Growth Investments	 	Total	
 	(In millions)	
Northeast	$	1	
 	 	$	9	
 	 	$	—	
 	 	$	10	
 	
Texas	37	
 	 	—	
 	 	—	
 	 	37	
 	
South Central	3	
 	 	—	
 	 	—	
 	 	3	
 	
West	2	
 	 	—	
 	 	60	
 	 	62	
 	
Other Conventional	2	
 	 	—	
 	 	11	
 	 	13	
 	
Retail	4	
 	 	—	
 	 	—	
 	 	4	
 	
Solar	—	
 	 	—	
 	 	837	
 	 	837	
 	
Total capital expenditures for the the three months ended
March 31, 2012	49	
 	 	9	
 	 	908	
 	 	966	
 	
Accrual impact	(1	)	 	12	
 	 	(338	)	 	(327	)	
Total cash capital expenditures for the three months ended
March 31, 2012	48	
 	 	21	
 	 	570	
 	 	639	
 	
Other investments (a)	—	
 	 	—	
 	 	(75	)	 	(75	)	
Funding from debt financing, net of fees	—	
 	 	(9	)	 	(398	)	 	(407	)	
Funding from third party equity partners	—	
 	 	—	
 	 	(56	)	 	(56	)	
Total capital expenditures and investments, net	$	48	
 	 	$	12	
 	 	$	41	
 	 	$	101	

Estimated capital expenditures for the remainder of 2012	$	211	
 	 	$	32	
 	 	$	3,003	
 	 	$	3,246	
 	
Other investments (a)	—	
 	 	—	
 	 	(131	)	 	(131	)	
Funding from debt financing, net of fees	—	
 	 	(32	)	 	(2,283	)	 	(2,315	)	
Funding from third party equity partners	—	
 	 	—	
 	 	(205	)	 	(205	)	
NRG estimated capital expenditures for the remainder of 2012, net of financings	$	211	
 	 	$	—	
 	 	$	384	
 	 	$	595	

(a)	Other investments include initial investments in projects; network upgrade fees, restricted cash activity and proceeds from cash grants.	

•	Maintenance and Environmental capital expenditures — For the three months ended March 31, 2012, the Company's environmental capital expenditures included $9 million related to a project to install selective catalytic reduction systems, scrubbers and fabric filters on Indian River Unit 4. The system was operational at year-end 2011 and is undergoing performance testing.	

•	Growth Investments capital expenditures — For the three months ended March 31, 2012, the Company's growth investment expenditures included $837 million for solar projects and $60 million for the Company's El Segundo project. In 2012, NRG will be continuing its efforts on the solar and El Segundo projects.	

59

Environmental Capital Expenditures

Based on current rules, technology and plans, as well as preliminary plans based on proposed rules, NRG has estimated that environmental capital expenditures from 2012 through 2016 to meet NRG's environmental commitments will be approximately $553 million. These costs are primarily associated with mercury controls to satisfy MATS on the Company's Big Cajun II, W.A. Parish and Limestone facilities and a number of intake modification projects across the fleet under state or proposed federal 316(b) rules. NRG continues to explore cost effective compliance alternatives to reduce costs. While this estimate reflects anticipated schedules and controls related to the proposed 316(b) Rule, the full impact on the scope and timing of environmental retrofits from any new or revised regulations cannot be determined until these rules are final and any legal challenges are reviewed. However, NRG believes it is positioned to meet more stringent requirements through its planned capital expenditures, existing controls, and increasing generation from renewable resources.

NRG's current contracts with the Company's rural electric cooperative customers in the South Central region allow for recovery of a portion of the region's environmental capital costs incurred as the result of complying with any change in environmental law. Cost recoveries begin once the environmental equipment becomes operational and include a capital return. The actual recoveries will depend, among other things, on the timing of the completion of the capital projects and the remaining duration of the contracts.

2012 Capital Allocation Program

On February 28, 2012, the Company announced its intention to initiate an annual common stock dividend of $0.36 per share, with the first quarterly payment expected to be paid in the third quarter of 2012.  Furthermore, the Company still intends to refinance its remaining $1.1 billion of 2017 Senior Notes to simplify its capital structure and better align covenant packages, but any refinancing will depend on market conditions and is therefore subject to change. Upon completion of this undertaking, a more flexible covenant package across credit facilities and debt securities will enable NRG to invest more opportunistically in growth initiatives and enhance its ability to efficiently return capital to all stockholders.

As part of the 2012 program, the Company plans to invest approximately $271 million in maintenance and environmental capital expenditures in existing assets, and approximately $425 million in solar and other projects under development.

60

Cash Flow Discussion

The following table reflects the changes in cash flows for the comparative three month periods:

 	 	 	 	 	 	 	 	 	 	 	 	
Three months ended March 31,	2012	 	2011	 	Change	
 	(In millions)	
Net cash (used)/provided by operating activities	$	(76	)	 	$	216	
 	 	$	(292	)	
Net cash used by investing activities	(543	)	 	(228	)	 	(315	)	
Net cash provided/(used) by financing activities	527	
 	 	(232	)	 	759	

Net Cash Used By Operating Activities

Changes to net cash provided by operating activities were driven by:

 	 	 	 	
 	(In millions)	
Decrease in operating income adjusted for non-cash charges	$	(128	)	
Change in cash paid in support of risk management activities, including option premium collected/paid,
   primarily related to margin posted for retail supply positions	(238	)	
Other changes in working capital, which primarily reflects a change in timing of interest payments related to
 Senior Notes that were redeemed and issued in 2011	74	
 	
 	$	(292	)	

Net Cash Used By Investing Activities

Changes to net cash used by investing activities were driven by:

 	 	 	 	
 	(In millions)	
Increase in capital expenditures due to increased spending on maintenance and RepoweringNRG, primarily for solar projects under construction	$	(420	)	
Decrease in restricted cash, which was mainly to support equity requirements for U.S. DOE funded projects	80	
 	
Increase in notes receivable	(19	)	
Receipt of cash grants	28	
 	
Other	16	
 	
 	$	(315	)	

Net Cash Provided By Financing Activities

Changes in net cash provided by financing activities were driven by:

 	 	 	 	
 	(In millions)	
Net decrease in borrowings of debt, primarily related to the issuance of $1.2 billion under the 2018 Senior Notes in January 2011, compared to $415 million which mainly related to financing arrangements for solar projects in construction	$	(871	)	
Cash paid for repurchases of treasury stock in 2011	130	
 	
Net decrease in debt payments, primarily from the redemption of the 2014 Senior Notes for $1.2 billion in January 2011	1,328	
 	
Proceeds from the sale of noncontrolling interest and other contributions from noncontrolling interests	178	
 	
Other	(6	)	
 	$	759	

61

NOLs, Deferred Tax Assets and Uncertain Tax Position Implications, under ASC 740, Income Taxes, or ASC 740

For the three months ended March 31, 2012, the Company had a total domestic pre-tax book loss of $336 million and foreign pre-tax book income of $10 million. For the three months ended March 31, 2012, the Company utilized net operating losses, or NOLs, of $13 million. As of March 31, 2012, the Company has cumulative domestic NOL carryforwards of $226 million for financial statement purposes. In addition, NRG has cumulative foreign NOL carryforwards of $259 million, of which $76 million will expire starting 2012 through 2019 and of which $183 million do not have an expiration date.

In addition to these amounts, the Company has $181 million of tax effected uncertain tax benefits. As a result of the Company's tax position, and based on current forecasts, NRG anticipates income tax payments, primarily due to foreign, state and local jurisdictions, of up to $50 million in 2012.

However, as the position remains uncertain for the $181 million of tax effected uncertain tax benefits, the Company has recorded a non-current tax liability of $62 million and may accrue the remaining balance as an increase to non-current liabilities until final resolution with the related taxing authority. The $62 million non-current tax liability for uncertain tax benefits is primarily from positions taken on various state returns, including accrued interest.

The Company continues to be under examination for various state and foreign jurisdictions for multiple years.

62

New and On-going Company Initiatives and Development Projects

NRG has a comprehensive set of initiatives and development projects that supports its strategy focused on: (i) excellence in safety and enhanced operating performance; (ii) earning a margin by selling electricity to end-use customers; (iii) development of new renewable and conventional power generation projects and repowering of power generation assets at existing sites; (iv) empowering retail customers with distinctive products and services; (v) engaging in a proactive capital allocation plan; and (vi) pursuing selective acquisitions, joint ventures, divestitures and investment in new energy-related businesses and new technologies in order to enhance the Company's asset mix and combat climate change.

Renewable Development and Acquisitions

As part of its core strategy, NRG intends to continue to invest in the development and acquisition of renewable energy projects, primarily solar. NRG's renewable strategy is intended to capitalize on first mover advantage in a high growth segment of NRG's business, the Company's existing presence in regions with attractive renewable resources and the prevalence, in the Company's core markets, of state-mandated renewable portfolio standards. A brief description of the Company's development efforts with respect to solar renewable technology follows.

Solar

NRG has acquired and is developing a number of solar projects utilizing photovoltaic, or PV, as well as solar thermal technologies. The following table is a brief summary of the Company's major Utility Scale Solar projects as of March 31, 2012, that are under construction.

NRG Owned Projects	Location	PPA	MW (a)	Expected COD	Status	
Ivanpah (b)	Ivanpah, CA	20 - 25 year	392	
 	2013	Under Construction	
Agua Caliente (c)	Yuma County, AZ	25 year	290	
 	2012 - 2014	Under Construction	
CVSR	San Luis Obispo, CA	25 year	250	
 	2012 - 2013	Under Construction	
Alpine	Lancaster, CA	20 year	66	
 	2012	Under Construction	
Borrego	Borrego Springs, CA	25 year	26	
 	2012	Under Construction	
Avra Valley	Pima County, AZ	25 year	25	
 	2012	Under Construction	
 	 	
(a)	Represents total project size.	
 	 	
(b)	NRG owns a 50.1% stake in the Ivanpah solar project.	
 	 	
(c)	Includes 110 MW, which reached commercial operations from January through April of 2012.	
 
Below is a summary of recent developments related to solar projects:

Agua Caliente— In 2011, NRG acquired 100% of the 290 MW Agua Caliente solar project, or Agua Caliente, in Yuma, AZ. On January 18, 2012, the Company completed the sale of a 49% interest in NRG Solar AC Holdings LLC, the indirect owner of Agua Caliente, to MidAmerican. Operations are scheduled to commence in phases through the first quarter of 2014, with 110 MW achieving commercial operations from January through April of 2012. On April 12, 2012, the Company received permission from the U.S. DOE to accelerate the block completion schedule. The impact of this decision will permit the Company to bring 245 MW on-line during 2012 and shortens the commercial operations date of the entire project by three months to March 2014. The acceleration will result in greater earnings earlier than originally anticipated, along with acceleration of payments under the Engineering, Procurement and Construction, or EPC, agreement which will be funded with earlier draw downs under the Agua Caliente Financing Agreement, as well as equity support by the partners. Power generated from Agua Caliente will be sold to Pacific Gas and Electric under a 25 year PPA.

CVSR— NRG owns 100% of the 250 MW CVSR project in eastern San Luis Obispo County, California. During the quarter, the Company met the conditions necessary to permit loan disbursements under the CVSR Financing Agreement, as discussed in Note 8,  Debt and Capital Leases , to this Form 10-Q. Operations are expected to commence in phases beginning in the third quarter of 2012 through the fourth quarter of 2013. Power generated from CVSR will be sold to Pacific Gas and Electric under a 25 year PPA.

Alpine — Alpine, located in Lancaster, CA, is a 66 MW facility utilizing First Solar thin film solar modules. The project, which is anticipated to reach commercial operations at the end of the third quarter of 2012, obtained financing during the first quarter of 2012, as discussed in Note 8,  Debt and Capital Leases , to this Form 10-Q. Power generated from Alpine will be sold to Pacific Gas and Electric under a 20 year PPA.

63

Distributed Solar

NRG's installation of solar power generating systems at MetLife Stadium, Gillette Stadium and Patriot Place is continuing, with construction at MetLife and Gillette Stadium anticipated being complete by the end of the third quarter of 2012. Additionally, in February 2012, NRG announced that it will install a solar power generating system at Lincoln Financial Field, home of the Philadelphia Eagles, which is anticipated to be completed by the end of 2012. All of the Company's Distributed Solar projects in operation or under construction are supported by long-term PPAs.

Conventional Power Development

Projects Under Construction

The Company's El Segundo Energy Center LLC, or ESEC, is continuing construction at its El Segundo Power Generating Station, a 550 MW fast start, gas turbine combined cycle generating facility in El Segundo, California. The facility is being constructed pursuant to a 10 year, 550 MW PPA with Southern California Edison Company, or SCE.  The Company expects a commercial operation date of August 1, 2013.
 
Retail Growth Initiatives

The Company's Retail businesses are expanding in the Northeast through a combination of new sales channels, partner marketing programs, and new product offerings. NRG grew its Northeast customer base by 10% during the first quarter of 2012, and the Retail businesses are currently operating in 12 states.

Also, the Company continues to grow its renewable customer base. At the end of the first quarter of 2012, about 300,000 of its retail electricity customers were on a 100% “green” electric product. Plus, Green Mountain Energy gained an iconic commercial customer by being selected as the official green energy provider of Super Bowl XLVI and this year's Pro Bowl, with the Company offsetting the carbon emissions from each event.

NRG also continues to expand its Reliant eSenseTM product offerings. eSense is a suite of technology solutions that uses the advanced meter system network (smart meters) that is being rolled out to customers in ERCOT.  Through March 31, 2012, Reliant had 600,000 customers using one of these products that provide customers with energy insights, choices and convenience solutions.

Reliant also continues to expand its Home SolutionsSM business with 250,000 customers utilizing home services products including protection products such as surge protection, in home power line protection, HVAC maintenance and energy efficiency products like air filter delivery and solar panel leasing.

Electric Vehicle Infrastructure Development

NRG, through its subsidiary eVgo, continues its build out of the Houston and Dallas/Fort Worth Metroplex, or DFW, EV ecosystems, and the Company is on track to be the first company to equip an entire major market with the privately funded infrastructure needed for successful EV adoption and integration. As of March 31, 2012, eVgo had 17 public fast charging Freedom Station sites operational, under construction, or in permitting in Houston, and 16 in DFW. These two ecosystems are the largest metropolitan-area networks of DC fast chargers in the nation. eVgo offers consumers a subscription-based plan that locks in all charging requirements for EVs at a competitive monthly fee. Based upon the successful launch of its subscription-based business model in Texas, eVgo is poised to enter the Washington, DC/Baltimore market.

Additionally, eVgo has entered into an agreement with the CPUC to build at least 200 public fast charging Freedom Station sites and wiring and associated work to prepare 10,000 commercial and multifamily parking spaces for electric vehicle charging in California. The agreement is part of a legal settlement, as discussed in detail in Note 14,  Commitments and Contingencies , of this Form 10-Q, and is pending FERC approval.

Post-combustion Carbon Capture Project

NRG, through its wholly owned subsidiary Petra Nova LLC, is continuing development of an up-to 240 MW-equivalent Post-Combustion Carbon Capture commercial scale unit at NRG's W.A. Parish plant, with the intent of using the captured CO 2 in enhanced oil recovery operations in oil fields on the Texas Gulf Coast. NRG is currently progressing through a Pipeline front-end engineering and design study and the Environmental Impact Statement process, the latter required under the National Environmental Policy Act.

64

Off-Balance Sheet Arrangements

Obligations under Certain Guarantee Contracts

NRG and certain of its subsidiaries enter into guarantee arrangements in the normal course of business to facilitate commercial transactions with third parties. These arrangements include financial and performance guarantees, stand-by letters of credit, debt guarantees, surety bonds and indemnifications.

Retained or Contingent Interests

NRG does not have any material retained or contingent interests in assets transferred to an unconsolidated entity.

Derivative Instrument Obligations

The Company's 3.625% Preferred Stock includes a feature which is considered an embedded derivative per ASC 815. Although it is considered an embedded derivative, it is exempt from derivative accounting as it is excluded from the scope pursuant to ASC 815. As of March 31, 2012, based on the Company's stock price, the embedded derivative was out-of-the-money and had no redemption value.

Obligations Arising Out of a Variable Interest in an Unconsolidated Entity

Variable interest in equity investments — As of March 31, 2012, NRG has several investments with an ownership interest percentage of 50% or less in energy and energy-related entities that are accounted for under the equity method of accounting. Several of these investments are variable interest entities for which NRG is not the primary beneficiary. See also Note 9,  Variable Interest Entities, or VIEs,  to this Form 10-Q.

NRG's pro-rata share of non-recourse debt held by unconsolidated affiliates was approximately $243 million as of March 31, 2012. This indebtedness may restrict the ability of these subsidiaries to issue dividends or distributions to NRG. See also Note 16,  Investments Accounted for by the Equity Method and Variable Interest Entities,  to the Company's 2011 Form 10-K.

Contractual Obligations and Commercial Commitments

NRG has a variety of contractual obligations and other commercial commitments that represent prospective cash requirements in addition to the Company's capital expenditure programs, as disclosed in the Company's 2011 Form 10-K. See also Note 8,  Debt and Capital Leases , and Note 14,  Commitments and Contingencies , to this Form 10-Q for a discussion of new commitments and contingencies that also include contractual obligations and commercial commitments that occurred during the three months ended March 31, 2012.

65

Fair Value of Derivative Instruments

NRG may enter into long-term power purchase and sales contracts, fuel purchase contracts and other energy-related financial instruments to mitigate variability in earnings due to fluctuations in spot market prices and to hedge fuel requirements at generation facilities or retail load obligations. In addition, in order to mitigate interest rate risk associated with the issuance of the Company's variable rate and fixed rate debt, NRG enters into interest rate swap agreements. The following disclosures about fair value of derivative instruments provide an update to, and should be read in conjunction with,  Fair Value of Derivative Instruments  in Item 7 —  Management's Discussion and Analysis of Financial Condition and Results of Operations,  of the Company's 2011 Form 10‑K.

The tables below disclose the activities that include both exchange and non-exchange traded contracts accounted for at fair value in accordance with ASC 820,  Fair Value Measurements and Disclosures , or ASC 820. Specifically, these tables disaggregate realized and unrealized changes in fair value; disaggregate estimated fair values at March 31, 2012, based on their level within the fair value hierarchy defined in ASC 820; and indicate the maturities of contracts at March 31, 2012.

 	 	 	 	
Derivative Activity Gains/(Losses)	(In millions)	
Fair value of contracts as of December 31, 2011	$	451	
 	
Contracts realized or otherwise settled during the period	(68	)	
Changes in fair value	(116	)	
Fair value of contracts as of March 31, 2012	$	267	

 	
 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	 	
 	Fair Value of Contracts as of March 31, 2012	
Fair value hierarchy gains/(losses)	Maturity
Less Than
1 Year	 	
Maturity
1-3 Years	 	
Maturity
4-5 Years	 	Maturity
in Excess
4-5 Years	 	
Total Fair
Value	
 	(In millions)	
Level 1	$	(36	)	 	$	(47	)	 	$	(9	)	 	$	—	
 	 	$	(92	)	
Level 2	328	
 	 	77	
 	 	(95	)	 	6	
 	 	316	
 	
Level 3	34	
 	 	9	
 	 	—	
 	 	—	
 	 	43	
 	
Total	$	326	
 	 	$	39	
 	 	$	(104	)	 	$	6	
 	 	$	267	

The Company has elected to disclose derivative assets and liabilities on a trade-by-trade basis and does not offset amounts at the counterparty master agreement level. Also, collateral received or paid on the Company's derivative assets or liabilities are recorded on a separate line item on the balance sheet. Consequently, the magnitude of the changes in individual current and non-current derivative assets or liabilities is higher than the underlying credit and market risk of the Company's portfolio. As discussed in Item 3  - Quantitative and Qualitative Disclosures About Market Risk, Commodity Price Risk , to this Form 10-Q, NRG measures the sensitivity of the Company's portfolio to potential changes in market prices using Value at Risk, or VaR, a statistical model which attempts to predict risk of loss based on market price and volatility. NRG's risk management policy places a limit on one-day holding period VaR, which limits the Company's net open position. As the Company's trade-by-trade derivative accounting results in a gross-up of the Company's derivative assets and liabilities, the net derivative assets and liability position is a better indicator of NRG's hedging activity. As of March 31, 2012, NRG's net derivative asset was $267 million, a decrease to total fair value of $184 million as compared to December 31, 2011. This decrease was primarily driven by the roll-off of trades that settled during the period in addition to losses in fair value due to the decreases in coal, gas and power prices and increases in ERCOT heat rates.

Based on a sensitivity analysis using simplified assumptions, the impact of a $1 per MMBtu increase or decrease in natural gas prices across the term of the derivative contracts would cause a change of approximately $245 million in the net value of derivatives as of March 31, 2012.

66

Critical Accounting Policies and Estimates

NRG's discussion and analysis of the financial condition and results of operations are based upon the consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the U.S, or U.S. GAAP. The preparation of these financial statements and related disclosures in compliance with U.S. GAAP requires the application of appropriate technical accounting rules and guidance as well as the use of estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures of contingent assets and liabilities. The application of these policies necessarily involves judgments regarding future events, including the likelihood of success of particular projects, legal and regulatory challenges, and the fair value of certain assets and liabilities. These judgments, in and of themselves, could materially affect the financial statements and disclosures based on varying assumptions, which may be appropriate to use. In addition, the financial and operating environment may also have a significant effect, not only on the operation of the business, but on the results reported through the application of accounting measures used in preparing the financial statements and related disclosures, even if the nature of the accounting policies have not changed.

On an ongoing basis, NRG evaluates these estimates, utilizing historic experience, consultation with experts and other methods the Company considers reasonable. In any event, actual results may differ substantially from the Company's estimates. Any effects on the Company's business, financial position or results of operations resulting from revisions to these estimates are recorded in the period in which the information that gives rise to the revision becomes known.

The Company identifies its most critical accounting policies as those that are the most pervasive and important to the portrayal of the Company's financial position and results of operations, and that require the most difficult, subjective and/or complex judgments by management regarding estimates about matters that are inherently uncertain. NRG's critical accounting policies include derivative instruments, income taxes and valuation allowance for deferred tax assets, impairment of long lived assets, goodwill and other intangible assets, and contingencies.

67

ITEM 3 — QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

NRG is exposed to several market risks in the Company's normal business activities. Market risk is the potential loss that may result from market changes associated with the Company's merchant power generation or with an existing or forecasted financial or commodity transaction. The types of market risks the Company is exposed to are commodity price risk, interest rate risk, liquidity risk, credit risk and currency exchange risk. The following disclosures about market risk provide an update to, and should be read in conjunction with, Item 7A — Quantitative and Qualitative Disclosures About Market Risk,  of the Company's 2011 Form 10-K.

Commodity Price Risk

Commodity price risks result from exposures to changes in spot prices, forward prices, volatilities, and correlations between various commodities, such as natural gas, electricity, coal, oil, and emissions credits. NRG manages the commodity price risk of the Company's merchant generation operations and load serving obligations by entering into various derivative or non-derivative instruments to hedge the variability in future cash flows from forecasted sales and purchases of electricity and fuel. NRG measures the risk of the Company's portfolio using several analytical methods, including sensitivity tests, scenario tests, stress tests, position reports, and Value at Risk, or VaR. NRG uses a Monte Carlo simulation based VaR model to estimate the potential loss in the fair value of the Company's energy assets and liabilities, which includes generation assets, load obligations, and bilateral physical and financial transactions.

As of March 31, 2012, the VaR for NRG's commodity portfolio, including generation assets, load obligations and bilateral physical and financial transactions calculated using the VaR model was $51 million.

The following table summarizes average, maximum and minimum VaR for NRG for the three months ended March 31, 2012, and 2011:

 	 	 	 	 	 	 	 	
(In millions)	2012	 	2011	
VaR as of March 31	$	51	
 	 	$	52	
 	
Three months ended March 31:	 	 	 	
Average	$	34	
 	 	$	51	
 	
Maximum	53	
 	 	56	
 	
Minimum	24	
 	 	44	

In order to provide additional information for comparative purposes to NRG's peers, the Company also uses VaR to estimate the potential loss of derivative financial instruments that are subject to mark-to-market accounting. These derivative instruments include transactions that were entered into for both asset management and trading purposes. The VaR for the derivative financial instruments calculated using the diversified VaR model as of March 31, 2012, for the entire term of these instruments entered into for both asset management and trading, was $22 million primarily driven by asset-backed transactions.

Interest Rate Risk

NRG is exposed to fluctuations in interest rates through the Company's issuance of fixed rate and variable rate debt. Exposures to interest rate fluctuations may be mitigated by entering into derivative instruments known as interest rate swaps, caps, collars and put or call options. These contracts reduce exposure to interest rate volatility and result in primarily fixed rate debt obligations when taking into account the combination of the variable rate debt and the interest rate derivative instrument. NRG's risk management policies allow the Company to reduce interest rate exposure from variable rate debt obligations.

NRG entered into interest rate swaps, which became effective on April 1, 2011, and are intended to hedge the risks associated with floating interest rates. For the interest rate swaps, the Company will pay its counterparty the equivalent of a fixed interest payment on a predetermined notional value, and NRG receives the monthly equivalent of a floating interest payment based on the 1-month LIBOR calculated on the same notional value. All interest rate swap payments by NRG and its counterparties are made monthly and the LIBOR is determined in advance of each interest period. The total notional amount of the swaps, which mature on February 1, 2013, is $900 million.

68

In addition to those discussed above, the Company's project subsidiaries enter into interest rate swaps, intended to hedge the risks associated with interest rates on non-recourse project level debt. See Note 12,  Debt and Capital Leases,  of the Company's 2011 Form 10-K, as well as Note 8,  Debt and Capital Leases  of this Form 10-Q, for more information on the Company's interest rate swaps.

If all of the above swaps had been discontinued on March 31, 2012, the Company would have owed the counterparties $91 million. Based on the investment grade rating of the counterparties, NRG believes its exposure to credit risk due to nonperformance by counterparties to its hedge contracts to be insignificant.

As part of the CVSR financing, the Company entered into swaptions with a notional value of $686 million in order to hedge the project interest rate risk. If the swaptions were discontinued on March 31, 2012, the counterparty would have owed the Company approximately $33 million.

NRG has both long and short-term debt instruments that subject the Company to the risk of loss associated with movements in market interest rates. As of March 31, 2012, a 1% change in interest rates would result in an $8 million change in interest expense on a rolling twelve month basis.

As of March 31, 2012, the fair value of the Company's debt was approximately equal to its carrying value of $10.1 billion. NRG estimates that a 1% decrease in market interest rates would have increased the fair value of the Company's long-term debt by $811 million.

Liquidity Risk

Liquidity risk arises from the general funding needs of NRG's activities and in the management of the Company's assets and liabilities. The Company is currently exposed to additional collateral posting if natural gas prices decline primarily due to the long natural gas equivalent position at various exchanges used to hedge NRG's retail supply load obligations.

Based on a sensitivity analysis for power and gas positions under marginable contracts, a $1 per MMBtu change in natural gas prices across the term of the marginable contracts would cause a change in margin collateral posted of approximately $262 million as of March 31, 2012, and a 1 MMBtu/MWh change in heat rates for heat rate positions would result in a change in margin collateral posted of approximately $48 million as of March 31, 2012. This analysis uses simplified assumptions and is calculated based on portfolio composition and margin-related contract provisions as of March 31, 2012.

Credit Risk

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. See Note 5, Fair Value of Financial Instruments , to this Form 10-Q for discussions regarding counterparty credit risk and retail customer credit risk, and Note 7,  Accounting for Derivative Instruments and Hedging Activities , to this Form 10-Q for discussion regarding credit risk contingent features.

Currency Exchange Risk

NRG's foreign earnings and investments may be subject to foreign currency exchange risk, which NRG generally does not hedge. As these earnings and investments are not material to NRG's consolidated results, the Company's foreign currency exposure is limited.

69

ITEM 4 — CONTROLS AND PROCEDURES

Conclusion Regarding the Effectiveness of Disclosure ControlsandProcedures

Under the supervision and with the participation of NRG's management, including its principal executive officer, principal financial officer and principal accounting officer, NRG conducted an evaluation of the effectiveness of the design and operation of its disclosure controls and procedures, as such term is defined in Rules 13a-15(e) or 15d-15(e) of the Securities Exchange Act of 1934, as amended, or the Exchange Act. Based on this evaluation, the Company's principal executive officer, principal financial officer and principal accounting officer concluded that the disclosure controls and procedures were effective as of the end of the period covered by this report on Form 10-Q.

Changes in Internal Control over Financial Reporting

There were no changes in the Company's internal controls over financial reporting (as such term is defined in Rule 13a-15(f) under the Exchange Act) that occurred in the first quarter of 2012 that materially affected, or are reasonably likely to materially affect, the Company's internal control over financial reporting.

70

PART II — OTHER INFORMATION
ITEM 1 — LEGAL PROCEEDINGS

For a discussion of material legal proceedings in which NRG was involved through March 31, 2012, see Note 14, Commitments and Contingencies , to this Form 10-Q.

ITEM 1A — RISK FACTORS
Information regarding risk factors appears in Part I, Item 1A, RiskFactors Related to NRG Energy, Inc., in the Company's 2011 Form 10-K.

ITEM 2 — UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
None.

ITEM 3 — DEFAULTS UPON SENIOR SECURITIES
None.
ITEM 4 — MINE SAFETY DISCLOSURES
Not applicable.
ITEM 5 — OTHER INFORMATION
None.

71

ITEM 6 — EXHIBITS

Exhibits	 	 	
3.1	 	Amended and Restated Certificate of Incorporation of NRG Energy, Inc.	
31.1	 	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, filed herewith.	
31.2	 	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, filed herewith.	
31.3	 	Certification of Chief Accounting Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, filed herewith.	
32	 	Certification of Chief Executive Officer, Chief Financial Officer and Chief Accounting Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350, filed herewith.	
101.INS	 	XBRL Instance Document	
101.SCH	 	XBRL Taxonomy Extension Schema	
101.CAL	 	XBRL Taxonomy Extension Calculation Linkbase	
101.DEF	 	XBRL Taxonomy Extension Definition Linkbase	
101.LAB	 	XBRL Taxonomy Extension Label Linkbase	
101.PRE	 	XBRL Taxonomy Extension Presentation Linkbase	

72

SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

 	NRG ENERGY, INC.
(Registrant)

 	/s/ DAVID W. CRANE  	 	
 	David W. Crane 	 	
 	Chief Executive Officer
(Principal Executive Officer) 	 	

 	/s/ KIRKLAND B. ANDREWS  	 	
 	Kirkland B. Andrews 	 	
 	Chief Financial Officer
(Principal Financial Officer) 	 	

 	/s/ RONALD B. STARK	 	
 	Ronald B. Stark	 	
Date: May 3, 2012	Chief Accounting Officer
(Principal Accounting Officer) 	 	

73

EXHIBIT INDEX

 	 	 	
Exhibits	 	 	
3.1	 	Amended and Restated Certificate of Incorporation of NRG Energy, Inc.	
31.1	 	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, filed herewith.	
31.2	 	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, filed herewith.	
31.3	 	Certification of Chief Accounting Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002, filed herewith.	
32	 	Certification of Chief Executive Officer, Chief Financial Officer and Chief Accounting Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, 18 U.S.C. Section 1350, filed herewith.	
101.INS	 	XBRL Instance Document	
101.SCH	 	XBRL Taxonomy Extension Schema	
101.CAL	 	XBRL Taxonomy Extension Calculation Linkbase	
101.DEF	 	XBRL Taxonomy Extension Definition Linkbase	
101.LAB	 	XBRL Taxonomy Extension Label Linkbase	
101.PRE	 	XBRL Taxonomy Extension Presentation Linkbase	

74

EXHIBIT 3.1

AMENDED AND RESTATED
CERTIFICATE OF INCORPORATION

OF

NRG ENERGY, INC.

Pursuant to Sections 242 and 245 of the Delaware General Corporation Law, NRG Energy, Inc., a Corporation organized and existing under the laws of the State of Delaware, the date of the filing of its original Certificate of Incorporation with the Secretary of State being May 29, 1992, hereby certifies as follows:

ARTICLE ONE

The name of the Corporation is NRG Energy, Inc.

ARTICLE TWO

The address of the Corporation's registered office in the State of Delaware is Corporation Trust Center, 1209 Orange Street, City of Wilmington, County of New Castle, 19801. The name of its registered agent at such address is The Corporation Trust Company.

ARTICLE THREE

The nature of the business or purposes to be conducted or promoted is to engage in any lawful act or activity for which corporations may be organized under the Delaware General Corporation Law.

ARTICLE FOUR

Section 1. Authorized Shares. The total number of shares of capital stock which the Corporation has authority to issue is 510,000,000 shares, consisting of:
 	 	
(a)	10,000,000 shares of Preferred Stock, par value $.01 per share (“Preferred Stock ”); and	

(b)	500,000,000 shares of Common Stock, par value $.01 per share (“Common Stock ”).	

1

The Preferred Stock and the Common Stock shall have the rights, preferences and limitations set forth below.

Section 2. Preferred Stock. The Preferred Stock may be issued from time to time and in one or more series. By resolution adopted by the affirmative vote of at least a majority of the total number of Directors then in office, the Board of Directors of the Corporation is authorized to determine or alter the powers, preferences and rights, and the qualifications, limitations and restrictions granted to or imposed upon any wholly unissued series of Preferred Stock, and within the limitations or restrictions stated in any resolution or resolutions of the Board of Directors adopted by the affirmative vote of at least a majority of the total number of Directors then in office, originally fixing the number of shares constituting any series of Preferred Stock to increase or decrease (but not below the number of shares of any such series of Preferred Stock, then outstanding) the number of shares of any such series of Preferred Stock and to fix the number of shares of any series of Preferred Stock. In the event that the number of shares of any series of Preferred Stock shall be so decreased, the shares constituting such decrease shall resume the status which such shares had prior to the adoption of the resolution originally fixing the number of shares of such series of Preferred Stock subject to the requirements of applicable law. The powers, preferences and relative, participating, optional and other special rights of each series of Preferred Stock, and the qualifications, limitations and restrictions granted to or imposed upon, any such series of Preferred Stock may be made dependent upon facts ascertainable outside the resolutions or resolutions providing for the issue of such Preferred Stock, adopted by the affirmative vote of at least a majority of the total number of Directors then in office, provided that the manner in which such facts shall operate upon the powers, preferences and rights of, and the qualifications, limitations and restrictions thereof, if any, may differ from those of any and all other series at any time outstanding. Any of the powers, preferences and rights of, and the qualifications, limitations and restrictions granted to or imposed upon, such series of Preferred Stock is clearly and expressly set forth in the resolution or resolutions providing for the issue of such series of Preferred Stock adopted by the affirmative vote of at least a majority of the total number of Directors then in office.

Section 3. Common Stock.

(a)Dividends and Other Distributions. Except as otherwise provided by the Delaware General Corporation Law or this Certificate of Incorporation (this “ Certificate ”), the holders of Common Stock, subject to the rights of holders of any series of Preferred Stock, shall share ratably in all dividends as may from time to time be declared by the Board of Directors of the Corporation in respect of the Common Stock out of funds legally available for the payment thereof and payable in cash, stock or otherwise, and in all other distributions (including, without limitation, the dissolution, liquidation and winding up of the Corporation), whether in respect of liquidation or dissolution (voluntary or involuntary) or otherwise, after payment of liabilities and liquidation preference on any outstanding Preferred Stock.

2

(b)Preemptive Rights. No holder of Common Stock shall have any preemptive rights with respect to the Common Stock or any other securities of the Corporation, or to any obligations convertible (directly or indirectly) into securities of the Corporation, whether now or hereafter authorized.

(c)Voting Rights. Except as otherwise provided by the Delaware General Corporation Law or this Certificate and subject to the rights of holders of any series of Preferred Stock, all of the voting power of the stockholders of the Corporation shall be vested in the holders of the Common Stock, and each holder of Common Stock shall have one vote for each share held by such holder on all matters voted upon by the stockholders of the Corporation.

ARTICLE FIVE

The Corporation is to have perpetual existence.

ARTICLE SIX

Except as provided by the Certificate of Incorporation (including any duly authorized certificate of designation of any series of Preferred Stock), each Director shall be elected by the vote of the majority of the votes cast with respect to that Director's election at any meeting for the election of Directors at which a quorum is present, provided that if the number of nominees at any such meeting exceeds the number of Directors to be elected at the meeting, the Directors shall be elected by the vote of a plurality of the shares represented in person or by proxy at any such meeting and entitled to vote on the election of Directors. For purposes of this Article, a majority of the votes cast means that the number of shares voted “for” a Director must exceed the number of votes cast “against” that Director.

ARTICLE SEVEN

Subject to any rights of the holders of any series of Preferred Stock to elect additional Directors under specified circumstances, the number of Directors which shall constitute the Board of Directors shall initially be established at eleven and, thereafter, may be enlarged up to fifteen by the affirmative vote of a majority of the total number of directors then in office or may otherwise be enlarged with the approval of the holders of at least a majority of the shares of Common Stock then outstanding, and may be reduced by resolution adopted by the affirmative vote of a majority of the total number of Directors then in office. Newly created directorships resulting from an increase in the size of the Board of Directors may be filled by the affirmative vote of a majority of the total number of Directors then in office or by vote of the stockholders.

3

ARTICLE EIGHT

In furtherance and not in limitation of the powers conferred by statute, the Board of Directors is expressly authorized to make, alter, amend or repeal the By-laws of the Corporation.

ARTICLE NINE

Section 1. Indemnification; Limitation of Liability.

(a)To the fullest extent permitted by the Delaware General Corporation Law as it now exists or may hereafter be amended, and excepts as otherwise provided in the Corporation's By-laws, (i) no Director of the Corporation shall be liable to the Corporation or its stockholders for monetary damages arising from a breach of fiduciary duty owed to the Corporation or its stockholders; and (ii) the Corporation shall indemnify its officers and Directors.

(b)Any repeal or modification of the foregoing paragraph by the stockholders of the Corporation shall not adversely affect any right or protection of a Director of the Corporation in respect of any act, omission or condition existing or event or circumstance occurring prior to the time of such repeal or modification.

ARTICLE TEN

Section 1. Classification of Directors.

(a)    From the effective date of this Amended and Restated Certificate of Incorporation until the election of directors at the 2013 Annual Meeting of stockholders, pursuant to Section 141(d) of the General Corporation Law of the State of Delaware, the Board of Directors shall be divided into three classes of Directors, Class I, Class II and Class III, with the Directors in Class I having a term expiring at the 2013 Annual Meeting, the directors in Class II having a term expiring at the 2014 Annual Meeting and the directors in Class III having a term expiring at the 2015 Annual Meeting.

(b)    Commencing with the election of directors at the 2013 Annual Meeting of stockholders, pursuant to Section 141(d) of the General Corporation Law of the State of Delaware, the Board of Directors shall be divided into two classes of directors, Class I and Class II, with the Directors in Class I having a term that expires at the 2014 Annual Meeting and the Directors in Class II having a term that expires at the 2015 Annual Meeting. The successors of the Directors who, immediately prior to the 2013 Annual Meeting, were members of Class I (and whose terms expire at the 2013 Annual Meeting) shall be elected to Class I; the directors who, immediately prior to the 2013 Annual Meeting, were members of Class II and whose terms were scheduled to expire at the 2014 Annual Meeting shall become members of Class I; and the directors who, immediately prior to the 2013 Annual Meeting, were members of Class III and whose terms were scheduled to expire at the 2015

4

Annual Meeting shall become members of Class II with a term expiring at the 2015 Annual Meeting.

(c)    Commencing with the election of directors at the 2014 Annual Meeting of stockholders, pursuant to Section 141(d) of the General Corporation Law of the State of Delaware, there shall be a single class of Directors, Class I, with all Directors of such class having a term that expires at the 2015 Annual Meeting. The successors of the Directors who, immediately prior to the 2014 Annual Meeting of stockholders, were members of Class I (and whose terms expire at the 2014 Annual Meeting) shall be elected to Class I for a term that expires at the 2015 Annual Meeting, and the Directors who, immediately prior to the 2014 Annual Meeting, were members of Class II and whose terms were scheduled to expire at the 2015 Annual Meeting shall become members of Class I with a term expiring at the 2015 Annual Meeting.

(d)    From and after the election of directors at the 2015 Annual Meeting of stockholders, the Board of Directors shall cease to be classified as provided in Section 141(d) of the General Corporation Law of the State of Delaware, and the Directors elected at the 2015 Annual Meeting (and each Annual Meeting thereafter) shall be elected for a term expiring at the next Annual Meeting and may be removed with or without cause. Each Director elected at any Annual Meeting shall hold office until such Director's successor shall have been duly elected and qualified.

Section 2. Removal. Until the cessation of the classified Board of Directors, pursuant to Article Ten Section 1(d) and subject to the rights, if any, of the holders of any series of Preferred Stock to remove Directors (with or without cause) and fill the vacancies thereby created (as specified in any duly authorized certificate of designation of any series of Preferred Stock), no Director may be removed from office except for cause and the affirmative vote of the holders of a majority of the shares of Common Stock then outstanding. Notwithstanding the foregoing, if the holders of any class or series of capital stock are entitled by the provisions of this Certificate (including any duly authorized certificate of designation of any series of Preferred Stock) to elect one or more Directors, such Director or Directors so elected may be removed with or without cause by the vote of the holders of a majority of the outstanding shares of that class or series entitled to vote.

Section 3. Vacancies. Subject to the rights of the holders of any series of Preferred Stock to remove Directors and fill the vacancies thereby created (as specified in any duly authorized certificate of designation of any series of Preferred Stock) and subject to ARTICLE SEVEN, vacancies occurring on the Board of Directors for any reason may be filled by vote of a majority of the remaining members of the Board of Directors, although less than a quorum, at any meeting of the Board of Directors. A person so elected by the Board of Directors to fill a vacancy shall hold office until the next election of the class for which such Directors shall have been chosen and until his or her successor shall have been duly elected and qualified.

5

ARTICLE ELEVEN

Meetings of stockholders may be held within or without the State of Delaware, as the By-laws may provide. The books of the Corporation may be kept (subject to any provision contained in the Delaware General Corporation Law) outside of the State of Delaware at such place or places as may be designated from time to time by the Board of Directors or in the By-laws of the Corporation.

ARTICLE TWELVE

Subject to the rights of holders of any series of Preferred Stock to act by written consent as specified in any duly authorized certificate of designation of any series of Preferred Stock, the stockholders of the Corporation may not take any action by written consent in lieu of a meeting, and must take any actions at a duly called annual or special meeting of stockholders and the power of stockholders to consent in writing without a meeting is specifically denied. Except as otherwise required by law, special meetings of stockholders of the Corporation may be called only by the Board of Directors pursuant to a resolution adopted by the affirmative vote of the majority of the total number of Directors then in office, by the chief executive officer of the Corporation or, if there is no chief executive officer, by the most senior executive officer of the Corporation.

ARTICLE THIRTEEN

Notwithstanding any other provisions of this Certificate or any provisions of law which might otherwise permit a lesser vote or no vote, but in addition to any affirmative vote of the holders of the capital stock required by law or this Certificate (including any duly authorized certificate of designation of any series of Preferred Stock), the affirmative vote of the holders of at least two-thirds (2/3) of the combined voting power of all of the then outstanding shares of the Corporation eligible to be cast in the election of Directors generally shall be required to alter, amend or repeal or ARTICLES NINE, TEN or TWELVE hereof, or this ARTICLE THIRTEEN, or any provision thereof or hereof.

ARTICLE FOURTEEN

The Corporation reserves the right to amend, alter, change or repeal any provision contained in this Certificate, in the manner now or hereafter prescribed by statute, and all rights conferred upon stockholders, Directors or any other person herein are granted subject to this reservation.

ARTICLE FIFTEEN

The Corporation expressly elects to be governed by Section 203 of the Delaware General Corporation Law.

* * * * * *

6

IN WITNESS WHEREOF, the undersigned on behalf of the Corporation for the purpose of amending and restating the Certificate of Incorporation pursuant to the General Corporation Law of the State of Delaware, under penalties of perjury does hereby declare and certify that this is the act and deed of the Corporation and the facts stated herein are true, and accordingly has hereunto signed this Certificate of Restated Certificate of Incorporation this 1st day of May, 2012.

NRG Energy, Inc.,
a Delaware corporation

By: /s/ Michael R. Bramnick
Name: Michael R. Bramnick
Title: Executive Vice President and General Counsel

7

EXHIBIT 31.1
CERTIFICATION
I, David W. Crane, certify that:
 	 	
1.	I have reviewed this quarterly report on Form 10-Q of NRG Energy, Inc.;	
 	 	
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;	
 	 	
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;	
 	 	
4.	The registrant's other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:	
 	 	
(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;	
 	 	
(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;	
 	 	
(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and	
 	 	
(d)	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and	
 	 	
5.	The registrant's other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):	
 	 	
(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and	
 	 	
(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.	

 	 	
/s/ DAVID W. CRANE	 	
David W. Crane
Chief Executive Officer
(Principal Executive Officer)	 	
Date: May 3, 2012 

EXHIBIT 31.2
CERTIFICATION
I, Kirkland B. Andrews, certify that:
 	 	
1.	I have reviewed this quarterly report on Form 10-Q of NRG Energy, Inc.;	
 	 	
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;	
 	 	
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;	
 	 	
4.	The registrant's other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:	
 	 	
(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;	
 	 	
(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;	
 	 	
(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and	
 	 	
(d)	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and	
 	 	
5.	The registrant's other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):	
 	 	
(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and	
 	 	
(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.	

 	 	
/s/ KIRKLAND B. ANDREWS	 	
Kirkland B. Andrews
Chief Financial Officer
(Principal Financial Officer)	 	
Date: May 3, 2012 

EXHIBIT 31.3
CERTIFICATION
I, Ronald B. Stark, certify that:
 	 	
1.	I have reviewed this quarterly report on Form 10-Q of NRG Energy, Inc.;	
 	 	
2.	Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;	
 	 	
3.	Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;	
 	 	
4.	The registrant's other certifying officers and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:	
 	 	
(a)	Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;	
 	 	
(b)	Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;	
 	 	
(c)	Evaluated the effectiveness of the registrant's disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and	
 	 	
(d)	Disclosed in this report any change in the registrant's internal control over financial reporting that occurred during the registrant's most recent fiscal quarter (the registrant's fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant's internal control over financial reporting; and	
 	 	
5.	The registrant's other certifying officers and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant's auditors and the audit committee of the registrant's board of directors (or persons performing the equivalent functions):	
 	 	
(a)	All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant's ability to record, process, summarize and report financial information; and	
 	 	
(b)	Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant's internal control over financial reporting.	

 	 	
/s/ RONALD B. STARK	 	
Ronald B. Stark
Chief Accounting Officer
(Principal Accounting Officer)	 	
Date: May 3, 2012 

EXHIBIT 32

CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

     In connection with the Quarterly Report of NRG Energy, Inc. on Form 10-Q for the quarter ended March 31, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Form 10-Q”), each of the undersigned officers of the Company certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to such officer's knowledge:
 	 	
(1)	The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and	
 	 	
(2)	
The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company as of the dates and for the periods expressed in the Form 10-Q.	

Date: May 3, 2012 

 	 	 	 	 	
 	/s/ DAVID W. CRANE  	 	
 	David W. Crane	 	
 	Chief Executive Officer
(Principal Executive Officer) 	 	

 	/s/ KIRKLAND B. ANDREWS	 	
 	Kirkland B. Andrews	 	
 	Chief Financial Officer
(Principal Financial Officer) 	 	

 	/s/ RONALD B. STARK  	 	
 	Ronald B. Stark	 	
 	Chief Accounting Officer
(Principal Accounting Officer) 	 	
     The foregoing certification is being furnished solely pursuant to 18 U.S.C. Section 1350 and is not being filed as part of this Form 10-Q or as a separate disclosure document.
     A signed original of this written statement required by Section 906, or other document authenticating, acknowledging or otherwise adopting the signature that appears in typed form within the electronic version of this written statement required by Section 906, has been provided to NRG Energy, Inc. and will be retained by NRG Energy, Inc. and furnished to the Securities and Exchange Commission or its staff upon request.