RRI Energy Reports Third Quarter 2009 Results

RRI Energy, Inc. today is reporting open EBITDA of $133 million for the third quarter of 2009, compared to $248 million for the same period of 2008. The decline was primarily due to lower unit margins resulting from lower commodity prices and lower power demand. Adjusted EBITDA was $100 million for the third quarter of 2009, compared to $350 million for the third quarter of 2008. Out-of-the-money coal hedges in 2009 compared to in-the-money coal hedges in 2008 form the primary difference between open and adjusted EBITDA for both periods. Free cash flow used in continuing operations was $179 million for the first nine months of 2009, compared to free cash flow provided by continuing operations of $298 million for the same period in 2008. These results exclude the performance of the Texas retail business, which was sold on May 1, 2009 and is included in discontinued operations.

"Managing challenges of this difficult economic environment continues to be our primary focus,” said Mark Jacobs, president and chief executive officer of RRI Energy. "Our modest hedging program, which provides a high probability of achieving free cash flow breakeven or better in 2010 and 2011, secured debt reduction, and over $1.1 billion of cash position us to deliver long-term value to shareholders when the market recovers. Notwithstanding the difficult market conditions, we have taken actions to maximize the value of our assets through efficiency and effectiveness. Some of those actions include reducing our cost structure, utilizing invested capital more efficiently and implementing flexible operating models at some of our generating stations.”

Open EBITDA was $129 million for the first nine months of 2009, compared to $505 million for the same period of 2008. Adjusted EBITDA was $42 million for the first nine months of 2009, compared to $709 million for the first nine months of 2008. The declines were due to the same factors as described above. These results exclude the performance of the Texas retail business, which was sold on May 1, 2009 and is included in discontinued operations.

The loss from continuing operations before income taxes for the third quarter of 2009 was $9 million, compared to income of $183 million for the third quarter of 2008. The reported results include net unrealized gains from energy derivatives of $7 million in 2009 and net unrealized losses from energy derivatives of $40 million in 2008.

The loss from continuing operations before income taxes for the first nine months of 2009 was $334 million, compared to income of $351 million for the first nine months of 2008. The 2009 reported results include net unrealized losses from energy derivatives of $30 million and severance costs totaling $8 million. The reported numbers for 2008 include net unrealized gains from energy derivatives of $58 million and a $37 million charge for western states litigation and similar settlements. Operating cash flow from continuing operations was ($275) million for the first nine months of 2009, compared to $505 million for the same period of 2008.

Outlook

RRI Energy’s outlook is based on forward commodity prices as of October 23, 2009. The outlook for open EBITDA is $198 million and $455 million for the years ending December 31, 2009 and 2010, respectively. The outlook for adjusted EBITDA, which includes the impact of hedges and other items and gains on sales of assets and emission and exchange allowances, net is $56 million and $428 million for the same periods. The outlook for free cash flow provided by (used in) continuing operations is ($314) million and $167 million for the years ending December 31, 2009 and 2010, respectively.

Open EBITDA Reconciliation
($ millions)		2008A		2009E		2010E
Income (loss) from continuing operations before income taxes		$26		($387)		($49)
Unrealized (gains) losses on energy derivatives		9		(25)		17
Severance		---		8		---
Western states litigation and similar settlements		37		---		---
Wholesale energy goodwill impairment		305		---		---
Debt extinguishments losses		2		4		---
Depreciation and amortization		313		281		302
Interest expense, net		179		175		158
Adjusted EBITDA		$871		$56		$428
Hedges and other items		(233)		163		27
Gains on sales of assets and emission and exchange allowances, net		(93)		(21)		---
Open EBITDA		$545		$198		$455

Free Cash Flow from Continuing Operations Reconciliation
($ millions)		2008A		2009E		2010E
Operating cash flow from continuing operations		$703		($464)		$502
Western states litigation and similar settlements payments		34		68		---
Change in margin deposits, net		(199)		290		(221)
Adjusted cash flow provided by (used in) continuing operations		$538		($106)		$281
Maintenance capital expenditures		(56)		(57)		(51)
Environmental capital expenditures and capitalized interest1		(223)		(141)		(35)
Emission and exchange allowances activity, net		(19)		(10)		(28)
Free cash flow provided by (used in) continuing operations		$240		($314)		$167
1. Estimate represents the low end of the range.

Non-GAAP Financial Measures

This press release and the attached financial tables include the following non-GAAP financial measures:

• EBITDA
• Adjusted EBITDA
• Open EBITDA
• Adjusted cash flow provided by (used in) continuing operations
• Free cash flow provided by (used in) continuing operations
• Open energy gross margin
• Open gross margin
• Gross debt
• Net debt
• Operation and maintenance, excluding severance
• General and administrative, excluding severance

A reconciliation of these financial measures and the most directly comparable GAAP measures is included above or in the attached financial tables. Additional information regarding these measures, including a discussion of their usefulness and purpose, is included in the Form 8-K furnished along with this press release. Certain factors that could affect GAAP financial measures are not accessible on a forward-looking basis, but could be material to future reported earnings and cash flows.

Webcast Of Earnings Conference Call

RRI Energy will host its third quarter 2009 earnings conference call beginning at 9:00 a.m. Central Time on Thursday, November 5, 2009. The conference call will be webcast live with audio and slides at www.rrienergy.com in the investor relations section. A replay of the call can be accessed approximately two hours after the call’s completion.

About RRI Energy, Inc.

RRI Energy, Inc. (NYSE:RRI) based in Houston, provides electricity to wholesale customers in the United States. The company is one of the largest independent power producers in the nation with more than 14,000 megawatts of power generation capacity across the United States. These strategically located generating assets use natural gas, fuel oil and coal. RRI will routinely post all important information on its Web site at www.rrienergy.com.

This news release contains "forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. Forward-looking statements are statements that contain projections, estimates or assumptions about our revenues, income, capital structure and other financial items, our plans and objectives for future operations or about our future economic performance, possible transactions, dispositions, financings or offerings, and our view of economic and market conditions. In many cases you can identify forward-looking statements by terminology such as "anticipate," "estimate," "believe," "continue," "could," "intend," "may," "plan," "potential," "predict," "should," "will," "expect," "objective," "projection," "forecast," "goal," "guidance," "outlook," "effort," "target" and other similar words. However, the absence of these words does not mean that the statements are not forward-looking.

Actual results may differ materially from those expressed or implied by forward-looking statements as a result of many factors or events, including, but not limited to, legislative, regulatory and/or market developments, the outcome of pending lawsuits, governmental proceedings and investigations, the effects of competition, financial and economic market conditions, access to capital, the timing and extent of changes in commodity prices and interest rates, weather conditions and other factors we discuss or refer to in the "Risk Factors” section of our most recent Annual Report on Form 10-K filed with the Securities and Exchange Commission. Our filings and other important information are also available on the Investor Relations page of our website at www.rrienergy.com.

Each forward-looking statement speaks only as of the date of the particular statement and we undertake no obligation to update or revise any forward-looking statement, whether as a result of new information, future events or otherwise.

RRI Energy, Inc. and Subsidiaries
Consolidated Statements of Operations
(Unaudited)
		Three Months Ended September 30,									Nine Months Ended September 30,
		2009				2008					2009				2008
		(thousands of dollars, except per share amounts)
Revenues:
Revenues (including $25,095, $6,169, $51,225 and $12,906 unrealized losses) (including $0, $0, $0 and $253,001 from affiliates)		$	507,179			$	959,865				$	1,363,140			$	2,853,227
Expenses:
Cost of sales (including $31,826, $(34,247), $20,857 and $70,806 unrealized gains (losses)) (including $0, $1,234, $0 and $71,540 from affiliates)			267,632				513,801					872,373				1,591,516
Operation and maintenance			114,457				134,586					428,567				455,764
General and administrative			23,686				23,070					80,345				84,911
Western states litigation and similar settlements			-				3,467					-				37,467
Gains on sales of assets and emission and exchange allowances, net			(1,013	)			(16,561	)				(21,184	)			(39,484	)
Depreciation and amortization			67,724				78,353					203,228				244,059
Total operating expense			472,486				736,716					1,563,329				2,374,233
Operating Income (Loss)			34,693				223,149					(200,189	)			478,994
Other Income (Expense):
Income of equity investment, net			1,297				1,405					1,148				2,600
Debt extinguishments gains (losses)			(103	)			(904	)				741				(2,257	)
Other, net			(417	)			4,593					(206	)			4,619
Interest expense			(44,614	)			(49,293	)				(136,600	)			(151,803	)
Interest income			407				4,495					1,376				19,146
Total other expense			(43,430	)			(39,704	)				(133,541	)			(127,695	)
Income (Loss) from Continuing Operations Before Income Taxes			(8,737	)			183,445					(333,730	)			351,299
Income tax expense (benefit)			9,532				89,868					(105,988	)			162,808
Income (Loss) from Continuing Operations			(18,269	)			93,577					(227,742	)			188,491
Income (loss) from discontinued operations			2,841				(1,131,497	)				864,467				(490,511	)
Net Income (Loss)		$	(15,428	)		$	(1,037,920	)			$	636,725			$	(302,020	)
Basic Earnings (Loss) Per Share:
Income (loss) from continuing operations		$	(0.05	)		$	0.27				$	(0.65	)		$	0.54
Income (loss) from discontinued operations			0.01				(3.24	)				2.46				(1.41	)
Net income (loss)		$	(0.04	)		$	(2.97	)			$	1.81			$	(0.87	)
Diluted Earnings (Loss) Per Share:
Income (loss) from continuing operations		$	(0.05	)		$	0.26				$	(0.65	)		$	0.53
Income (loss) from discontinued operations			0.01				(3.19	)				2.46				(1.38	)
Net income (loss)		$	(0.04	)		$	(2.93	)			$	1.81			$	(0.85	)
Weighted Average Common Shares Outstanding (in thousands):
- Basic			351,561				349,200					350,908				347,086
- Diluted			351,561				353,694					350,908				353,958
Reference is made to RRI Energy, Inc.'s Annual Report
on Form 10-K for the year ended December 31, 2008.

RRI Energy, Inc. and Subsidiaries
Results of Operations by Segment - Adjusted and Open
(Unaudited)
		Three Months Ended September 30,													Nine Months Ended September 30,
		2009				2008				Change					2009				2008				Change
		(millions of dollars)
East coal open gross margin (1)		$	100			$	228			$	(128	)			$	312			$	714			$	(402	)
East gas open gross margin (1)			67				66				1					155				146				9
West open gross margin (1)			81				90				(9	)				114				138				(24	)
Other open gross margin (1)			19				17				2					48				42				6
Total			267				401				(134	)				629				1,040				(411	)
Operation and maintenance, excluding severance			(114	)			(135	)			21					(424	)			(456	)			32
General and administrative, excluding severance			(21	)			(24	)			3					(77	)			(86	)			9
Other income (expense), net			1				6				(5	)				1				7				(6	)
Open EBITDA			133				248				(115	)				129				505				(376	)
Power			(10	)			(18	)			8					(30	)			(53	)			23
Fuel			(51	)			90				(141	)				(185	)			192				(377	)
Tolling / Other			27				13				14					107				25				82
Hedges and other items			(34	)			85				(119	)				(108	)			164				(272	)
Gains on sales of assets and emission and exchange allowances, net			1				17				(16	)				21				40				(19	)
Adjusted EBITDA			100				350				(250	)				42				709				(667	)
Unrealized gains (losses) on energy derivatives			7				(40	)			47					(30	)			58				(88	)
Western states litigation and similar settlements			-				(3	)			3					-				(37	)			37
Severance (2)			(3	)			-				(3	)				(8	)			-				(8	)
Debt extinguishments gains (losses)			-				(1	)			1					1				(2	)			3
EBITDA			104				306				(202	)				5				728				(723	)
Depreciation and amortization			(68	)			(78	)			10					(203	)			(244	)			41
Interest expense, net			(45	)			(45	)			-					(136	)			(133	)			(3	)
Income (loss) from continuing operations before income taxes		$	(9	)		$	183			$	(192	)			$	(334	)		$	351			$	(685	)
(1) Segment profitability measure consists of open energy gross margin and other margin.
(2) Includes severance from operation and maintenance and general and administrative expenses.
Reference is made to RRI Energy, Inc.'s Annual Report
on Form 10-K for the year ended December 31, 2008.

RRI Energy, Inc. and Subsidiaries
Consolidated Balance Sheets
(Unaudited)
		September 30, 2009					December 31, 2008
ASSETS		(thousands of dollars)
Current Assets:
Cash and cash equivalents		$	1,254,070				$	1,004,367
Restricted cash			3,473					2,721
Accounts and notes receivable, principally customer			145,266					249,871
Inventory			317,993					314,999
Derivative assets			150,302					161,340
Margin deposits			184,117					32,676
Investment in and receivables from Channelview, net			24,271					58,703
Prepayments and other current assets			94,688					124,449
Current assets of discontinued operations ($87,990 and $295,477 of margin deposits)			161,925					2,506,340
Total current assets			2,336,105					4,455,466
Property, plant and equipment, gross			6,544,219					6,417,268
Accumulated depreciation			(1,773,491	)				(1,597,479	)
Property, Plant and Equipment, net			4,770,728					4,819,789
Other Assets:
Other intangibles, net			370,014					380,554
Derivative assets			62,926					78,879
Prepaid lease			292,127					273,374
Other ($33,264 and $29,012 accounted for at fair value)			238,028					219,552
Long-term assets of discontinued operations			10,343					494,781
Total other assets			973,438					1,447,140
Total Assets		$	8,080,271				$	10,722,395
LIABILITIES AND EQUITY
Current Liabilities:
Current portion of long-term debt and short-term borrowings		$	568,420				$	12,517
Accounts payable, principally trade			134,583					156,604
Derivative liabilities			215,727					202,206
Margin deposits			4,538					93,000
Other			240,367					199,026
Current liabilities of discontinued operations ($8,750 and $0 of margin deposits)			71,659					2,375,895
Total current liabilities			1,235,294					3,039,248
Other Liabilities:
Derivative liabilities			87,637					140,493
Other			296,612					272,079
Long-term liabilities of discontinued operations			19,483					873,190
Total other liabilities			403,732					1,285,762
Long-term Debt			1,984,792					2,610,737
Commitments and Contingencies
Temporary Equity Stock-based Compensation			5,765					9,004
Stockholders' Equity:
Preferred stock; par value $0.001 per share (125,000,000 shares authorized; none outstanding)			-					-
Common stock; par value $0.001 per share (2,000,000,000 shares authorized; 352,757,922 and 349,812,537 issued)			114					111
Additional paid-in capital			6,257,995					6,238,639
Accumulated deficit			(1,738,476	)				(2,375,201	)
Accumulated other comprehensive loss			(68,945	)				(85,905	)
Total stockholders' equity			4,450,688					3,777,644
Total Liabilities and Equity		$	8,080,271				$	10,722,395
Reference is made to RRI Energy, Inc.'s Annual Report
on Form 10-K for the year ended December 31, 2008.

RRI Energy, Inc. and Subsidiaries
Consolidated Statements of Cash Flows
(Unaudited)
		Nine Months Ended September 30,
		2009					2008
		(thousands of dollars)
Cash Flows from Operating Activities:
Net income (loss)		$	636,725				$	(302,020	)
(Income) loss from discontinued operations			(864,467	)				490,511
Net income (loss) from continuing operations			(227,742	)				188,491
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities:
Depreciation and amortization			203,228					244,059
Deferred income taxes			(106,923	)				136,909
Net changes in energy derivatives			30,748					(57,900	)
Amortization of deferred financing costs			6,459					4,949
Gains on sales of assets and emission and exchange allowances, net			(21,184	)				(39,484	)
Western states litigation and similar settlements			-					37,467
Other, net			(2,446	)				(2,158	)
Changes in other assets and liabilities:
Accounts and notes receivable, net			117,255					17,133
Change in notes, receivables and payables with affiliates, net			68					4,183
Inventory			(1,399	)				(42,484	)
Margin deposits, net			(239,903	)				28,944
Net derivative assets and liabilities			(26,816	)				(5,550	)
Western states litigation and similar settlement payments			(3,449	)				-
Accounts payable			(9,111	)				(53,185	)
Other current assets			7,749					(800	)
Other assets			(19,858	)				(4,774	)
Taxes payable/receivable			(3,479	)				24,034
Other current liabilities			36,779					33,905
Other liabilities			(15,719	)				(8,246	)
Net cash provided by (used in) continuing operations from operating activities			(275,743	)				505,493
Net cash provided by (used in) discontinued operations from operating activities			534,275					(237,392	)
Net cash provided by operating activities			258,532					268,101
Cash Flows from Investing Activities:
Capital expenditures			(157,750	)				(191,059	)
Proceeds from sales of assets, net			35,931					18,429
Proceeds from sales of emission and exchange allowances			19,180					38,685
Purchases of emission allowances			(7,624	)				(26,053	)
Restricted cash			(752	)				(2,705	)
Other, net			3,750					3,312
Net cash used in continuing operations from investing activities			(107,265	)				(159,391	)
Net cash provided by (used in) discontinued operations from investing activities			313,775					(24,636	)
Net cash provided by (used in) investing activities			206,510					(184,027	)
Cash Flows from Financing Activities:
Payments of long-term debt			(59,413	)				(57,704	)
Payments of debt extinguishments			-					(1,017	)
Proceeds from issuances of stock			4,584					13,542
Net cash used in continuing operations from financing activities			(54,829	)				(45,179	)
Net cash used in discontinued operations from financing activities			(260,707	)				-
Net cash used in financing activities			(315,536	)				(45,179	)
Net Change in Cash and Cash Equivalents, Total Operations			149,506					38,895
Less: Net Change in Cash and Cash Equivalents, Discontinued Operations			(100,197	)				(90,596	)
Cash and Cash Equivalents at Beginning of Period, Continuing Operations			1,004,367					524,070
Cash and Cash Equivalents at End of Period, Continuing Operations		$	1,254,070				$	653,561
Free Cash Flow Reconciliation
(Unaudited)
		Nine Months Ended September 30,
		2009					2008
		(millions of dollars)
Operating cash flow from continuing operations		$	(275	)			$	505
Western states litigation and similar settlements payments			3					-
Change in margin deposits, net			240					(29	)
Adjusted cash flow provided by (used in) continuing operations			(32	)				476
Capital expenditures			(158	)				(191	)
Proceeds from sales of emission and exchange allowances			19					39
Purchases of emission allowances			(8	)				(26	)
Free cash flow provided by (used in) continuing operations		$	(179	)			$	298
Reference is made to RRI Energy, Inc.'s Annual Report
on Form 10-K for the year ended December 31, 2008.

RRI Energy, Inc. and Subsidiaries
Power Generation Data
(Unaudited)
		Three Months Ended September 30,																Nine Months Ended September 30,
		2009								2008								2009								2008
		GWh				% Economic (1)				GWh				% Economic (1)				GWh				% Economic (1)				GWh				% Economic (1)
Economic Generation (2) (3):
East Coal			5,524.6				55	%			5,776.5			57	%				17,886.4				60	%			20,464.7			68	%
East Gas			1,028.4				12	%			766.0			9	%				1,701.7				7	%			1,178.8			5	%
West			288.4				5	%			1,405.9			20	%				576.5				3	%			1,952.9			9	%
Other			11.6				1	%			63.5			3	%				74.7				1	%			70.4			2	%
Total			6,853.0				26	%			8,011.9			29	%				20,239.3				26	%			23,666.8			31	%
Commercial Capacity Factor (4):
East Coal			89.5	%							90.7	%							82.3	%							85.7	%
East Gas			97.6	%							90.2	%							96.3	%							90.8	%
West			94.6	%							96.9	%							86.3	%							93.9	%
Other			100.0	%							81.7	%							98.9	%							81.7	%
Total			90.9	%							91.6	%							83.6	%							86.6	%
Generation (3):		GWh								GWh								GWh								GWh
East Coal			4,943.5								5,237.8								14,711.6								17,529.0
East Gas			1,004.1								690.9								1,638.4								1,070.6
West			272.7								1,361.7								497.7								1,834.0
Other			11.6								51.9								73.9								57.5
Total			6,231.9								7,342.3								16,921.6								20,491.1
Open Energy Unit Margin ($/MWh) (5):
East Coal		$	8.70							$	33.41							$	12.10							$	34.91
East Gas			11.95								28.95								10.99								37.36
West			11.00								5.14								24.11								NM		(6)
Other			-								19.27								-								17.39
Weighted average total		$	9.31							$	27.65							$	12.29							$	31.82
		Three Months Ended September 30,																Nine Months Ended September 30,
		2009				2008				Change								2009				2008				Change
		(in millions)																(in millions)
East Coal
Open energy gross margin (7)		$	43			$	175			$	(132	)						$	178			$	612			$	(434	)
Other margin (8)			57				53				4								134				102				32
Open gross margin (9)		$	100			$	228			$	(128	)						$	312			$	714			$	(402	)
East Gas
Open energy gross margin (7)		$	12			$	20			$	(8	)						$	18			$	40			$	(22	)
Other margin (8)			55				46				9								137				106				31
Open gross margin (9)		$	67			$	66			$	1							$	155			$	146			$	9
West
Open energy gross margin (7)		$	3			$	7			$	(4	)						$	12			$	(1	)		$	13
Other margin (8)			78				83				(5	)							102				139				(37	)
Open gross margin (9)		$	81			$	90			$	(9	)						$	114			$	138			$	(24	)
Other
Open energy gross margin (7)		$	-			$	1			$	(1	)						$	-			$	1			$	(1	)
Other margin (8)			19				16				3								48				41				7
Open gross margin (9)		$	19			$	17			$	2							$	48			$	42			$	6
Total
Open energy gross margin (7)		$	58			$	203			$	(145	)						$	208			$	652			$	(444	)
Other margin (8)			209				198				11								421				388				33
Open gross margin		$	267			$	401			$	(134	)						$	629			$	1,040			$	(411	)
(1) Generally represents economic generation (hours) divided by maximum generation hours (maximum plant capacity multiplied by 8,760 hours).
(2) Estimated generation at 100% plant availability based on an hourly analysis of when it is economical to generate based on the price of power, fuel, emission allowances and variable operating costs.
(3) Excludes generation related to power purchase agreements, including tolling agreements.
(4) Generation divided by economic generation.
(5) Represents open energy gross margin divided by generation.
(6) NM is not meaningful.
(7) Open energy gross margin is calculated using the power sales prices received by the plants less market based delivered fuel cost. This figure excludes the effects of other margin, hedges and other items and unrealized gains/losses on energy derivatives.
(8) Other margin represents power purchase agreements, capacity payments, ancillary services revenues and selective commercial strategies.
(9) Segment profitability measure.
Reference is made to RRI Energy, Inc.'s Annual Report
on Form 10-K for the year ended December 31, 2008.

RRI Energy, Inc. and Subsidiaries
East Coal
(Unaudited)
		Capacity		Heat Rate		Q3 economic generation (GWh)				Q3 commercial capacity factor						Q3 generation (GWh)
Unit Name (1)		(MW)		(MMBtu/MWh)		2009		2008		2009			2008			2009		2008
Cheswick		560		10.0		888.5		489.0		91.2	%		96.3	%		810.5		471.0
Conemaugh (2)		280		9.4		502.1		551.8		93.9	%		89.1	%		471.3		491.7
Elrama		460		11.3		33.1		145.1		98.2	%		87.5	%		32.5		127.0
Keystone (2)		282		9.5		583.1		606.4		87.2	%		97.5	%		508.5		591.3
Portland		401		9.8		621.6		608.1		80.6	%		89.7	%		501.1		545.4
Seward		525		9.6		1,053.4		1,088.0		95.9	%		88.3	%		1,010.3		960.9
Shawville (2)		597		10.3		552.2		1,050.7		91.1	%		83.0	%		503.3		871.7
Titus		243		10.8		217.2		299.1		88.4	%		97.1	%		191.9		290.3
Avon Lake		721		9.3		818.2		487.7		84.3	%		99.9	%		690.1		487.3
New Castle		328		10.6		158.3		259.7		92.5	%		96.8	%		146.5		251.4
Niles		216		10.5		96.9		190.9		80.0	%		78.5	%		77.5		149.8
East Coal Total		4,613				5,524.6		5,776.5		89.5	%		90.7	%		4,943.5		5,237.8
		Capacity		Heat Rate		Q3 YTD economic generation (GWh)				Q3 YTD commercial capacity factor						Q3 YTD generation (GWh)
Unit Name (1)		(MW)		(MMBtu/MWh)		2009		2008		2009			2008			2009		2008
Cheswick		560		10.0		2,634.2		1,929.5		77.8	%		94.1	%		2,050.6		1,816.0
Conemaugh (2)		280		9.4		1,579.0		1,727.8		94.8	%		88.9	%		1,496.9		1,535.6
Elrama		460		11.3		316.7		1,211.4		88.1	%		83.1	%		278.9		1,007.0
Keystone (2)		282		9.5		1,759.0		1,810.5		81.4	%		98.1	%		1,432.0		1,776.2
Portland		401		9.8		2,069.6		2,011.7		81.8	%		76.4	%		1,693.7		1,536.6
Seward		525		9.6		3,111.7		3,251.6		76.4	%		81.8	%		2,377.0		2,658.3
Shawville (2)		597		10.3		2,043.0		3,143.0		81.0	%		83.6	%		1,654.7		2,628.3
Titus		243		10.8		888.2		1,033.2		86.1	%		87.7	%		765.1		906.4
Avon Lake		721		9.3		2,586.0		2,432.0		89.5	%		83.6	%		2,313.2		2,033.3
New Castle		328		10.6		539.2		1,063.1		83.4	%		88.9	%		449.8		945.4
Niles		216		10.5		359.8		850.9		55.5	%		80.6	%		199.7		685.9
East Coal Total		4,613				17,886.4		20,464.7		82.3	%		85.7	%		14,711.6		17,529.0
(1) Unless otherwise indicated, the Company owns a 100% interest in each facility listed.
(2) The Company leases a 100% interest in the Shawville facility, a 16.67% interest in the Keystone facility and a 16.45% interest in the Conemaugh facility under facility interest lease agreements, which expire in 2026, 2034 and 2034, respectively.
Reference is made to RRI Energy, Inc.'s Annual Report
on Form 10-K for the year ended December 31, 2008.

RRI Energy, Inc. and Subsidiaries
East Gas
(Unaudited)
		Capacity		Heat Rate		Q3 economic generation (GWh)				Q3 commercial capacity factor						Q3 generation (GWh)
Unit Name (1)		(MW)		(MMBtu/MWh)		2009		2008		2009			2008			2009		2008
Aurora (2)		878		10.5		2.8		23.1		100.0	%		100.0	%		2.8		23.1
Blossburg		19		14.6		2.5		0.7		100.0	%		100.0	%		2.5		0.7
Brunot Island		289		10.4		0.2		0.8		100.0	%		100.0	%		0.2		0.8
Gilbert		536		11.0		4.0		18.1		100.0	%		100.0	%		4.0		18.1
Glen Gardner		160		14.6		0.4		0.5		75.0	%		100.0	%		0.3		0.5
Hamilton		20		14.8		0.1		0.1		100.0	%		100.0	%		0.1		0.1
Hunterstown		60		14.8		0.2		1.1		100.0	%		100.0	%		0.2		1.1
Hunterstown CCGT		810		7.0		1,014.8		709.1		97.6	%		89.7	%		990.6		635.8
Mountain		40		14.3		0.3		1.6		100.0	%		100.0	%		0.3		1.6
Orrtanna		20		14.4		0.1		0.2		100.0	%		100.0	%		0.1		0.2
Portland		169		11.2		0.7		0.9		100.0	%		100.0	%		0.7		0.9
Sayreville		224		13.8		0.3		5.4		100.0	%		68.5	%		0.3		3.7
Shawnee		20		14.0		0.2		-		100.0	%		0.0	%		0.2		-
Shawville 5-7 (3)		6		10.2		-		-		0.0	%		0.0	%		-		-
Titus		31		17.4		-		-		0.0	%		0.0	%		-		-
Tolna		39		14.2		0.2		0.7		100.0	%		100.0	%		0.2		0.7
Warren		68		12.8		-		-		0.0	%		0.0	%		-		-
Werner		212		13.8		0.6		1.8		100.0	%		94.4	%		0.6		1.7
Shelby		356		9.8		1.0		1.9		100.0	%		100.0	%		1.0		1.9
East Gas Total		3,957				1,028.4		766.0		97.6	%		90.2	%		1,004.1		690.9
		Capacity		Heat Rate		Q3 YTD economic generation (GWh)				Q3 YTD commercial capacity factor						Q3 YTD generation (GWh)
Unit Name (1)		(MW)		(MMBtu/MWh)		2009		2008		2009			2008			2009		2008
Aurora (2)		878		10.5		14.0		34.4		99.3	%		100.0	%		13.9		34.4
Blossburg		19		14.6		2.6		7.9		100.0	%		92.4	%		2.6		7.3
Brunot Island		289		10.4		3.6		2.1		100.0	%		100.0	%		3.6		2.1
Gilbert		536		11.0		12.3		36.8		100.0	%		100.0	%		12.3		36.8
Glen Gardner		160		14.6		0.4		3.0		75.0	%		86.7	%		0.3		2.6
Hamilton		20		14.8		0.6		0.4		100.0	%		100.0	%		0.6		0.4
Hunterstown		60		14.8		1.6		2.6		100.0	%		100.0	%		1.6		2.6
Hunterstown CCGT		810		7.0		1,655.3		1,016.3		96.3	%		90.8	%		1,594.2		922.9
Mountain		40		14.3		2.0		5.3		100.0	%		100.0	%		2.0		5.3
Orrtanna		20		14.4		0.6		0.5		33.3	%		100.0	%		0.2		0.5
Portland		169		11.2		2.6		10.3		100.0	%		100.0	%		2.6		10.3
Sayreville		224		13.8		1.7		44.2		88.2	%		71.7	%		1.5		31.7
Shawnee		20		14.0		0.2		0.1		100.0	%		100.0	%		0.2		0.1
Shawville 5-7 (3)		6		10.2		0.1		-		100.0	%		0.0	%		0.1		-
Titus		31		17.4		-		-		0.0	%		0.0	%		-		-
Tolna		39		14.2		0.5		1.7		100.0	%		100.0	%		0.5		1.7
Warren		68		12.8		-		-		0.0	%		0.0	%		-		-
Werner		212		13.8		2.6		9.4		46.2	%		86.2	%		1.2		8.1
Shelby		356		9.8		1.0		3.8		100.0	%		100.0	%		1.0		3.8
East Gas Total		3,957				1,701.7		1,178.8		96.3	%		90.8	%		1,638.4		1,070.6
(1) Unless otherwise indicated, the Company owns a 100% interest in each facility listed.
(2) Excludes generation during periods the unit operated under power purchase agreements.
(3) The Company leases a 100% interest in the Shawville facility under a facility interest lease agreement, which expires in 2026.
Reference is made to RRI Energy, Inc.'s Annual Report
on Form 10-K for the year ended December 31, 2008.

RRI Energy, Inc. and Subsidiaries
West and Other
(Unaudited)
West
		Capacity		Heat Rate		Q3 economic generation (GWh)				Q3 commercial capacity factor						Q3 generation (GWh)
Unit Name (1)		(MW)		(MMBtu/MWh)		2009		2008		2009			2008			2009		2008
Bighorn (2)		598		7.2		-		582.3		0.0	%		94.8	%		-		552.2
Coolwater		622		10.1		25.4		189.0		89.8	%		96.8	%		22.8		182.9
Ellwood (3)		54		13.3		-		-		0.0	%		0.0	%		-		-
Etiwanda (3)		640		10.0		-		-		0.0	%		0.0	%		-		-
Mandalay (3)		560		10.9		107.0		219.3		87.9	%		97.3	%		94.0		213.3
Ormond Beach		1,516		9.6		156.0		415.3		99.9	%		99.5	%		155.9		413.3
West Total		3,990				288.4		1,405.9		94.6	%		96.9	%		272.7		1,361.7
		Capacity		Heat Rate		Q3 YTD economic generation (GWh)				Q3 YTD commercial capacity factor						Q3 YTD generation (GWh)
Unit Name (1)		(MW)		(MMBtu/MWh)		2009		2008		2009			2008			2009		2008
Bighorn (2)		598		7.2		-		582.8		0.0	%		94.8	%		-		552.7
Coolwater		622		10.1		102.8		363.3		37.8	%		90.9	%		38.9		330.3
Ellwood (3)		54		13.3		-		-		0.0	%		0.0	%		-		-
Etiwanda (3)		640		10.0		-		-		0.0	%		0.0	%		-		-
Mandalay (3)		560		10.9		223.5		381.0		93.4	%		96.0	%		208.7		365.8
Ormond Beach		1,516		9.6		250.2		625.8		100.0	%		93.5	%		250.1		585.2
West Total		3,990				576.5		1,952.9		86.3	%		93.9	%		497.7		1,834.0
Other
		Capacity		Heat Rate		Q3 economic generation (GWh)				Q3 commercial capacity factor						Q3 generation (GWh)
Unit Name (1)		(MW)		(MMBtu/MWh)		2009		2008		2009			2008			2009		2008
Choctaw		800		7.0		11.6		62.9		100.0	%		81.6	%		11.6		51.3
Indian River (3)		587		10.5		-		-		0.0	%		0.0	%		-		-
Osceola (3)		470		11.0		-		0.6		0.0	%		100.0	%		-		0.6
Other Total		1,857				11.6		63.5		100.0	%		81.7	%		11.6		51.9
		Capacity		Heat Rate		Q3 YTD economic generation (GWh)				Q3 YTD commercial capacity factor						Q3 YTD generation (GWh)
Unit Name (1)		(MW)		(MMBtu/MWh)		2009		2008		2009			2008			2009		2008
Choctaw		800		7.0		73.2		66.9		98.9	%		80.7	%		72.4		54.0
Indian River (3)		587		10.5		-		-		0.0	%		0.0	%		-		-
Osceola (3)		470		11.0		1.5		3.5		100.0	%		100.0	%		1.5		3.5
Other Total		1,857				74.7		70.4		98.9	%		81.7	%		73.9		57.5
(1) Unless otherwise indicated, the Company owns a 100% interest in each facility listed.
(2) The Bighorn facility was sold in October 2008.
(3) Excludes generation during periods the unit operated under power purchase agreements.
Reference is made to RRI Energy, Inc.'s Annual Report
on Form 10-K for the year ended December 31, 2008.

RRI Energy, Inc. and Subsidiaries
Capital Expenditures
(Unaudited)
		Nine months ended September 30,						Projected Annual Outlook
		2009			2008			2009E			2010E
		(in millions)						(in millions)
Maintenance capital expenditures		$	45		$	39		$	57		$	51
Environmental			91			141			111	(1)		25	(1)
Capitalized interest			22	(2)		11	(2)		30	(2)		10	(3)
Total environmental and cap interest			113			152			141			35
Total capital expenditures		$	158		$	191		$	198		$	86
(1) Estimate represents the low end of the range.
(2) Relates primarily to scrubber projects at Cheswick and Keystone.
(3) Relates primarily to a scrubber project at Cheswick.
Reference is made to RRI Energy, Inc.'s Annual Report
on Form 10-K for the year ended December 31, 2008.

RRI Energy, Inc. and Subsidiaries
GAAP Debt, Gross Debt and Net Debt
(Unaudited)
		September 30, 2009
		(in millions)
Senior secured revolver		$	-
Senior secured notes (1)			437
Senior unsecured notes			1,300
Orion Power 12% notes (2)			408
PEDFA fixed-rate bonds for Seward plant (3)			408
GAAP debt		$	2,553
Orion Power 12% notes purchase accounting adjustment			(8	)
REMA operating leases (off-balance sheet)			423
Gross Debt		$	2,968
Cash and cash equivalents			(1,254	)
Restricted cash			(3	)
Net margin deposits and cash collateral (4) (5)			(278	)
Net Debt		$	1,433
(1) During October 2009, we completed a tender offer and purchased for cash $127 million principal amount. During November 2009, we repurchased for cash $31 million principal amount.
(2) Orion Power 12% notes include purchase accounting adjustment of $8 million.
(3) During October 2009, we completed a tender offer and purchased for cash $2 million principal amount.
(4) Includes $79 million related to discontinued operations.
(5) Includes $19 million related to cash collateral.
Reference is made to RRI Energy, Inc.'s Annual Report
on Form 10-K for the year ended December 31, 2008.