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Share Name | Share Symbol | Market | Type |
---|---|---|---|
Rri Energy | NYSE:RRI | NYSE | Ordinary Share |
Price Change | % Change | Share Price | High Price | Low Price | Open Price | Shares Traded | Last Trade | |
---|---|---|---|---|---|---|---|---|
0.00 | 0.00% | 3.62 | 0.00 | 01:00:00 |
-- Merger with Mirant to create GenOn Energy will create significant near-term value driven by $150 million annual cost savings -- Received stockholder approval from both companies -- Entered into revolving credit facility and agreements to borrow $1.925 billion, which will satisfy the financing condition in the merger agreement -- Received FERC approval and NY Public Service Commission clearance -- Expect to close by the end of the year -- Third quarter financial results improved year-over-year and reflect continued depressed commodity prices and weak economic conditions -- Investments to improve equipment performance resulted in 3% reduction in unplanned outage rate compared to Q1 -- New Castle and Titus power plant non-cash impairments totaling $113 million charged in third quarter
RRI Energy, Inc. today is reporting open EBITDA of $212 million for the third quarter of 2010, compared to $133 million for the third quarter of 2009. The improvement was primarily due to improved energy margins driven by higher heat rates related to warmer weather in July and early August and improved economic conditions compared to the same period last year. The company reported adjusted EBITDA of $212 million in the third quarter of 2010, compared to $100 million in the third quarter of 2009. The improvement was primarily due to the items mentioned above and a reduction in losses from coal hedges. Free cash flow provided by continuing operations during the first nine months of 2010 was $84 million, compared to a use of cash of ($182) million for the first nine months of 2009. The improvement was primarily a result of improved earnings and lower environmental capital expenditures.
"We have made excellent progress toward completing the steps necessary to finalize our proposed merger with Mirant and expect to close the transaction by the end of the year after we receive clearance from the Department of Justice," said Mark Jacobs, president and chief executive officer of RRI Energy. "Third quarter financial results and market conditions have improved relative to last year, but still reflect continued depressed commodity prices and weak economic conditions."
Open EBITDA was $241 million for the first nine months of 2010, compared to $129 million for the same period of 2009. Adjusted EBITDA was $244 million for the first nine months of 2010, compared to $42 million for the same period of 2009. The improvements were due to the same factors as described above, partially offset by increased plant operation and maintenance expenses to improve equipment performance.
Income from continuing operations before income taxes for the third quarter of 2010 was $41 million, compared to a loss from continuing operations of $9 million for the third quarter of 2009. The 2010 reported results include net unrealized gains from energy derivatives of $51 million, $5 million in merger-related costs and a $113 million charge for long-lived assets impairments. The reported numbers for 2009 include net unrealized gains from energy derivatives of $7 million.
The loss from continuing operations before income taxes for the first nine months of 2010 was $361 million, compared to $334 million for the first nine months of 2009. The 2010 reported results include net unrealized gains from energy derivatives of $112 million, a $17 million charge for western states litigation and similar settlements, $19 million in merger-related costs and a $361 million charge for long-lived assets impairments. The reported numbers for 2009 include net unrealized losses from energy derivatives of $30 million and $8 million in severance charges. Operating cash flow from continuing operations was $252 million for the first nine months of 2010, compared to a use of cash of ($275) million for the same period of 2009.
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 -- Other margin -- Open gross margin -- Total controllable costs -- Total controllable costs/MWh -- Total controllable costs/MW capacity -- Gross debt -- Net debt -- Operation and maintenance, excluding severance -- General and administrative, excluding severance and merger-related costs
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 2010 earnings conference call beginning at 10:00 a.m. Eastern Time on Wednesday, November 3, 2010. 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 routinely posts all important information on its web site at www.rrienergy.com.
Forward-Looking Statements
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," "think", "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, statements about the benefits of the proposed merger involving us and Mirant Corporation, including our future financial position and operating results and the expected timing or ability to obtain necessary approvals and satisfy conditions to complete the merger and the related financings, legislative, regulatory and/or market developments, the outcome of pending or threatened lawsuits, regulatory or tax proceedings or investigations, the effects of competition or regulatory intervention, financial and economic market conditions, access to capital, the timing and extent of changes in law and regulation (including environmental), commodity prices, prevailing demand and market prices for electricity, capacity, fuel and emission allowances, weather conditions, operational constraints or outages, fuel supply or transmission issues, hedging ineffectiveness and other factors we discuss or refer to in the "Risk Factors" sections of our most recent Annual Report on Form 10-K and Quarterly Report on Form 10-Q filed with the Securities and Exchange Commission (SEC). 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.
Additional Information and Where To Find It
This news release does not constitute an offer to sell or the solicitation of an offer to buy any securities nor shall there be any sale of securities in any jurisdiction in which such offer, solicitation or sale would be unlawful prior to registration or qualification under the securities laws of any such jurisdiction. In connection with the proposed merger between us and Mirant, we filed with the SEC a registration statement on Form S-4 that includes a joint proxy statement of us and Mirant and that also constitutes a prospectus of us. The registration statement was declared effective by the SEC on September 13, 2010. We and Mirant urge investors and shareholders to read the registration statement, and any other relevant documents filed with the SEC, including the joint proxy statement/prospectus that is a part of the registration statement, because they contain important information. You may obtain copies of all documents filed with the SEC regarding this transaction, free of charge, at the SEC's website (www.sec.gov). You may also obtain these documents, free of charge, from our website (www.rrienergy.com) under the tab "Investor Relations" and then under the heading "Company Filings." You may also obtain these documents, free of charge, from Mirant's website (www.mirant.com) under the tab "Investor Relations" and then under the heading "SEC Filings."
RRI Energy, Inc. and Subsidiaries Consolidated Statements of Operations (Unaudited) Three Months Ended Nine Months Ended September 30, September 30, ---------------------- ---------------------- 2010 2009 2010 2009 ---------- ---------- ---------- ---------- (thousands of dollars, except per share amounts) Revenues: Revenues (including $49,536, $(25,095), $98,621 and $(51,225) unrealized gains (losses)) $ 697,556 $ 507,179 $1,702,464 $1,363,140 ---------- ---------- ---------- ---------- Expenses: Cost of sales (including $856, $31,826, $13,278 and $20,857 unrealized gains) 305,616 267,632 837,415 872,373 Operation and maintenance 116,196 114,457 459,815 428,567 General and administrative 20,215 23,686 76,403 80,345 Western states litigation and similar settlements - - 17,000 - Gains on sales of assets and emission and exchange allowances, net (664) (1,013) (1,700) (21,184) Long-lived assets impairments 112,856 - 360,571 - Depreciation and amortization 64,968 67,724 196,436 203,228 ---------- ---------- ---------- ---------- Total operating expense 619,187 472,486 1,945,940 1,563,329 ---------- ---------- ---------- ---------- Operating Income (Loss) 78,369 34,693 (243,476) (200,189) ---------- ---------- ---------- ---------- Other Income (Expense): Debt extinguishments gains (losses) - (103) - 741 Interest expense (39,568) (44,614) (122,197) (136,600) Interest income 126 407 492 1,376 Other, net 2,040 880 4,663 942 ---------- ---------- ---------- ---------- Total other expense (37,402) (43,430) (117,042) (133,541) ---------- ---------- ---------- ---------- Income (Loss) from Continuing Operations Before Income Taxes 40,967 (8,737) (360,518) (333,730) Income tax expense (benefit) 18,805 9,532 69,657 (105,988) ---------- ---------- ---------- ---------- Income (Loss) from Continuing Operations 22,162 (18,269) (430,175) (227,742) Income from discontinued operations 664 2,841 4,178 864,467 ---------- ---------- ---------- ---------- Net Income (Loss) $ 22,826 $ (15,428) $ (425,997) $ 636,725 ========== ========== ========== ========== Basic and Diluted Earnings (Loss) Per Share: Income (loss) from continuing operations $ 0.06 $ (0.05) $ (1.22) $ (0.65) Income from discontinued operations - 0.01 0.01 2.46 ---------- ---------- ---------- ---------- Net income (loss) $ 0.06 $ (0.04) $ (1.21) $ 1.81 ========== ========== ========== ========== Weighted Average Common Shares Outstanding (in thousands): - Basic 353,520 351,561 353,434 350,908 - Diluted 353,705 351,561 353,434 350,908 Reference is made to RRI Energy, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2009 RRI Energy, Inc. and Subsidiaries Results of Operations by Segment and Adjusted and Open Data (Unaudited) Three Months Ended Nine Months Ended September 30, September 30, ---------------------- ---------------------- 2010 2009 Change 2010 2009 Change ------ ------ ------ ------ ------ ------ (millions of dollars) East coal open gross margin (1) $ 172 $ 100 $ 72 $ 427 $ 310 $ 117 East gas open gross margin (1) 85 67 18 196 155 41 West open gross margin (1) 71 81 (10) 101 118 (17) Other open gross margin (1) 14 19 (5) 28 46 (18) ------ ------ ------ ------ ------ ------ Total 342 267 75 752 629 123 Operation and maintenance, excluding severance (116) (114) (2) (458) (424) (34) General and administrative, excluding severance and merger-related costs (16) (21) 5 (58) (77) 19 Other income (loss), net 2 1 1 5 1 4 ------ ------ ------ ------ ------ ------ Open EBITDA 212 133 79 241 129 112 ------ ------ ------ ------ ------ ------ Hedges and other items (1) (34) 33 1 (108) 109 Gains on sales of assets and emission and exchange allowances, net 1 1 - 2 21 (19) ------ ------ ------ ------ ------ ------ Adjusted EBITDA 212 100 112 244 42 202 ------ ------ ------ ------ ------ ------ Unrealized gains (losses) on energy derivatives 51 7 44 112 (30) 142 Western states litigation and similar settlements - - - (17) - (17) Severance (2) - (3) 3 (2) (8) 6 Merger-related costs (3) (5) - (5) (19) - (19) Long-lived assets impairments (113) - (113) (361) - (361) Debt extinguishments gains - - - - 1 (1) ------ ------ ------ ------ ------ ------ EBITDA 145 104 41 (43) 5 (48) ------ ------ ------ ------ ------ ------ Depreciation and amortization (65) (68) 3 (196) (203) 7 Interest expense, net (39) (45) 6 (122) (136) 14 ------ ------ ------ ------ ------ ------ Income (loss) from continuing operations before income taxes $ 41 $ (9) $ 50 $ (361) $ (334) $ (27) ====== ====== ====== ====== ====== ====== (1) Segment profitability measure consists of open energy gross margin and other margin. (2) Includes severance classified in operation and maintenance and general and administrative expenses. (3) Includes merger-related costs classified in general and administrative. Reference is made to RRI Energy, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2009 RRI Energy, Inc. and Subsidiaries Consolidated Balance Sheets September 30, December 31, 2010 2009 ------------ ------------ (thousands of dollars, except per share amounts) ASSETS (Unaudited) Current Assets: Cash and cash equivalents $ 781,097 $ 943,440 Restricted cash 6,930 24,093 Accounts and notes receivable, principally customer, net 124,054 152,569 Inventory 280,612 331,584 Derivative assets 175,146 132,062 Margin deposits 124,953 198,582 Prepayments and other current assets 86,404 86,844 Current assets of discontinued operations ($14,823 and $55,855 of margin deposits) 40,641 108,476 ------------ ------------ Total current assets 1,619,837 1,977,650 ------------ ------------ Property, plant and equipment, gross 5,766,852 6,330,879 Accumulated depreciation (1,644,285) (1,728,566) ------------ ------------ Property, Plant and Equipment, net 4,122,567 4,602,313 ------------ ------------ Other Assets: Other intangibles, net 290,977 305,913 Derivative assets 51,488 53,138 Prepaid lease 285,772 277,370 Other ($27,655 and $33,793 accounted for at fair value) 198,165 239,078 Long-term assets of discontinued operations 3,230 5,232 ------------ ------------ Total other assets 829,632 880,731 ------------ ------------ Total Assets $ 6,572,036 $ 7,460,694 ============ ============ LIABILITIES AND EQUITY Current Liabilities: Current portion of long-term debt $ 108 $ 404,505 Accounts payable, principally trade 99,346 142,787 Derivative liabilities 88,714 151,461 Margin deposits 33,479 2,860 Other 233,318 169,898 Current liabilities of discontinued operations ($0 and $11,000 of margin deposits) 14,891 58,452 ------------ ------------ Total current liabilities 469,856 929,963 ------------ ------------ Other Liabilities: Derivative liabilities 35,964 61,436 Other 265,069 260,547 Long-term liabilities of discontinued operations 13,315 13,700 ------------ ------------ Total other liabilities 314,348 335,683 ------------ ------------ Long-term Debt 1,949,689 1,949,771 ------------ ------------ Commitments and Contingencies Temporary Equity Stock-based Compensation 7,303 6,890 ------------ ------------ 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; 353,432,149 and 352,785,985 issued) 114 114 Additional paid-in capital 6,268,528 6,259,248 Accumulated deficit (2,398,386) (1,972,389) Accumulated other comprehensive loss (39,416) (48,586) ------------ ------------ Total stockholders' equity 3,830,840 4,238,387 ------------ ------------ Total Liabilities and Equity $ 6,572,036 $ 7,460,694 ============ ============ Reference is made to RRI Energy, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2009 RRI Energy, Inc. and Subsidiaries Consolidated Statements of Cash Flows (Unaudited) Nine Months Ended September 30, -------------------------- 2010 2009 ------------ ------------ (thousands of dollars) Cash Flows from Operating Activities: Net income (loss) $ (425,997) $ 636,725 Income from discontinued operations (4,178) (864,467) ------------ ------------ Loss from continuing operations (430,175) (227,742) Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities: Depreciation and amortization 196,436 203,228 Deferred income taxes 67,566 (106,923) Net changes in energy derivatives (107,469) 30,748 Gains on sales of assets and emission and exchange allowances, net (1,700) (21,184) Western states litigation and similar settlements 17,000 - Long-lived assets impairments 360,571 - Amortization of deferred financing costs 5,220 5,405 Other, net (7,426) (1,392) Changes in other assets and liabilities: Accounts and notes receivable, net 29,411 117,255 Inventory 48,189 (1,399) Margin deposits, net 104,248 (239,903) Net derivative assets and liabilities (2,358) (26,816) Western states litigation and similar settlement payments - (3,449) Accounts payable (23,814) (9,111) Other current assets 361 7,817 Other assets (17,165) (19,858) Taxes payable/receivable 773 (3,479) Other current liabilities 23,726 36,779 Other liabilities (10,911) (15,719) ------------ ------------ Net cash provided by (used in) continuing operations from operating activities 252,483 (275,743) Net cash provided by discontinued operations from operating activities 34,586 534,275 ------------ ------------ Net cash provided by operating activities 287,069 258,532 ------------ ------------ Cash Flows from Investing Activities: Capital expenditures (64,041) (157,750) Proceeds from sales of assets, net 8,385 35,931 Proceeds from sales of emission and exchange allowances 139 19,180 Purchases of emission allowances (270) (7,624) Other, net 4,863 2,998 ------------ ------------ Net cash used in continuing operations from investing activities (50,924) (107,265) Net cash provided by (used in) discontinued operations from investing activities (4,402) 313,775 ------------ ------------ Net cash provided by (used in) investing activities (55,326) 206,510 ------------ ------------ Cash Flows from Financing Activities: Payments of long-term debt (399,809) (59,413) Proceeds from issuances of stock 1,899 4,584 ------------ ------------ Net cash used in continuing operations from financing activities (397,910) (54,829) Net cash used in discontinued operations from financing activities - (260,707) ------------ ------------ Net cash used in financing activities (397,910) (315,536) ------------ ------------ Net Change in Cash and Cash Equivalents, Total Operations (166,167) 149,506 Less: Net Change in Cash and Cash Equivalents, Discontinued Operations (3,824) (100,197) Cash and Cash Equivalents at Beginning of Period, Continuing Operations 943,440 1,004,367 ------------ ------------ Cash and Cash Equivalents at End of Period, Continuing Operations $ 781,097 $ 1,254,070 ============ ============ Free Cash Flow Reconciliation (Unaudited) Nine Months Ended September 30, -------------------------- 2010 2009 ------------ ------------ (millions of dollars) Operating cash flow from continuing operations $ 252 $ (275) Change in margin deposits, net (104) 240 ------------ ------------ Adjusted cash flow provided by (used in) continuing operations 148 (35) ------------ ------------ Capital expenditures (64) (158) Proceeds from sales of emission and exchange allowances - 19 Purchases of emission allowances - (8) ------------ ------------ Free cash flow provided by (used in) continuing operations $ 84 $ (182) ============ ============ Reference is made to RRI Energy, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2009 RRI Energy, Inc. and Subsidiaries Power Generation Operational and Financial Data (Unaudited) Three Months Ended Nine Months Ended September 30, September 30, ---------------------------- ---------------------------- 2010 2009 Change 2010 2009 Change -------- -------- -------- -------- -------- -------- (in millions) (in millions) East Coal Open energy gross margin (1) $ 113 $ 43 $ 70 $ 269 $ 178 $ 91 Other margin (2) 59 57 2 158 132 26 -------- -------- -------- -------- -------- -------- Open gross margin (3)(4) $ 172 $ 100 $ 72 $ 427 $ 310 $ 117 ======== ======== ======== ======== ======== ======== East Gas Open energy gross margin (1) $ 27 $ 12 $ 15 $ 37 $ 18 $ 19 Other margin (2) 58 55 3 159 137 22 -------- -------- -------- -------- -------- -------- Open gross margin (3)(4) $ 85 $ 67 $ 18 $ 196 $ 155 $ 41 ======== ======== ======== ======== ======== ======== West Open energy gross margin (1) $ 7 $ 3 $ 4 $ 7 $ 12 $ (5) Other margin (2) 64 78 (14) 94 106 (12) -------- -------- -------- -------- -------- -------- Open gross margin (3)(4) $ 71 $ 81 $ (10) $ 101 $ 118 $ (17) ======== ======== ======== ======== ======== ======== Other Open energy gross margin (1) $ 3 $ - $ 3 $ 3 $ - $ 3 Other margin (2) 11 19 (8) 25 46 (21) -------- -------- -------- -------- -------- -------- Open gross margin (3)(4) $ 14 $ 19 $ (5) $ 28 $ 46 $ (18) ======== ======== ======== ======== ======== ======== Total Open energy gross margin (1) $ 150 $ 58 $ 92 $ 316 $ 208 $ 108 Other margin (2) 192 209 (17) 436 421 15 -------- -------- -------- -------- -------- -------- Open gross margin (4) $ 342 $ 267 $ 75 $ 752 $ 629 $ 123 ======== ======== ======== ======== ======== ======== Total margin capture factor (5) 92.1% 94.8% -2.7% 87.0% 89.5% -2.5% Three Months Ended Nine Months Ended September 30, September 30, ---------------------------- ---------------------------- 2010 2009 Change 2010 2009 Change -------- -------- -------- -------- -------- -------- Generation (GWh) (6): East Coal 5,513.9 4,943.5 570.4 15,592.3 14,711.6 880.7 East Gas 904.3 1,004.1 (99.8) 1,691.7 1,638.4 53.3 West 168.3 272.7 (104.4) 194.8 497.7 (302.9) Other 356.6 11.6 345.0 394.0 73.9 320.1 -------- -------- -------- -------- -------- -------- Total 6,943.1 6,231.9 711.2 17,872.8 16,921.6 951.2 ======== ======== ======== ======== ======== ======== Open Energy Unit Margin ($/MWh) (7): East Coal $ 20.49 $ 8.70 $ 11.79 $ 17.25 $ 12.10 $ 5.15 East Gas 29.86 11.95 17.91 21.87 10.99 10.88 West 41.59 11.00 30.59 35.93 24.11 11.82 Other 8.41 - 8.41 7.61 - 7.61 -------- -------- -------- -------- -------- -------- Weighted average total $ 21.60 $ 9.31 $ 12.29 $ 17.68 $ 12.29 $ 5.39 ======== ======== ======== ======== ======== ======== (1) Open energy gross margin is calculated using the day-ahead and real-time market power sales prices received by the plants less market-based delivered fuel costs. (2) Other margin represents power purchase agreements, capacity payments, ancillary services revenues and selective commercial strategies relating to optimizing our assets. (3) Segment profitability measure. (4) This figure excludes the effects of hedges and other items and unrealized gains/losses on energy derivatives. (5) Total margin capture factor is calculated by dividing open gross margin generated by the plants by the total available open gross margin, assuming 100% availability. (6) Excludes generation related to power purchase agreements. (7) Represents open energy gross margin divided by generation. Reference is made to RRI Energy, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2009 RRI Energy, Inc. and Subsidiaries Total Controllable Costs Metrics (Unaudited) Efficiency Measures - Total Controllable Costs Three Months Ended Nine Months Ended September 30, September 30, ---------------------- ---------------------- 2010 2009 2010 2009 ---------- ---------- ---------- ---------- (in millions, except per MWh and per MW data) Operation and maintenance, excluding severance (1) $ 116 $ 114 $ 458 $ 424 REMA lease expense (15) (15) (45) (45) General and administrative, excluding severance and merger-related costs (1) 16 21 58 77 Maintenance capital expenditures 4 10 24 45 ---------- ---------- ---------- ---------- Total Controllable Costs $ 121 $ 130 $ 495 $ 501 ========== ========== ========== ========== TWh generation 6.9 6.2 17.9 16.9 Total Controllable Costs/MWh $ 18 $ 21 $ 28 $ 30 MW capacity (2) 14,586 14,563 14,586 14,563 Total Controllable Costs ($ thousands)/ MW capacity $ 8.3 $ 8.9 $ 33.9 $ 34.4 Reconciliation Three Months Ended Nine Months Ended September 30, September 30, ---------------------- ---------------------- 2010 2009 2010 2009 ---------- ---------- ---------- ---------- (in millions, except per MWh and per MW data) Operation and maintenance (O&M) $ 116 $ 115 $ 460 $ 429 General and administrative (G&A) 21 23 77 80 Capital expenditures 14 43 64 158 ---------- ---------- ---------- ---------- Total operation and maintenance, general and administrative and capital expenditures $ 151 $ 181 $ 601 $ 667 ========== ========== ========== ========== Total Controllable Costs $ 121 $ 130 $ 495 $ 501 REMA lease expense in operation and maintenance 15 15 45 45 Severance included in operation and maintenance - 1 2 5 Severance included in general and administrative - 2 - 3 Merger-related costs included in general and administrative 5 - 19 - Environmental capital expenditures 10 25 32 91 Capitalized interest - 8 8 22 ---------- ---------- ---------- ---------- Total operation and maintenance, general and administrative and capital expenditures $ 151 $ 181 $ 601 $ 667 ========== ========== ========== ========== TWh generation 6.9 6.2 17.9 16.9 Total O&M, G&A and capital expenditures/MWh $ 22 $ 29 $ 34 $ 39 MW capacity (2) 14,586 14,563 14,586 14,563 Total O&M, G&A and capital expenditures ($ thousands)/MW capacity $ 10.4 $ 12.4 $ 41.2 $ 45.8 (1) Excludes (a) severance charges incurred in connection with (i) repositioning the company in connection with the sale of our retail business and (ii) implementing our plant-specific operating model, classified in operation and maintenance and general and administrative and (b) merger-related costs classified in general and administrative. Merger-related costs include financial advisory fees, legal costs, stock-based compensation expense related to the modification of our stock options and other merger-related expenses. (2) MW capacity changed from September 30, 2009 to September 30, 2010 as a result of MW re-ratings that occurred during the fourth quarter of 2009 and third quarter of 2010. Reference is made to RRI Energy, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2009 RRI Energy, Inc. and Subsidiaries East Coal (Unaudited) Net Heat Q3 Total Margin Q3 Generation Generating Rate Capture Factor (GWh) Capacity (MMBtu/ ---------------- ----------------- Unit Name (MW) MWh) 2010 2009 2010 2009 -------- -------- ------- ------- -------- -------- Cheswick 565 10.0 83.8% 90.8% 674.1 810.5 Conemaugh (1) 281 9.4 95.8% 95.2% 543.9 471.3 Elrama 460 11.3 82.9% 89.3% 181.1 32.5 Keystone (1) 284 9.5 94.4% 92.9% 587.0 508.5 Portland 401 9.8 88.8% 85.7% 599.5 501.1 Seward 525 9.6 94.4% 87.8% 1,050.1 1,010.3 Shawville (1) 597 10.3 85.9% 93.8% 571.3 503.3 Titus 243 10.8 94.7% 93.5% 236.4 191.9 Avon Lake 763 9.3 87.8% 89.3% 704.8 690.1 New Castle 333 10.6 92.6% 96.1% 246.5 146.5 Niles 244 10.5 77.5% 89.5% 119.2 77.5 -------- ------- ------- -------- -------- East Coal Total 4,696 89.4% 90.5% 5,513.9 4,943.5 ======== ======= ======= ======== ======== Net Heat Q3 YTD Total Margin Q3 YTD Generating Rate Capture Factor Generation (GWh) Capacity (MMBtu/ ---------------- ----------------- Unit Name (MW) MWh) 2010 2009 2010 2009 -------- -------- ------- ------- -------- -------- Cheswick 565 10.0 70.0% 81.8% 1,735.1 2,050.6 Conemaugh (1) 281 9.4 92.8% 96.2% 1,453.5 1,496.9 Elrama 460 11.3 80.7% 82.8% 464.8 278.9 Keystone (1) 284 9.5 95.3% 88.6% 1,698.8 1,432.0 Portland 401 9.8 76.8% 84.8% 1,306.4 1,693.7 Seward 525 9.6 81.6% 71.0% 2,732.7 2,377.0 Shawville (1) 597 10.3 84.2% 90.1% 2,154.2 1,654.7 Titus 243 10.8 90.0% 93.6% 636.5 765.1 Avon Lake 763 9.3 83.4% 88.9% 2,351.4 2,313.2 New Castle 333 10.6 93.3% 88.6% 656.2 449.8 Niles 244 10.5 74.5% 70.8% 402.7 199.7 -------- ------- ------- -------- -------- East Coal Total 4,696 82.8% 84.5% 15,592.3 14,711.6 ======== ======= ======= ======== ======== (1) The Company leases a 100% interest in the Shawville plant, a 16.67% interest in the Keystone plant and a 16.45% interest in the Conemaugh plant under facility lease agreements, which expire in 2026, 2034 and 2034, respectively. The table includes our net share of capacity for the coal units of these plants. Reference is made to RRI Energy, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2009 RRI Energy, Inc. and Subsidiaries East Gas (Unaudited) Net Genera- Heat Q3 Total Margin Q3 Generation ting Rate Capture Factor (GWh) Capacity (MMBtu/ ----------------- ---------------- Unit Name (MW) MWh) 2010 2009 2010 2009 ------- ------- ------ ------ ------- ------- Aurora 878 10.5 NM (1) NM (1) 16.5 2.8 Blossburg 19 14.6 NM (1) NM (1) 0.8 2.5 Brunot Island 289 10.4 NM (1) NM (1) 3.9 0.2 Gilbert 536 11.0 NM (1) NM (1) 16.5 4.0 Glen Gardner 160 14.6 NM (1) NM (1) 4.8 0.3 Hamilton 20 14.8 NM (1) NM (1) 0.6 0.1 Hunterstown 60 14.8 NM (1) NM (1) 7.6 0.2 Hunterstown CCGT 810 7.0 88.2% 99.1% 829.8 990.6 Mountain 40 14.3 NM (1) NM (1) 3.6 0.3 Orrtanna 20 14.4 NM (1) NM (1) 1.1 0.1 Portland 169 11.2 NM (1) NM (1) 3.7 0.7 Sayreville 224 13.8 NM (1) NM (1) 3.2 0.3 Shawnee 20 14.0 NM (1) NM (1) 0.2 0.2 Shawville (2) 6 10.2 NM (1) NM (1) - - Titus 31 17.4 NM (1) NM (1) - - Tolna 39 14.2 NM (1) NM (1) 2.6 0.2 Warren 68 12.8 NM (1) NM (1) - - Werner 212 13.8 NM (1) NM (1) 4.0 0.6 Shelby 356 9.8 NM (1) NM (1) 5.4 1.0 ------- ------ ------ ------- ------- East Gas Total 3,957 92.2% 95.1% 904.3 1,004.1 ======= ====== ====== ======= ======= Net Genera- Heat Q3 YTD Total Margin Q3 YTD ting Rate Capture Factor Generation (GWh) Capacity (MMBtu/ ----------------- ---------------- Unit Name (MW) MWh) 2010 2009 2010 2009 ------- ------- ------ ------ ------- ------- Aurora 878 10.5 NM (1) NM (1) 27.9 13.9 Blossburg 19 14.6 NM (1) NM (1) 1.2 2.6 Brunot Island 289 10.4 NM (1) NM (1) 8.9 3.6 Gilbert 536 11.0 NM (1) NM (1) 18.9 12.3 Glen Gardner 160 14.6 NM (1) NM (1) 4.9 0.3 Hamilton 20 14.8 NM (1) NM (1) 0.6 0.6 Hunterstown 60 14.8 NM (1) NM (1) 8.8 1.6 Hunterstown CCGT 810 7.0 91.6% 96.8% 1,593.9 1,594.2 Mountain 40 14.3 NM (1) NM (1) 4.7 2.0 Orrtanna 20 14.4 NM (1) NM (1) 1.2 0.2 Portland 169 11.2 NM (1) NM (1) 3.8 2.6 Sayreville 224 13.8 NM (1) NM (1) 4.4 1.5 Shawnee 20 14.0 NM (1) NM (1) 0.2 0.2 Shawville (2) 6 10.2 NM (1) NM (1) 0.1 0.1 Titus 31 17.4 NM (1) NM (1) - - Tolna 39 14.2 NM (1) NM (1) 2.8 0.5 Warren 68 12.8 NM (1) NM (1) - - Werner 212 13.8 NM (1) NM (1) 4.0 1.2 Shelby 356 9.8 NM (1) NM (1) 5.4 1.0 ------- ------ ------ ------- ------- East Gas Total 3,957 92.0% 93.4% 1,691.7 1,638.4 ======= ====== ====== ======= ======= (1) NM is not meaningful. (2) The Company leases a 100% interest in the Shawville plant under a facility lease agreement, which expires in 2026. The table includes our net share of capacity for the gas units of this plant. Reference is made to RRI Energy, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2009 RRI Energy, Inc. and Subsidiaries West and Other (Unaudited) West Net Genera- Heat Q3 Total Margin Q3 Generation ting Rate Capture Factor (GWh) Capacity (MMBtu/ ------------------ ----------------- Unit Name (MW) MWh) 2010 2009 2010 2009 -------- -------- ------ ------ -------- -------- Coolwater 622 10.1 NM (1) NM (1) 10.4 22.8 Ellwood (2) 54 13.3 NM (1) NM (1) - - Etiwanda (2) 640 10.0 NM (1) NM (1) - - Mandalay (2) 560 10.9 NM (1) NM (1) 55.9 94.0 Ormond Beach 1,516 9.6 NM (1) NM (1) 102.0 155.9 -------- ------- ------ -------- -------- West Total 3,392 97.9% 99.2% 168.3 272.7 ======== ======= ====== ======== ======== Net Genera- Heat Q3 YTD Total Margin Q3 YTD ting Rate Capture Factor Generation (GWh) Capacity (MMBtu/ ------------------ ----------------- Unit Name (MW) MWh) 2010 2009 2010 2009 -------- -------- ------ ------ -------- -------- Coolwater 622 10.1 NM (1) NM (1) 11.2 38.9 Ellwood (2) 54 13.3 NM (1) NM (1) - - Etiwanda (2) 640 10.0 NM (1) NM (1) - - Mandalay (2) 560 10.9 NM (1) NM (1) 66.5 208.7 Ormond Beach 1,516 9.6 NM (1) NM (1) 117.1 250.1 -------- ------- ------ -------- -------- West Total 3,392 94.3% 95.1% 194.8 497.7 ======== ======= ====== ======== ======== Other Net Genera- Heat Q3 Total Margin Q3 Generation ting Rate Capture Factor (GWh) Capacity (MMBtu/ ------------------ ----------------- Unit Name (MW) MWh) 2010 2009 2010 2009 -------- -------- ------ ------ -------- -------- Choctaw 800 7.0 NM (1) NM (1) 356.6 11.6 Indian River (2)(3) 587 10.5 NM (1) NM (1) - - Osceola (2) 470 11.0 NM (1) NM (1) - - Sabine (4) 54 N/A N/A N/A N/A N/A Vandolah (5) 630 N/A N/A N/A N/A N/A -------- ------- ------ -------- -------- Other Total 2,541 98.0% (1) NM (1) 356.6 11.6 ======== ======= ====== ======== ======== Net Genera- Heat Q3 YTD Total Margin Q3 YTD ting Rate Capture Factor Generation (GWh) Capacity (MMBtu/ ------------------ ----------------- Unit Name (MW) MWh) 2010 2009 2010 2009 -------- -------- ------ ------ -------- -------- Choctaw 800 7.0 NM (1) NM (1) 394.0 72.4 Indian River (2)(3) 587 10.5 NM (1) NM (1) - - Osceola (2) 470 11.0 NM (1) NM (1) - 1.5 Sabine (4) 54 N/A N/A N/A N/A N/A Vandolah (5) 630 N/A N/A N/A N/A N/A -------- ------- ------ -------- -------- Other Total 2,541 99.0% (1) NM (1) 394.0 73.9 ======== ======= ====== ======== ======== (1) NM is not meaningful. (2) Excludes generation during periods the unit operated under power purchase agreements. (3) This plant was mothballed in January 2010, other than during the third quarter of 2010 where one unit serviced a power purchase agreement. (4) We own 50% interest in this plant located in Texas (non-ERCOT) having 108 MW of net generating capacity. An unaffiliated party owns the other 50%. The table includes our net share of capacity of this plant. (5) We are party to a tolling agreement entitling us to 100% of the capacity of this Florida plant having 630 MW of net generating capacity. This tolling agreement expires in 2012 and is treated as an operating lease for accounting purposes. Reference is made to RRI Energy, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2009 RRI Energy, Inc. and Subsidiaries Capital Expenditures (Unaudited) Three Months Ended Nine Months Ended September 30, September 30, ------------------- ------------------- 2010 2009 2010 2009 ------- ------- ------- ------- (in millions) (in millions) Maintenance capital expenditures $ 4 $ 10 $ 24 $ 45 ------- ------- ------- ------- Environmental capital expenditures 10 25 32 91 Capitalized interest - 8 (1) 8 (2) 22 (1) ------- ------- ------- ------- Total environmental capital expenditures and capitalized interest 10 33 40 113 ------- ------- ------- ------- Total capital expenditures $ 14 $ 43 $ 64 $ 158 ======= ======= ======= ======= (1) Relates primarily to environmental capital expenditures for SO2 emission reductions at our Cheswick and Keystone plants, which are included in our East Coal segment. (2) Relates primarily to environmental capital expenditures for SO2 emission reductions at our Cheswick plant, which is included in our East Coal segment. Reference is made to RRI Energy, Inc.'s Annual Report on Form 10-K for the year ended December 31, 2009 RRI Energy, Inc. and Subsidiaries GAAP Debt, Gross Debt and Net Debt (Unaudited) September 30, December 31, 2010 2009 Change ------------- ------------- -------- (in millions) Senior secured revolver $ - $ - $ - Senior secured notes (1) 279 279 - Senior unsecured notes 1,300 1,300 - Orion Power 12% notes (2) - 405 (405) PEDFA fixed-rate bonds for Seward plant (1) 371 371 - ------------- ------------- -------- GAAP Debt $ 1,950 $ 2,355 $ (405) Orion Power 12% notes purchase accounting adjustment - (5) 5 REMA operating leases (off-balance sheet) 411 423 (12) ------------- ------------- -------- Gross Debt $ 2,361 $ 2,773 $ (412) Cash and cash equivalents (781) (943) 162 Restricted cash (7) (24) 17 Net margin deposits and cash collateral (137) (3) (260) (4) 123 ------------- ------------- -------- Net Debt $ 1,436 $ 1,546 $ (110) ============= ============= ======== (1) Expected to be refinanced in connection with the proposed merger with Mirant. (2) Orion Power 12% notes include purchase accounting adjustment of $5 million as of December 31, 2009. This debt was paid off in May 2010. (3) Includes $15 million related to discontinued operations and $31 million related to cash collateral. (4) Includes $45 million related to discontinued operations and $20 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, 2009
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