ATN Atlas Energy Resources Llc

Atlas Energy Resources, LLC (NYSE: ATN) (“Atlas Energy” or “the Company”) today reported financial results for the second quarter 2009 and announced a sharp increase in estimated potential Marcellus Shale reserves from its acreage position in southwestern Pennsylvania.

Highlights from Atlas Energy’s operational and financial results include the following:

• The Company generated record average natural gas and oil production of approximately 101.7 million cubic feet of natural gas equivalents (“Mmcfe”) per day for the second quarter 2009, including record average net daily production in Appalachia of 43.6 Mmcfe/d, an increase of approximately 25% over the prior year second quarter.
• Atlas Energy has increased its estimate of gross undeveloped potential reserves in the Marcellus Shale in southwestern Pennsylvania to 9.125 trillion cubic feet of natural gas equivalents (“Tcfe”) from a previous estimated range of 4 to 6 Tcfe. The Company has identified approximately 3,900 drillable Marcellus Shale locations. Over the past several months, Atlas Energy embarked on a process to evaluate in detail its entire Marcellus Shale leasehold in southwestern Pennsylvania, which as of June 30, 2009 totaled approximately 266,000 acres. The Company divided these acres into 20 discrete units and assigned a team of geologists and senior land personnel to each unit. Each project team was charged with gridding out an optimal Marcellus Shale horizontal development plan based on lease configurations, lease restrictions and sub-surface constraints. To develop its estimate of potential gross reserves, Atlas Energy used a 4 billion cubic feet of natural gas equivalents (“Bcfe”) type curve for Marcellus Shale horizontal wells and a 1.4 Bcfe type curve for Marcellus Shale vertical wells. Today’s announcement comes as a result of this extensive evaluation.

• The Company anticipates that it will exit 2009 with net daily production from its Appalachia segment of approximately 48 to 52 Mmcfe per day and believes it will exit 2010 at approximately 95 to 105 Mmcfe per day of net production. Net production from the Michigan segment is expected to remain relatively flat at approximately 58 Mmcfe per day through 2010. In addition, Atlas Energy plans to commence drilling up to four horizontal Marcellus Shale wells, in which it will have a 100% working interest, in the fourth quarter 2009 as well as 30 net horizontal Marcellus Shale wells for its own account in 2010. As a result, the Company expects total net production in 2010 to be between 45 and 50 Bcfe, representing a company-wide growth rate at a mid-point of 28%.

• Atlas Energy completed one horizontal Marcellus Shale well in the second quarter. The Company’s fourth horizontal completion, which was drilled in eastern Greene County, Pennsylvania, had an initial 24-hour peak rate of production into a pipeline of 3.2 Mmcfe per day. The Company has drilled five additional horizontal Marcellus Shale wells that are waiting on upgrades to two natural gas processing plants owned by Laurel Mountain Midstream, LLC (“Laurel Mountain”) before they are frac’d and turned into line. These plants are anticipated to be back online towards the end of September.
• During the second quarter 2009, the Company raised approximately $123 million in investor funds (above its original target of $100 million in investor funds) for the Public #18-2009 (B) drilling program. The Company anticipates that it will shortly commence the offering of an additional $275 million in investor funds. (1)
• Adjusted earnings before interest, income taxes, depreciation and amortization (“adjusted EBITDA”), a non-GAAP measure, was $89.4 million for the second quarter 2009, as compared with $80.1 million for the second quarter 2008, an increase of $9.3 million, or approximately 12%. The increase over the prior year comparable quarter was primarily related to increased production in Appalachia and the cash proceeds of $28.5 million from the early termination of derivative instruments, partially offset by lower overall commodity prices. A reconciliation from net income to adjusted EBITDA is provided in the financial tables of this release.
• Net income for the second quarter 2009 was $12.2 million, a decrease of $26.2 million compared with $38.4 million for the second quarter 2008.

Edward E. Cohen, Chairman and Chief Executive Officer, stated, "This has been a great quarter - we have enhanced our balance sheet, we have expanded our investor programs, we have confirmed a substantial increase in Marcellus Shale reserves, we have operated on a net cash flow positive basis, and debt amounts will be further reduced upon consummation of the merger with Atlas America, Inc. In short, we are poised to accelerate our success, especially in the Marcellus Shale play."

Recent Events

Senior Notes Offering and Reduction in Bank Loan Outstanding

In July 2009, the Company issued $200 million aggregate principal amount of 12.125% senior unsecured notes due 2017. Net proceeds from the offering were used to reduce outstanding borrowings under its revolving credit facility.

New Natural Gas Gathering Agreement and Sale of Natural Gas Gathering and Processing Assets

On June 1, 2009, the Company entered into new natural gas gathering agreements with Laurel Mountain, a newly-formed joint venture in the northern Appalachian Basin between the Company’s affiliate, Atlas Pipeline Partners, L.P. (NYSE: APL) (“Atlas Pipeline”), and Williams. These new agreements superseded the previous master gas gathering agreement and omnibus agreement between the Company and Atlas Pipeline. As part of the transaction, the Company completed the sale of two natural gas processing plants and associated pipelines located in southwestern Pennsylvania for cash of $10.0 million to Laurel Mountain. The Company used the net proceeds from the sale to reduce borrowings under its revolving credit facility. Williams is the operator of Laurel Mountain’s assets.

Merger with Atlas America

On April 27, 2009, Atlas Energy and Atlas America, Inc. (NASDAQ: ATLS) (“Atlas America”), which owns approximately 48% of the Class B common units and Class A units including the management incentive interests in Atlas Energy, jointly announced that they executed a definitive merger agreement, pursuant to which a newly formed subsidiary of Atlas America will merge with and into Atlas Energy, with Atlas Energy surviving as a wholly owned subsidiary of Atlas America. In the merger, each Class B common unit of Atlas Energy not currently held by Atlas America will be converted into 1.16 shares of Atlas America common stock, and Atlas America will be renamed “Atlas Energy, Inc.” The Atlas America Board of Directors has approved the merger agreement and has resolved to recommend that the Atlas America stockholders vote in favor of the transactions contemplated by the merger agreement. The Atlas Energy board of directors and a special committee of Atlas Energy directors comprised entirely of independent directors have also approved the merger agreement and have resolved to recommend that the Atlas Energy unitholders vote in favor of the merger.

The transaction is expected to create a stronger balance sheet and capital structure at the combined entity, along with a lower cost of capital. The net debt outstanding at Atlas Energy will be reduced by cash on hand at Atlas America. Furthermore, liquidity should be greatly improved from the larger, newly combined company. The retention and investment of future cash flows will also reduce the need to raise capital from outside sources under unfavorable market conditions.

The transaction is subject to approval by holders of a majority of the outstanding Atlas America common stock and a majority of the outstanding Atlas Energy Class B units, and other customary closing conditions.

(1) Atlas Energy’s subsidiary serves as managing general partner of the partnership. A written prospectus meeting the requirements of Section 10 of the Securities Act may be obtained when available from Anthem Securities, Inc. (a subsidiary of Atlas Energy), 1550 Coraopolis Heights Rd. – 2nd Floor, Moon Township, PA 15108.

Appalachia Segment Results

• The Company drilled 19 vertical Marcellus Shale wells and 2 horizontal Marcellus Shale wells in the second quarter 2009. The Company connected 105 wells in Appalachia to its affiliated gathering system during the second quarter 2009. During 2009, the Company plans to drill and complete a total of approximately 100 vertical Marcellus Shale wells, all of which will be funded through its investment programs.
• Partnership management margin was $13.2 million for the second quarter 2009, compared to $23.2 million for the prior year second quarter. Lower drilling revenues reflected management's decision to match drilling expenditures to capital inflows from the funding of its spring investment program, Public #18-2009 (B). This decision had the effect of deferring certain partnership management revenues to the third quarter 2009.
• As of June 30, 2009, the Company held approximately 890,000 net acres in the Appalachian Basin, of which approximately 616,000 were undeveloped. As of June 30, 2009, the Company controlled approximately 532,000 Marcellus Shale acres in Pennsylvania, New York and West Virginia, of which approximately 266,000 of these acres are located in the Company’s current focus area of southwestern Pennsylvania.
• As of June 30, 2009, the Company had an interest in approximately 9,260 gross producing wells in Appalachia, of which it operated approximately 85%.

Michigan/Indiana Segment Results

• Natural gas and oil production from the Michigan's segment averaged 58.1 Mmcfe per day during the second quarter 2009.
• At June 30, 2009, the Company had approximately 272,200 net acres in the Antrim Shale in Michigan, of which 28,100 were net undeveloped acres. The Company has identified approximately 715 infill drilling locations in the Antrim Shale, most of which are proved undeveloped locations.
• At June 30, 2009, the Company had access to approximately 244,000 gross acres in the New Albany Shale in Indiana.
• In the second quarter 2009, the Company drilled an additional 10 wells into the New Albany Shale in southwestern Indiana.

Corporate and Other

• General and administrative expenses remained consistent with the prior year comparable quarter at $12.3 million.
• Depreciation, depletion and amortization expense was $27.3 million in the second quarter 2009, compared to $22.9 million in the prior year comparable quarter. The increase is due primarily to the increase in production in the Company’s Appalachia segment, notably from production from the Marcellus Shale.
• Interest expense was $15.1 million in the second quarter 2009, compared to $14.6 million in the prior year comparable quarter. The increase in interest expense compared with the prior year comparable quarter is due principally to interest expense associated with the issuance of additional senior unsecured notes by the Company in May 2008.
• The Company also has LIBOR interest rate swaps on $150.0 million of outstanding debt through January 2011.

Hedging Summary

The Company entered into additional hedging contracts during the second quarter 2009 for its natural gas production.

A summary of the Company’s current equity hedge positions as of August 10, 2009 is as follows:

Natural Gas

Fixed Price Swaps

    Average Production Period Fixed Price Volumes Ended December 31, (per mcf)(1)(2) (per mcf)(1) 2009(3) $ 8.37 15,082,745 2010 $ 7.91 22,876,782 2011 $ 7.19 15,181,497 2012 $ 7.24 13,926,950 2013 $ 7.25

9,884,650

Costless Collars

      Average Average Production Period Floor Price Ceiling Price Volumes Ended December 31, (per mcf)(1)(2) (per mcf)(1)(2) (per mcf)(1) 2009(3) $ 11.25 $ 15.68 85,572 2010 $ 8.03 $ 9.22 2,420,926 2011 $ 6.46 $ 7.66 7,045,685 2012 $ 6.64 $ 7.86 3,066,981 2013 $ 6.71 $ 8.04 4,152,862

Crude Oil

Fixed Price Swaps

    Average Production Period Fixed Price Volumes Ended December 31, (per bbl)(1) (bbls)(1) 2009(3) $ 99.32 21,691 2010 $ 97.30 36,977 2011 $ 69.77 32,194 2012 $ 71.55 26,139 2013 $ 72.26 5,900

Costless Collars

      Average Average Production Period Floor Price Ceiling Price Volumes Ended December 31, (per bbl)(1) (per bbl)(1) (bbls)(1) 2009(3) $ 85.00 $ 116.56 13,371 2010 $ 85.00 $ 112.72 23,442 2011 $ 60.00 $ 80.92 20,361 2012 $ 60.00 $ 86.50 16,777 2013 $ 60.00 $ 88.90 3,540

_______________________________________________________________

(1) “Mcf” represents thousand cubic feet; “bbl” represents barrel. (2) Includes an estimated positive basis differential and Btu (British thermal units) adjustment. (3) Reflects hedges covering the last six months of 2009.

Interested parties are invited to access the live webcast of Atlas Energy’s second quarter 2009 results on Tuesday, August 11, 2009 at 9:00 am ET by going to the Investor Relations section of Atlas Energy’s website at www.atlasenergyresources.com. An audio replay of the conference call will also be available beginning at 11:00 am ET on Tuesday, August 11, 2009. To access the replay, dial 1-888-286-8010 and enter conference code 11875571.

Atlas Energy Resources, LLC is one of the largest independent natural gas producers in the Appalachian and Michigan Basins. The Company is also the country’s largest sponsor and manager of tax-advantaged energy investment partnerships that finance the exploration and development of the Company’s acreage. For more information, visit Atlas Energy’s website at www.atlasenergyresources.com or contact investor relations at InvestorRelations@atlasamerica.com.

Atlas America, Inc. owns approximately 48% of the Class B common unit interests and all of the management incentive interests in Atlas Energy Resources, LLC. Atlas America, Inc. also owns 1.1 million common units in Atlas Pipeline Partners, L.P. (NYSE: APL) and a 64% interest in Atlas Pipeline Holdings, L.P. (NYSE: AHD). For more information, please visit our website at www.atlasamerica.com, or contact Investor Relations at InvestorRelations@atlasamerica.com.

Atlas Pipeline Partners, L.P. is active in the transmission, gathering and processing segments of the midstream natural gas industry. In the Mid-Continent region of Oklahoma, southern Kansas, northern and western Texas and the Texas panhandle, APL owns and operates eight active gas processing plants and a treating facility, as well as approximately 8,750 miles of active intrastate gas gathering pipeline. In Appalachia, APL is a 49% joint venture partner with Williams in Laurel Mountain Midstream, LLC, which manages the natural gas gathering system in that region, namely from the Marcellus Shale in southwestern Pennsylvania. For more information, visit the Partnership’s website at www.atlaspipelinepartners.com or contact investorrelations@atlaspipelinepartners.com.

Atlas Pipeline Holdings, L.P. is a limited partnership which owns and operates the general partner of Atlas Pipeline Partners, L.P., through which it owns a 2% general partner interest, all the incentive distribution rights and approximately 5.8 million common and 15,000 $1,000 par value 12% preferred limited partner units of Atlas Pipeline Partners, L.P.

Cautionary Note Regarding Forward-Looking Statements

This document contains forward-looking statements that involve a number of assumptions, risks and uncertainties that could cause actual results to differ materially from those contained in the forward-looking statements. Atlas Energy Resources, LLC (“Atlas Energy”) cautions readers that any forward-looking information is not a guarantee of future performance. Such forward-looking statements include, but are not limited to, statements or assumptions regarding whether the proposed merger between Atlas America, Inc. (“Atlas America”) and Atlas Energy will occur, statements about the benefits of such proposed merger, including future financial and operating results, the combined company’s plans, objectives, expectations and intentions and other statements that are not historical facts. Risks, assumptions and uncertainties that could cause actual results to materially differ from the forward-looking statements include, but are not limited to, those associated with general economic and business conditions; changes in commodity price; the possibility that the proposed merger might not occur; inability to obtain capital needed for operations; the level of indebtedness; changes in government environmental policies; tax consequences of business transactions; and other risks, assumptions and uncertainties detailed from time to time in either company’s reports filed with the U.S. Securities and Exchange Commission (the “SEC”), including each company’s report on Form 10-K for the year ended December 31, 2008. There can be no assurance that the transactions described in this document will be consummated. Forward-looking statements speak only as of the date hereof, and each company assumes no obligation to update such statements.

Additional Information About the Merger

In connection with the proposed merger between Atlas America and Atlas Energy, Atlas America filed with the SEC a Registration Statement on Form S-4 that includes a joint proxy statement of Atlas America and Atlas Energy, which will also constitute a prospectus of Atlas America. Each of Atlas America and Atlas Energy will mail the joint proxy statement/prospectus to their respective equity holders.

INVESTORS AND SECURITY HOLDERS ARE URGED TO READ THE JOINT PROXY STATEMENT/PROSPECTUS REGARDING THE PROPOSED MERGER IF AND WHEN IT BECOMES AVAILABLE BECAUSE IT WILL CONTAIN IMPORTANT INFORMATION.

Investors may obtain free copies of the joint proxy statement/prospectus when it becomes available, as well as other filings containing information about Atlas America and Atlas Energy, without charge, at the SEC’s website at www.sec.gov. In addition, the documents filed with the SEC by Atlas America may be obtained free of charge by directing such request to: Investor Relations, Atlas America, Inc., Westpointe Corporate Center One, 1550 Coraopolis Heights, Moon Township, PA 15108, (412) 262-2830. These documents may also be obtained for free from Atlas America’s Investor Relations website at www.atlasamerica.com. The documents filed with the SEC by Atlas Energy Resources may be obtained free of charge by directing such request to: Investor Relations, Atlas Energy Resources, LLC, Westpointe Corporate Center One, 1550 Coraopolis Heights, Moon Township, PA 15108, (412) 262-2830. These documents may also be obtained for free from Atlas Energy Resource’s Investor Relations website at www.atlasenergyresources.com.

Atlas America, Atlas Energy and their respective directors and executive officers and other members of management and employees may be deemed to participate in the solicitation of proxies in respect of the proposed transaction. Information regarding Atlas America’s directors and executive officers is available in Atlas America’s proxy statement for its 2008 annual meeting of shareholders, which was filed with the SEC on May 8, 2008, and information regarding Atlas Energy’s directors and executive officers is available in Atlas Energy’s proxy statement for its 2008 annual meeting of shareholders, which was filed with the SEC on May 8, 2008. Additional information regarding the interests of such potential participants will be included in the joint proxy statement/prospectus and the other relevant documents filed with the SEC if and when they become available.

This document shall 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. No offering of securities shall be made except by means of a prospectus meeting the requirements of Section 10 of the U.S. Securities Act of 1933, as amended.

ATLAS ENERGY RESOURCES, LLC

FINANCIAL SUMMARY

(unaudited; in thousands, except per unit data)

  Three Months Ended   Six Months Ended June 30, June 30, 2009   2008 2009   2008 REVENUES Well construction and completion $ 63,367 $ 122,341 $ 175,735 $ 226,479 Gas and oil production 69,979 78,957 141,922 155,183 Administration and oversight 2,642 5,137 6,494 10,154 Well services 4,806 5,266 9,899 10,064 Gathering   5,388   5,855   10,112   10,265 Total revenues   146,182   217,556   344,162   412,145   COSTS AND EXPENSES Well construction and completion 53,701 106,384 149,098 196,939 Gas and oil production 12,712 15,205 27,294 28,286 Well services 2,120 2,650 4,544 5,062 Gathering fee 6,485 5,610 10,978 9,733 General and administrative 12,268 12,286 26,817 24,078 Depreciation, depletion and amortization 27,275 22,948 55,303 44,758 Loss on asset sale   4,250   —   4,250   — Total costs and expenses   118,811   165,083   278,284   308,856   OPERATING INCOME   27,371   52,473   65,878   103,289   OTHER INCOME (EXPENSE): Interest expense (15,124) (14,563) (28,108) (27,868) Other, net   (1)   466   79   519 Total other expense, net   (15,125)   (14,097)   (28,029)   (27,349)   Net income 12,246 38,376 37,849 75,940 Income attributable to non-controlling interests   (15)   (17)   (30)   (38) Net income attributable to members’ interests $ 12,231 $ 38,359 $ 37,819 $ 75,902   Allocation of net income attributable to members’ interests: Class A member’s units $ 245 $ 2,465 $ (7,199) $ 4,419 Class B members’ units   11,986   35,894   45,018   71,483 Net income attributable to members’ interests $ 12,231 $ 38,359 $ 37,819 $ 75,902   Net income attributable to Class B members per unit: Basic $ 0.19 $ 0.57 $ 0.70 $ 1.15 Diluted $ 0.19 $ 0.57 $ 0.70 $ 1.14   Weighted Average Class B members’ units outstanding: Basic   63,381   62,144   63,381   61,427 Diluted   63,381   62,819   63,381   61,912   June 30,   December 31, 2009 2008

Balance Sheet Data (at period end):

Cash and cash equivalents

$ 4,849 $ 5,655

Property, plant and equipment, net

1,988,375 1,963,891

Total assets

2,304,813 2,291,317

Total debt

862,289 873,655

Total members’ equity

1,064,937 1,039,523

ATLAS ENERGY RESOURCES, LLC

FINANCIAL INFORMATION

(unaudited; in thousands)

  Three Months Ended   Six Months Ended June 30, June 30, 2009   2008 2009   2008 Capital Expenditure data: Maintenance capital expenditures $ 12,975 $ 12,975 $ 25,950 $ 25,950 Expansion capital expenditures   26,231   67,078   70,463   109,720 Total $ 39,206 $ 80,053 $ 96,413 $ 135,670   Three Months Ended   Six Months Ended June 30, June 30, 2009   2008 2009   2008 Reconciliation of net income to non-GAAP measures(1): Net income $ 12,246 $ 38,376 $ 37,849 $ 75,940 Income attributable to non-controlling interests (15) (17) (30) (38) Depreciation, depletion and amortization 27,275 22,948 55,303 44,758 Interest expense   15,124   14,563   28,108   27,868 EBITDA 54,630 75,870 121,230 148,528 Adjustment to reflect cash impact of derivatives(2) 29,019 2,920 30,623 7,948 Non-cash loss on sale of assets 4,250 — 4,250 — Non-cash compensation expense   1,453   1,339   2,981   2,659 Adjusted EBITDA 89,352 80,129 159,084 159,135 Interest expense (15,124) (14,563) (28,108) (27,868) Amortization of deferred financing costs

(included within interest expense)

1,002

742

1,667

1,512

Maintenance capital expenditures   (12,975)   (12,975)   (25,950)   (25,950) Distributable cash flow $ 62,255 $ 53,333 $ 106,693 $ 106,829 (1)   EBITDA, adjusted EBITDA and distributable cash flow are non-GAAP (generally accepted accounting principles) financial measures under the rules of the Securities and Exchange Commission. Management of the Company believes that EBITDA, adjusted EBITDA and distributable cash flow provide additional information for evaluating the Company’s ability to make distributions to its unitholders, among other things. These measures are widely used by commercial banks, investment bankers, rating agencies and investors in evaluating performance relative to peers and pre-set performance standards. EBITDA is also a financial measurement that, with certain negotiated adjustments, is utilized within the Company’s financial covenants under its credit facility. EBITDA, adjusted EBITDA and distributable cash flow are not measures of financial performance under GAAP and, accordingly, should not be considered as a substitute for net income, operating income, or cash flows from operating activities in accordance with GAAP. (2) Consists of (i) $28.5 million of cash proceeds received in May 2009 from the early settlement of natural gas and oil derivative positions and (ii) cash proceeds received from the settlement of ineffective derivative gains recognized in connection with the acquisition of the Company’s Michigan assets in June 2007 but not reflected in its consolidated statements of income for the three and six months ended June 30, 2009 and 2008.

ATLAS ENERGY RESOURCES, LLC

Operating Highlights

  Three Months Ended   Six Months Ended June 30, June 30, 2009   2008 2009   2008 Production revenues (in thousands): Gas $ 66,897 $ 74,217 $ 136,771 $ 147,092 Oil $ 3,082 $ 4,740 $ 5,151 $ 8,091   Production volume:(1) (2) Appalachia: Gas (Mcfd) 40,770 32,259 40,341 31,272 Oil (Bpd)   471   419   432   409 Total (Mcfed) Oil (Bbls/day)   43,596   34,773   42,933   33,726 Michigan: Gas (Mcfd) 58,058 59,767 58,154 59,411 Oil (Bpd)   11   15   9   11 Total (Mcfed) Oil (Bbls/day)   58,124   59,857   58,208   59,477 Total (Mcfed) 101,720 94,630 101,141 93,203   Average sales prices: (2) Gas (per Mcf) (3)(4) $ 7.49 $ 9.21 $ 7.79 $ 9.39 Oil (per Bbl)(5) $ 70.23 $ 120.00 $ 67.66 $ 106.02   Production costs(2)(6) Lease operating expenses as a percent of production revenues 11% 9% 10% 9% Lease operating expenses per Mcfe $ 0.78 $ 0.83 $ 0.84 $ 0.81 Production taxes per Mcfe   0.14   0.43   0.17   0.38 Total production costs per Mcfe $ 0.92 $ 1.26 $ 1.01 $ 1.19   Depletion per Mcfe(2) $ 2.82 $ 2.56 $ 2.90 $ 2.54 (1)   Production quantities consist of the sum of (i) the Company’s proportionate share of production from wells in which it has a direct interest, based on the Company’s proportionate net revenue interest in such wells, and (ii) the Company’s proportionate share of production from wells owned by the investment partnerships in which the Company has an interest, based on its equity interest in each such partnership and based on each partnership’s proportionate net revenue interest in these wells. (2) “Mcf” and “Mcfd” represent thousand cubic feet and thousand cubic feet per day; “Mcfe” and “Mcfed” represent thousand cubic feet equivalents and thousand cubic feet equivalents per day, and “Bbl” and “Bpd” represent barrels and barrels per day. Barrels are converted to Mcfe using the ratio of six Mcf’s to one barrel. (3) The Company’s average sales price for gas before the effects of financial hedging were $3.50 and $11.21 per Mcf for the three months ended June 30, 2009 and 2008, respectively, and $4.35 and $9.79 per Mcf for the six months ended June 30, 2009 and 2008, respectively. (4) Includes cash proceeds received from the settlement of derivative contracts of $0.5 million and $2.9 million for the three months ended June 30, 2009 and 2008, respectively, and $2.1 million and $7.9 million for the six months ended June 30, 2009 and 2008, respectively. The cash proceeds received from the settlement of derivative contracts were not included as gas revenue for the respective periods. (5) The Company’s average sales price for oil before the effects of financial hedging was $57.16 and $125.99 per barrel for the three months ended June 30, 2009 and 2008, respectively, and $46.26 and $109.12 per barrel for the six months ended June 30, 2009 and 2008, respectively. (6) Production costs include labor to operate the wells and related equipment, repairs and maintenance, materials and supplies, property taxes, severance taxes, insurance and production overhead.