Exhibit 99.1

		EXCO Resources, Inc.
		12377 Merit Drive, Suite 1700, LB 82, Dallas, Texas 75251
		(214) 368-2084            FAX (972) 367-3559

EXCO RESOURCES, INC. REPORTS FOURTH QUARTER AND

FULL YEAR 2010 RESULTS

DALLAS, TEXAS, February 23, 2011 …EXCO Resources, Inc. (NYSE: XCO) today announced fourth quarter and full year results for 2010.

Our fourth quarter and full year 2010 operating and financial results were driven by the continued success in developing our assets and managing our balance sheet. We have grown our reserves, acreage and production through both drilling and acquisitions. As a result of our Appalachia joint venture with BG Group in June 2010, we have positioned ourselves to accelerate our development and appraisal programs in Appalachia during 2011. While our capital expenditures are increasing, our expected cash flows together with available borrowing capacity under our credit agreement will provide funding for our programs. On January 24, 2011, we issued a press release containing our fourth quarter and full year 2010 operations update. Our significant financial results follow:

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Douglas H. Miller, EXCO’s Chief Executive Officer commented “2010 was another significant year of achievement for EXCO. We increased our daily production from approximately 212 Mmcfe per day at the beginning of 2010 to approximately 385 Mmcfe per day at year end, effectively replacing all of the production we sold in 2009. We continued our success in the Haynesville shale play, entered into a joint venture with BG Group in Appalachia, and began ramping up our Appalachia activity. We also increased our Proved Reserves during 2010 by over 50%. Significant growth is expected to continue during 2011 with a projected daily exit rate of more than 600 Mmcfe per day. Our substantial inventory of undrilled locations in all of our operating areas will be very important to our operations in the future. ”

Net income

Our reported net income shown below, a GAAP measure, includes certain items not typically included by securities analysts in their published estimates of financial results. The following table provides a reconciliation of our net income to non-GAAP measures of adjusted net income:

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Cash flow and financing transactions

Our cash flow from operations before working capital changes was $106 million for the fourth quarter and $434 million for the full year. During 2010, we utilized our cash flow, credit agreement and proceeds from the Appalachia joint venture with BG Group to fund drilling and development programs. In addition, we issued $750 million of senior notes in September 2010 and used the proceeds to redeem our $445 million of outstanding senior notes and increase our liquidity.

Proved Reserves

Our estimated proved reserves grew by 56%, from 959 Bcfe at December 31, 2009 to approximately 1.5 Tcfe at December 31, 2010, calculated pursuant to SEC pricing rules, which are based on the simple average of the first of the month reference natural gas and oil prices for the prior twelve month period, adjusted for energy content, quality and basis differentials. For 2010, the reference price was $4.38 per Mmbtu for natural gas and $79.43 per Bbl for oil which resulted in an adjusted price of $4.37 per Mmbtu for natural gas and $75.83 per Bbl for oil. Our PV-10, a non-GAAP measure, and standardized measure using the SEC pricing adjusted for differentials were $1.4 billion and $1.2 billion, respectively. The following table presents the details of changes in our proved reserves:

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Using the five year futures strip price at December 31, 2010 averaging $5.23 per Mmbtu for natural gas and $93.09 per Bbl of oil, as adjusted for energy content, quality and basis differentials, our estimated proved reserves would have been 1.6 Tcfe. Pro forma for the Chief acquisition that closed on January 11, 2011 and a pending Appalachian acquisition that is projected to close in March 2011, we estimate our total net resource potential to be approximately 13.0 Tcfe.

We replaced 576% of our production with a finding and development cost of $0.54 per Mcfe through the drill bit. Adjusting for the benefit of $351 million of BG carry, our “all-in” finding and development cost would have been $1.03 per Mcfe. Our development drilling success has given us the ability to book proved reserves on 80-acre spacing in our core DeSoto Parish Haynesville shale development area.

Development and Exploitation Activity

We drilled and completed 51 gross (31.0 net) operated wells in the fourth quarter 2010 and 154 gross (93.7 net) operated wells during full year 2010. Including the wells we own interests in that were operated by others, we drilled and completed 68 gross (32.1 net) wells in the fourth quarter 2010 and we drilled and completed 205 gross (97.2 net) wells during full year 2010. During the fourth quarter 2010, we had a 100% drilling success rate, while for full year 2010, we realized a 99% drilling success rate as we completed 205 of the 207 wells that we drilled.

Our capital expenditures, including our development, leasing, and other corporate activity, totaled $132 million and $503 million for fourth quarter 2010 and full year 2010, respectively. In addition, we contributed $144 million to our midstream entities development program.

Our capital budget for 2011 totals $976 million. Approximately $769 million of this budget will fund the drilling and completion of 369 gross wells. Approximately 89% of our 2011 capital budget is allocated to our Haynesville/Bossier and Marcellus shale programs. Highlights of our 2011 capital budget program follow.

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East Texas/North Louisiana

Our budgeted capital expenditures in this area total $782 million, of which $683 million are allocated for drilling and completion of 233 gross (65.2 net) horizontal shale wells, all of which are within our EXCO/BG Group joint venture area. We will operate 163 of the 233 gross wells. We plan to run 22 operated drilling rigs throughout full year 2011 to implement this drilling and completion program which will be focused in our DeSoto Parish area of northwest Louisiana and in our Shelby Trough area of East Texas. In the DeSoto Parish area, we will run 16 operated drilling rigs as we implement a full development program, drilling on 80-acre spacing from pads within our operated units. In the Shelby Trough area, we will drill using six operated rigs as we delineate and hold our acreage acquired during 2010. We plan to move to full development of the Shelby Trough area acreage during 2012.

Appalachia

We plan to spend $83 million of capital within our Appalachian region during 2011. Of this total, approximately $38 million will be allocated to drilling and completion of 64 gross (23.9 net) operated wells. Of the 64 wells, 52 will be development wells (within our recently acquired acreage in northeast Pennsylvania and our acreage in west central Pennsylvania) and 12 will be appraisal wells (primarily in central Pennsylvania). This drilling will be within the EXCO/BG Group Appalachia joint venture area, so our net drilling dollars are reduced by the effect of the carry we receive from BG Group per the terms of our joint venture. As of early 2011, approximately $126 million of carry dollars remain available to us from BG Group. We will drill with two operated drilling rigs early in 2011, and plan to exit 2011 with four to five operated drilling rigs in Appalachia.

Permian

Our Permian Canyon Sand field development continues. We will use two operated drilling rigs and spend $48 million of the total $53 million capital budget allocated to the Permian area to drill and complete 72 gross (69.8 net) wells during 2011. As this development program contains a significant amount of oil production, our rates of return for this drilling and completion program typically exceed 60%.

Midstream

Through our jointly held midstream company, TGGT, we are constructing a major expansion in our Shelby Trough area of East Texas. We are also continuing to develop our gathering and treating capacity in the DeSoto Parish area of northwest Louisiana. TGGT recently closed a $500 million credit agreement which, combined with internally generated cash flow, will fund its capital program. At the closing of the credit agreement, TGGT funded a distribution to its owners, of which $125 million was distributed to us.

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Financial Data

Our consolidated balance sheets as of December 31, 2010 and 2009 and consolidated statements of operations for the three months and years ended December 31, 2010 and 2009, and consolidated statements of cash flows for the years ended December 31, 2010 and 2009, are included on the following pages. We have also included reconciliations of non-GAAP financial measures referred to in this press release which have not been previously reconciled.

EXCO will host a conference call on Thursday, February 24, 2011 at 9:00 a.m. (Dallas time) to discuss the contents of this release and respond to questions. Please call (800) 309-5788 if you wish to participate, and ask for the EXCO conference call ID# 43614912. The conference call will also be webcast on EXCO’s website at www.excoresources.com under the Investor Relations tab. Presentation materials related to this release will be posted on EXCO’s website on Wednesday, February 23, 2011, after market close.

A digital recording will be available starting two hours after the completion of the conference call until 11:59 p.m., March 10, 2011. Please call (800) 642-1687 and enter conference ID# 43614912 to hear the recording. A digital recording of the conference call will also be available on EXCO’s website.

Additional information about EXCO Resources, Inc. may be obtained by contacting EXCO’s Chairman, Douglas H. Miller, or its President, Stephen F. Smith, at EXCO’s headquarters, 12377 Merit Drive, Suite 1700, Dallas, TX 75251, telephone number (214) 368-2084, or by visiting EXCO’s website at www.excoresources.com. EXCO’s SEC filings and press releases can be found under the Investor Relations tab.

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We believe that it is important to communicate our expectations of future performance to our investors. However, events may occur in the future that we are unable to accurately predict, or over which we have no control. You are cautioned not to place undue reliance on a forward-looking statement. When considering our forward-looking statements, keep in mind the risk factors and other cautionary statements in this presentation, and the risk factors included in the Annual Report on Form 10-K, as amended, for the year ended December 31, 2009 and after February 24, 2011, our Annual Report on Form 10-K for the year ended December 31, 2010, and our other periodic filings with the SEC.

Our revenues, operating results, financial condition and ability to borrow funds or obtain additional capital depend substantially on prevailing prices for oil and natural gas. Declines in oil or natural gas prices may materially adversely affect our financial condition, liquidity, ability to obtain financing and operating results. Lower oil or natural gas prices also may reduce the amount of oil or natural gas that we can produce economically. A decline in oil and/or natural gas prices could have a material adverse effect on the estimated value and estimated quantities of our oil and natural gas reserves, our ability to fund our operations and our financial condition, cash flow, results of operations and access to capital. Historically, oil and natural gas prices and markets have been volatile, with prices fluctuating widely, and they are likely to continue to be volatile.

The SEC permits oil and natural gas companies in filings made with the SEC to disclose proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions. Beginning with reserves reported for the year ended December 31, 2009, the SEC permits optional disclosure of “probable” and “possible” reserves in its filings with the SEC. EXCO may use

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broader terms to describe additional reserve opportunities such as “potential,” “unproved,” or “unbooked potential,” to describe volumes of reserves potentially recoverable through additional drilling or recovery techniques that the SEC’s guidelines strictly prohibit us from including in filings with the SEC. These estimates are by their nature more speculative than estimates of proved, probable or possible reserves and accordingly are subject to substantially greater risk of being actually realized by the company. While we believe our calculations of unproved drillsites and estimation of unproved reserves have been appropriately risked and are reasonable, such calculations and estimates have not been reviewed by third party engineers or appraisers. Investors are urged to consider closely the disclosure in our Annual Report on Form 10-K, as amended, for the year ended December 31, 2009 and after February 24, 2011, our Annual Report on Form 10-K for the year ended December 31, 2010, which are available on our website at www.excoresources.com under the Investor Relations tab.

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EXCO Resources, Inc.

Consolidated balance sheet

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EXCO Resources, Inc.

Consolidated balance sheet

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EXCO Resources, Inc.

Consolidated statement of operations

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EXCO Resources, Inc.

Consolidated statement of cash flows

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EXCO Resources, Inc.

Consolidated EBITDA

And adjusted EBITDA reconciliations and statement of cash flow data

(Unaudited)

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EXCO Resources, Inc.

Summary of operating data