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 THIRD QUARTER 2011 RESULTS

DALLAS, TEXAS, November 1, 2011…EXCO Resources, Inc. (NYSE: XCO) (“EXCO”) today announced third quarter results for 2011.

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Douglas H. Miller, EXCO’s Chief Executive Officer commented “Our results for the third quarter 2011 reflect our focus on well performance, capital and operating costs. Production grew 69% from the prior year despite curtailments, and we remain on track to exit 2011 at nearly 600 Mmcfe per day of net production. Our direct operating costs during the quarter decreased by 44% from the prior year to $0.42 per Mcfe, reflecting the high quality of our asset base. In DeSoto Parish, we continue to refine our production techniques and have successfully reduced our drilling and completion costs during the year. In our Shelby area, we are focused on further delineation in both the Haynesville and Bossier shales where recent IP’s were in excess of 27 Mmcf per day. Our drilling days have shown a marked improvement during the year resulting in reduced drilling costs. Results in our Marcellus acreage during the quarter have also seen improvements. During the third quarter, we turned 11 Marcellus wells to sales with an average IP rate of 5.8 Mmcf per day. As we begin our development program in the Marcellus, we are realizing reductions in our average well cost and expect further reductions as a result of drilling and completion efficiencies and building our water infrastructure. We are currently in the process of finalizing our 2012 capital budget. Although the low cost, high volume nature of our operations results in a satisfactory rate of return in the current natural gas environment, we are evaluating the appropriate level of our 2012 development activities.”

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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:

Cash flow and financing transactions

Our cash flow from operations before working capital changes, a non-GAAP measure, was $151 million for the third quarter 2011. We use our cash flow and credit agreement to fund our drilling and development programs.

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Current liquidity

As of October 27, 2011, $1.0 billion was drawn under our credit agreement and we had $230.9 million of cash, which includes $152.5 million of restricted cash. Our available borrowing under our credit agreement as of October 27, 2011, including cash and restricted cash on hand was $688.9 million.

Operations activity and outlook

During the third quarter 2011, we spent $233 million on development and exploitation activities, drilling and completing 79 gross (41.2 net) operated wells, compared with 71 gross (40.6 net) operated wells during the second quarter 2011. In addition, we participated in 12 gross (0.3 net) wells operated by others (OBO) during the third quarter 2011. We had an overall drilling success rate of 100% for the third quarter 2011. Our total capital expenditures, including leasing and net of acreage reimbursements from BG Group, were approximately $263 million in the third quarter 2011. We are continuing efforts to opportunistically acquire additional leasehold in our core shale areas.

Our projected capital spending for 2011 is presented in the following table.

During the third quarter 2011, we closed on $15.3 million of acquisitions, which were principally undeveloped Marcellus shale acreage in our Appalachian region.

Haynesville/Bossier Shale

Our horizontal Haynesville shale development program continues to yield outstanding results. As of October 16, 2011, our Haynesville/Bossier operated production was 1,243 Mmcf per day gross (395 Mmcf per day net) and with the addition of our OBO wells, we had 419 Mmcf per day of net production. We continue to focus our activities in two main development areas. Our development program in DeSoto Parish, Louisiana is focused on manufacturing on 80-acre spacing. Our program in San Augustine and Nacogdoches Counties, Texas is focused on delineation and testing of our acreage. We continue optimizing our operations with efforts to reduce costs and improve our estimated ultimate recoveries.

During 2011, we plan to drill 243 gross (70.7 net) wells in the Haynesville/Bossier shale play in East Texas/North Louisiana. Of these 243 wells, 173 gross wells are operated by EXCO. During the third quarter 2011, we drilled and completed 50 gross (19.7 net) operated horizontal Haynesville and Bossier wells and participated in 12 gross (0.3 net) OBO Haynesville horizontal wells. We utilized 22 operated rigs and spud 39 operated horizontal wells. In addition to our operated rig count, we typically have 3-6 OBO rigs drilling in the play. During the quarter, nine OBO wells were spud. We currently have 264 operated horizontal wells and 144 OBO horizontal wells flowing to sales.

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The average initial production rate (“IP”) during the quarter from all of our operated Haynesville horizontal wells in DeSoto Parish was 18.9 Mmcf per day on a managed drawdown/restricted choke program. Our manufacturing approach for simultaneous drilling followed by simultaneous completions by unit is being successfully implemented. We currently have 19 units fully drilled, completed and flowing to sales on 80-acre spacing and expect to have 25 units fully developed by year end. During the course of 2011, our average well costs in DeSoto Parish have decreased from $9.9 million in the first half of 2011 to $9.6 million in the third quarter of 2011. These cost improvements include more efficient pad and road utilization and construction processes, drill bit design changes and more efficient completion design and implementation processes.

We acquired our Shelby area assets in May 2010 with total gross production of 34 Mmcf per day gross from eight operated wells. Our Shelby area is currently producing 224 Mmcf per day gross from 49 operated wells. Results from our testing and delineation program in this area are encouraging. During the third quarter 2011, we completed three Haynesville wells in the deeper part of the play in Nacogdoches County, Texas with average IP rates of 28 Mmcf per day with average flowing pressures of 10,300 psi on 26/64ths chokes. These wells are performing above our original expectations. The wells in this area are approximately 19,700 feet measured depth with an average completed lateral length of approximately 4,700 feet. We have made significant progress in 2011 in the drilling performance in the Nacogdoches County area of the play. Our initial wells in the first half of 2011 were averaging 63 days from spud to rig release and our most recent wells in the second half of 2011 are averaging 55 days, a 13% reduction in time. We drilled and completed our second horizontal Middle Bossier test well in the Shelby area during the third quarter 2011 with an IP rate of 27 Mmcf per day from a 13 stage fracture stimulation treatment. The Middle Bossier performance is also above our original expectations. We currently have a total of seven operated rigs running in the Shelby area.

Marcellus Shale

Our current gross operated Marcellus shale production is approximately 100 Mmcf per day, which represents an increase of more than 50% since the end of the second quarter 2011. We have implemented a development program within our acreage in northeast Pennsylvania and an appraisal program primarily in central Pennsylvania. We plan to drill 49 gross (16.0 net) operated wells in the Marcellus shale play in our Appalachia region during 2011. Of the 49 wells, 42 gross (12.8 net) will be development wells and 7 gross (3.2 net) will be appraisal wells. We are currently drilling with four operated rigs, three of which are in our northeast Pennsylvania development area. Our net drilling dollars are reduced by the effect of the carry we receive from BG Group. Approximately $78.8 million of the carry remains available to us from BG Group as of September 30, 2011. We expect that the remaining carry amount will be used in the first half of 2012.

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We spud 12 new operated wells and drilled and completed 11 gross (4.0 net) operated wells during the third quarter 2011 in the Marcellus shale. In northeast Pennsylvania, we turned six wells on two pads to sales at the end of the quarter with an average IP rate of 6.4 Mmcf per day from an average lateral length of approximately 3,400 feet. In our central Pennsylvania area, we turned five wells to sales from two pads during the quarter with an average IP rate of 5.0 Mmcf per day from an average lateral length of approximately 4,100 feet. We are also focused on building our field infrastructure in support of our expected levels of activity. Along with efficiency gains derived from our drilling and completion program, these infrastructure investments are expected to be the primary drivers to reduce our average development well costs.

Permian

We drilled and completed 18 gross (17.5 net) wells in our Sugg Ranch area during the third quarter 2011 with 100% drilling success. We currently are running one operated rig and plan to drill 68 gross (65.4 net) wells in 2011. Our production at Sugg Ranch has increased by 8% in the third quarter of 2011 as compared to the third quarter of 2010, and economics for this drilling activity typically have rates-of-return in excess of 50%.

Midstream

Through our jointly held midstream company, TGGT, we continue pipeline expansion and treating facilities installation efforts in our Shelby Trough area of east Texas in order to meet the expected throughput volume increase. We are also continuing to provide timely well-hookups and increased treating capacity in the DeSoto Parish area of northwest Louisiana. Total throughput for TGGT averaged approximately 1.5 Bcf per day for the third quarter of 2011 compared with total average throughput of 1.4 Bcf per day in the second quarter 2011. Despite the volumetric reductions from the May 28, 2011 incident discussed below, our current throughput is approximately 1.6 Bcf per day.

In the second quarter 2011, an incident occurred at a TGGT amine treating facility in northwest Red River Parish, Louisiana resulting in an immediate shut-down of the facility. As a precautionary measure, TGGT also shut down another amine treating facility located in DeSoto Parish with similar specifications, which was restarted in October 2011. TGGT is also installing temporary treating units and expects to be capable of treating all projected northwest Louisiana throughput volumes early in the first quarter of 2012 once these temporary treating units are operational. Restart of all treating activity has been delayed from the initial estimated timeline. Delays have resulted from the damage assessment of infrastructure and facilities and the related planning and execution of appropriate engineering and operational upgrades

The estimated third quarter 2011 impact to TGGT resulting from this incident was an $8.7 million net decrease to their operating income, which was primarily due to an estimated $7.0 million reduction in revenue. TGGT received an initial insurance reimbursement associated with the incident of approximately $6.2 million during the third quarter 2011. TGGT expects to have the damaged facility re-commissioned early in 2012.

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Financial Data

Our consolidated balance sheets as of September 30, 2011 and December 31, 2010 and consolidated statements of operations for the three and nine months ended September 30, 2011 and 2010, and consolidated statements of cash flows for the nine months ended September 30, 2011 and 2010, are included on the following pages. We have also included reconciliations of non-GAAP financial measures referred to in this release which have not been previously reconciled.

EXCO will host a conference call on Wednesday, November 2, 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# 16833223. 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 Tuesday, November 1, 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., November 16, 2011. Please call (800) 585-8367 or (855) 859-2056 and enter conference ID# 16833223 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, 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.

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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 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, 2010, which is 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