Exco Resources (EXCO) 10-Q 27 Jul 15 2015 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	6 Months Ended
	Jun. 30, 2015	Jul. 24, 2015
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q2
Entity Registrant Name	EXCO RESOURCES INC
Entity Central Index Key	316,300
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		277,186,096

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 49,907	$ 46,305
Restricted cash	17,581	23,970
Accounts receivable, net:
Oil and natural gas	55,479	81,720
Joint interest	40,231	65,398
Other	8,164	8,945
Derivative financial instruments	55,111	97,278
Inventory and other	7,859	7,150
Total current assets	234,332	330,766
Equity investments	55,188	55,985
Oil and natural gas properties (full cost accounting method):
Unproved oil and natural gas properties and development costs not being amortized	248,196	276,025
Proved developed and undeveloped oil and natural gas properties	3,385,948	3,852,073
Accumulated depletion	(2,537,476)	(2,414,461)
Oil and natural gas properties, net	1,096,668	1,713,637
Other property and equipment, net	23,937	24,644
Deferred financing costs, net	26,385	30,636
Derivative financial instruments	3,772	2,138
Deferred income taxes	18,669	35,935
Goodwill	163,155	163,155
Total assets	1,622,106	2,356,896
Current liabilities:
Accounts payable and accrued liabilities	93,721	110,211
Revenues and royalties payable	135,180	152,651
Drilling advances	30,077	37,648
Accrued interest payable	26,046	26,265
Current portion of asset retirement obligations	1,769	1,769
Income taxes payable	0	0
Deferred income taxes	18,669	35,935
Derivative financial instruments	320	892
Total current liabilities	305,782	365,371
Long-term debt	1,537,243	1,446,535
Asset retirement obligations	36,502	34,986
Commitments and contingencies	0	0
Shareholders’ equity:
Common shares, $0.001 par value; 350,000,000 authorized shares; 274,328,625 shares issued and 273,750,583 shares outstanding at June 30, 2015; 274,351,756 shares issued and 273,773,714 shares outstanding at December 31, 2014	270	270
Additional paid-in capital	3,507,050	3,502,209
Accumulated deficit	(3,757,126)	(2,984,860)
Treasury shares, at cost; 578,042 shares at June 30, 2015 and December 31, 2014	(7,615)	(7,615)
Total shareholders' equity	(257,421)	510,004
Total liabilities and shareholders' equity	$ 1,622,106	$ 2,356,896

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Jun. 30, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Common stock, par value	$ 0.001	$ 0.001
Common stock, authorized shares	350,000,000	350,000,000
Common stock, shares issued	274,328,625	274,351,756
Common stock, shares outstanding	273,750,583	273,773,714
Treasury stock, shares	578,042	578,042

Consolidated Statements Of Oper

Consolidated Statements Of Operations - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Revenues:
Oil	$ 31,545	$ 56,055	$ 52,428	$ 108,385
Natural gas	62,197	126,911	127,634	273,053
Total revenues	93,742	182,966	180,062	381,438
Costs and expenses:
Oil and natural gas operating costs	14,135	15,827	29,076	34,614
Production and ad valorem taxes	5,603	7,364	10,464	14,973
Gathering and transportation	24,785	26,038	50,500	50,651
Depletion, depreciation and amortization	61,658	67,253	124,147	136,528
Impairment of oil and natural gas properties	394,327	0	670,654	0
Accretion of discount on asset retirement obligations	568	695	1,124	1,376
General and administrative	12,597	19,504	27,834	36,842
Other operating items	1,534	2,973	1,346	5,719
Total costs and expenses	515,207	139,654	915,145	280,703
Operating income (loss)	(421,465)	43,312	(735,083)	100,735
Other income (expense):
Interest expense, net	(25,571)	(25,968)	(53,061)	(46,132)
Gain (loss) on derivative financial instruments	(6,631)	(14,718)	17,079	(57,740)
Other income	47	77	98	123
Equity income (loss)	(535)	(410)	(1,300)	701
Total other income (expense)	(32,690)	(41,019)	(37,184)	(103,048)
Income (loss) before income taxes	(454,155)	2,293	(772,267)	(2,313)
Income tax expense	0	0	0	0
Net income (loss)	$ (454,155)	$ 2,293	$ (772,267)	$ (2,313)
Basic:
Net income (loss) (in dollars per share)	$ (1.67)	$ 0.01	$ (2.84)	$ (0.01)
Weighted average common shares outstanding	271,549	270,492	271,536	265,631
Diluted:
Net income (loss) (in dollars per share)	$ (1.67)	$ 0.01	$ (2.84)	$ (0.01)
Weighted average common shares and common share equivalents outstanding	271,549	271,226	271,536	265,631

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Operating Activities:
Net loss	$ (772,267)	$ (2,313)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion, depreciation and amortization	124,147	136,528
Share-based compensation expense	3,119	3,252
Accretion of discount on asset retirement obligations	1,124	1,376
Impairment of oil and natural gas properties	670,654	0
(Income) loss from equity method investments	1,300	(701)
(Gain) loss on derivative financial instruments	(17,079)	57,740
Cash receipts (payments) of derivative financial instruments	57,039	(34,469)
Amortization of deferred financing costs and discount on debt issuance	6,975	7,697
Effect of changes in:
Restricted cash	(600)	0
Accounts receivable	50,758	30,796
Other current assets	790	(577)
Accounts payable and other current liabilities	(17,756)	68,793
Net cash provided by operating activities	108,204	268,122
Investing Activities:
Additions to oil and natural gas properties, gathering assets and equipment	(204,600)	(197,341)
Property acquisitions	(7,608)	(426)
Proceeds from disposition of property and equipment	7,397	76,266
Restricted cash	6,989	5,349
Net changes in advances to joint ventures	5,756	(10,540)
Equity method investments	(503)	1,749
Net cash provided by (used in) investing activities	(192,569)	(124,943)
Financing Activities:
Borrowings under credit agreements	90,000	0
Repayments under credit agreements	0	(882,424)
Proceeds received from issuance of 2022 Notes	0	500,000
Proceeds (payments) for issuance of common shares, net	(2)	271,772
Payments of common share dividends	(15)	(27,066)
Deferred financing costs and other	(2,016)	(10,066)
Net cash provided by (used in) financing activities	87,967	(147,784)
Net increase (decrease) in cash	3,602	(4,605)
Cash at beginning of period	46,305	50,483
Cash at end of period	49,907	45,878
Supplemental Cash Flow Information:
Cash interest payments	52,069	39,576
Income tax payments	0	0
Supplemental non-cash investing and financing activities:
Capitalized share-based compensation	1,936	2,955
Capitalized interest	7,027	10,255
Issuance of common stock for director services	$ 100	$ 129

Consolidated Statements Of Chan

Consolidated Statements Of Changes In Shareholders' Equity - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock	Rights [Member]	Treasury Stock	Additional paid-in capital	Accumulated deficit
Beginning Balance (in shares) at Dec. 31, 2013		218,783		(539)
Beginning Balance, Subscription Rights (in shares) at Dec. 31, 2013			54,575
Beginning Balance at Dec. 31, 2013	$ 147,905	$ 215	$ 55	$ (7,479)	$ 3,219,748	$ (3,064,634)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of common stock	271,901	$ 55	$ (55)		271,901
Issuance of common stock (in shares)		54,579	(54,575)
Share-based compensation	6,200				6,200
Restricted stock issued, net of cancellations (in shares)		(84)
Restricted stock issued, net of cancellations	0	$ 0
Common stock dividends	(27,111)					(27,111)
Net income (loss)	(2,313)					(2,313)
Ending Balance at Jun. 30, 2014	396,582	$ 270	$ 0	$ (7,479)	3,497,849	(3,094,058)
Ending Balance, Subscription Rights (in shares) at Jun. 30, 2014			0
Ending Balance (in shares) at Jun. 30, 2014		273,278		(539)
Beginning Balance (in shares) at Dec. 31, 2014		274,352		(578)
Beginning Balance, Subscription Rights (in shares) at Dec. 31, 2014			0
Beginning Balance at Dec. 31, 2014	510,004	$ 270	$ 0	$ (7,615)	3,502,209	(2,984,860)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of common stock	98	$ 0	$ 0		98
Issuance of common stock (in shares)		0	0
Share-based compensation	4,743				4,743
Restricted stock issued, net of cancellations (in shares)		(23)
Restricted stock issued, net of cancellations	0	$ 0
Common stock dividends	1					1
Net income (loss)	(772,267)					(772,267)
Ending Balance at Jun. 30, 2015	$ (257,421)	$ 270	$ 0	$ (7,615)	$ 3,507,050	$ (3,757,126)
Ending Balance, Subscription Rights (in shares) at Jun. 30, 2015			0
Ending Balance (in shares) at Jun. 30, 2015		274,329		(578)

Organization And Basis Of Prese

Organization And Basis Of Presentation	6 Months Ended
	Jun. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization and basis of presentation	Organization and basis of presentation Unless the context requires otherwise, references in this Quarterly Report on Form 10-Q to “EXCO,” “EXCO Resources,” “Company,” “we,” “us,” and “our” are to EXCO Resources, Inc. and its consolidated subsidiaries. We are an independent oil and natural gas company engaged in the exploration, exploitation, acquisition, development and production of onshore U.S. oil and natural gas properties with a focus on shale resource plays. Our principal operations are conducted in certain key U.S. oil and natural gas areas including Texas, Louisiana and the Appalachia region. The following is a brief discussion of our producing regions. • East Texas and North Louisiana The East Texas and North Louisiana regions are primarily comprised of our Haynesville and Bossier shale assets. We have a joint venture with BG Group, plc ("BG Group") covering an undivided 50% interest in certain Haynesville/Bossier shale assets in East Texas and North Louisiana. The East Texas and North Louisiana regions also include assets outside of the joint venture in the Haynesville and Bossier shales. We serve as the operator for most of our properties in both the East Texas and North Louisiana regions. • South Texas The South Texas region is primarily comprised of our Eagle Ford shale assets. We have a joint venture with affiliates of Kohlberg Kravis Roberts & Co. L.P. ("KKR") to develop certain assets in the Eagle Ford shale. The South Texas region also includes assets outside of the joint venture in the Eagle Ford shale, Buda and other formations. We serve as the operator for most of our properties in the South Texas region. • Appalachia The Appalachia region is primarily comprised of Marcellus shale assets as well as shallow conventional assets in other formations. We have a joint venture with BG Group covering our shallow conventional assets and Marcellus shale assets in the Appalachia region ("Appalachia JV"). EXCO and BG Group each own an undivided 50% interest in the Appalachia JV and a 49.75% working interest in the Appalachia JV's properties. The remaining 0.5% working interest is held by a jointly owned operating entity ("OPCO") that operates the Appalachia JV's properties. We own a 50% interest in OPCO. The accompanying Condensed Consolidated Balance Sheets as of June 30, 2015 and December 31, 2014 , Condensed Consolidated Statements of Operations for the three and six months ended June 30, 2015 and 2014 , Condensed Consolidated Statements of Cash Flows and Condensed Consolidated Statements of Changes in Shareholders’ Equity for the six months ended June 30, 2015 and 2014 are for EXCO and its subsidiaries. The condensed consolidated financial statements and related footnotes are presented in accordance with generally accepted accounting principles in the United States ("GAAP"). Certain reclassifications have been made to prior period information to conform to current period presentation. We have prepared the accompanying unaudited interim financial statements pursuant to the rules and regulations of the Securities and Exchange Commission ("SEC") and in the opinion of management, such financial statements reflect all adjustments necessary to fairly present the consolidated financial position of EXCO at June 30, 2015 and its results of operations and cash flows for the periods presented. We have omitted certain information and disclosures normally included in annual financial statements prepared in accordance with GAAP pursuant to those rules and regulations, although we believe that the disclosures we have made are adequate to make the information presented not misleading. These unaudited interim financial statements should be read in conjunction with our audited consolidated financial statements and related footnotes included in EXCO's Annual Report on Form 10-K for the year ended December 31, 2014 , filed with the SEC on February 25, 2015 , as amended by Amendment No. 1 to Annual Report on Form 10-K/A, filed with the SEC on April 10, 2015 ("2014 Form 10-K"). In preparing the accompanying financial statements, management has made certain estimates and assumptions that affect reported amounts in the financial statements and disclosures. The results of operations for the interim periods are not necessarily indicative of the results we expect for the full year.

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2015
Accounting Policies [Abstract]
Significant accounting policies	Significant accounting policies We consider significant accounting policies to be those related to our estimates of proved reserves, oil and natural gas properties, derivatives, business combinations, share-based compensation, goodwill, revenue recognition, asset retirement obligations and income taxes. The policies include significant estimates made by management using information available at the time the estimates were made. However, these estimates could change materially if different information or assumptions were used. These policies and others are summarized in the 2014 Form 10-K. Goodwill We perform an impairment test for goodwill at least annually or more frequently as impairment indicators arise. Our impairment test is typically performed during the fourth quarter; however, we performed an impairment test as of June 30, 2015 as a result of continued depressed commodity prices and recent impairments of oil and natural gas properties. As a result of our testing, the fair value of our business exceeded the carrying value of net assets and we did not record an impairment charge during the second quarter of 2015. Recent accounting pronouncements In April 2015, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2015-03, Interest - Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs ("ASU 2015-03"). ASU 2015-03 requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. We currently recognize debt issuance costs as assets on our balance sheet. The recognition and measurement guidance for debt issuance costs are not affected by ASU 2015-03. ASU 2015-03 is effective for annual and interim periods beginning after December 15, 2015 and early adoption is permitted. We are currently assessing the potential impact the adoption of ASU 2015-03 will have on our consolidated financial statements.

Acquisitions

Acquisitions	6 Months Ended
	Jun. 30, 2015
Business Combinations [Abstract]
Acquisitions	Acquisitions Eagle Ford acquisition program We have a participation agreement with a joint venture partner in the Eagle Ford shale to mitigate the impact of development expenditures on our capital resources and liquidity ("Participation Agreement"). The Participation Agreement requires us to offer to purchase our joint venture partner's working interest in wells that have been on production for at least one year . The offers are made on a quarterly basis for a group of wells based on prices defined in the Participation Agreement, subject to specific well criteria and return hurdles. We closed the first acquisition of our joint venture partner's interest in 3 gross ( 1.4 net) wells on March 11, 2015 for a total purchase price of $7.6 million . We revised our second offer in July 2015 based on an independent evaluation from a reserve engineering firm, which included a total of 10 gross ( 5.2 net) wells for a total offer price of $16.3 million . Our joint venture partner did not accept our offer and these wells will be included in future offers. The offer for these wells did not meet the specified return hurdle in the Participation Agreement; therefore, our joint venture partner was not required to sell us the wells included in this offer. Our next offer will occur in the third quarter of 2015, which is expected to include a total of up to 26 gross ( 13.6 net) wells. The total purchase price will depend on our joint venture partner's acceptance of the offer as well as our joint venture partner's option to retain an undivided 15% of their collective interest in certain wells. If our joint venture partner accepts the offer, we expect the offer and acceptance process to be completed and the acquisition to close in the third quarter of 2015.

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2015
Asset Retirement Obligation [Abstract]
Asset retirement obligations	Asset retirement obligations The following is a reconciliation of our asset retirement obligations for the six months ended June 30, 2015 : (in thousands) Asset retirement obligations at beginning of period $ 36,755 Activity during the period: Liabilities incurred during the period 693 Liabilities settled during the period (65 ) Adjustment to liability due to acquisitions 43 Adjustment to liability due to divestitures (279 ) Accretion of discount 1,124 Asset retirement obligations at end of period 38,271 Less current portion 1,769 Long-term portion $ 36,502 Our asset retirement obligations are determined using discounted cash flow methodologies based on inputs and assumptions developed by management. We do not have any assets that are legally restricted for purposes of settling asset retirement obligations.

Oil and Natural Gas Properties

Oil and Natural Gas Properties	6 Months Ended
	Jun. 30, 2015
Oil and Gas Property [Abstract]
Oil and natural gas properties	Oil and natural gas properties We use the full cost method of accounting, which involves capitalizing all acquisition, exploration, exploitation and development costs of oil and natural gas properties. Once we incur costs, they are recorded in the depletable pool of proved properties or in unproved properties, collectively, the full cost pool. We review our unproved oil and natural gas property costs on a quarterly basis to assess for impairment or the need to transfer unproved costs to proved properties as a result of extensions or discoveries from drilling operations or determination that no proved reserves are attributable to such costs. The majority of our undeveloped properties are held-by-production, which reduces the risk of impairment as a result of lease expirations. There were no impairments of unproved properties during the six months ended June 30, 2015 and 2014 . At the end of each quarterly period, companies that use the full cost method of accounting for their oil and natural gas properties must compute a limitation on capitalized costs ("ceiling test"). The ceiling test involves comparing the net book value of the full cost pool, after taxes, to the full cost ceiling limitation defined below. In the event the full cost ceiling limitation is less than the full cost pool, we are required to record an impairment of our oil and natural gas properties. The full cost ceiling limitation is computed as the sum of the present value of estimated future net revenues from our proved reserves by applying the average price as prescribed by the SEC, less estimated future expenditures (based on current costs) to develop and produce the proved reserves, discounted at 10% , plus the cost of properties not being amortized and the lower of cost or estimated fair value of unproved properties included in the costs being amortized, net of income tax effects. The ceiling test for each period presented was based on the following average spot prices, in each case adjusted for quality factors and regional differentials to derive estimated future net revenues. Prices presented in the table below are the trailing 12 month simple average spot prices at the first of the month for natural gas at Henry Hub ("HH") and West Texas Intermediate ("WTI") crude oil at Cushing, Oklahoma. The fluctuations demonstrate the volatility in oil and natural gas prices between each of the periods and have a significant impact on our ceiling test limitation. Trailing 12 month simple average spot prices Oil (per Bbl) Natural gas (per Mmbtu) June 30, 2015 $ 71.68 $ 3.39 March 31, 2015 82.72 3.88 December 31, 2014 94.99 4.35 We recognized an impairment to our proved oil and natural gas properties of $394.3 million and $670.7 million for the three and six months ended June 30, 2015 , respectively. The impairments were primarily due to the decline in oil and natural gas prices. We did no t recognize impairments to our proved oil and natural gas properties for the three and six months ended June 30, 2014 . We may incur additional impairments to our oil and natural gas properties in 2015 if prices do not increase. The possibility and amount of any future impairment is difficult to predict, and will depend, in part, upon future oil and natural gas prices to be utilized in the ceiling test, estimates of proved reserves and future capital expenditures and operating costs. The evaluation of impairment of our oil and natural gas properties includes estimates of proved reserves. There are numerous uncertainties inherent in estimating quantities of proved reserves, in projecting the future rates of production and in the timing of development activities. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing and production subsequent to the date of the estimate may justify revisions of such estimate. Accordingly, reserve estimates often differ from the quantities of oil and natural gas that are ultimately recovered.

Earnings Per Share

Earnings Per Share	6 Months Ended
	Jun. 30, 2015
Earnings Per Share [Abstract]
Earnings per share	Earnings (loss) per share The following table presents the basic and diluted earnings (loss) per share computations for the three and six months ended June 30, 2015 and 2014 : Three Months Ended June 30, Six Months Ended June 30, (in thousands, except per share data) 2015 2014 2015 2014 Basic net income (loss) per common share: Net income (loss) $ (454,155 ) $ 2,293 $ (772,267 ) $ (2,313 ) Weighted average common shares outstanding 271,549 270,492 271,536 265,631 Net income (loss) per basic common share $ (1.67 ) $ 0.01 $ (2.84 ) $ (0.01 ) Diluted net income (loss) per common share: Net income (loss) $ (454,155 ) $ 2,293 $ (772,267 ) $ (2,313 ) Weighted average common shares outstanding 271,549 270,492 271,536 265,631 Dilutive effect of: Stock options — — — — Restricted shares and restricted share units — 734 — — Weighted average common shares and common share equivalents outstanding 271,549 271,226 271,536 265,631 Net income (loss) per diluted common share $ (1.67 ) $ 0.01 $ (2.84 ) $ (0.01 ) Diluted net income (loss) per common share for the three and six months ended June 30, 2015 and 2014 is computed in the same manner as basic income (loss) per share after assuming the issuance of common shares for all potentially dilutive common share equivalents, which include stock options, restricted share units and restricted share awards, whether exercisable or not. The computation of diluted earnings (loss) per share excluded 12,152,822 and 12,855,434 antidilutive share equivalents for the three months ended June 30, 2015 and 2014 , respectively, and 12,657,675 and 13,853,885 antidilutive share equivalents for the six months ended June 30, 2015 and 2014 , respectively.

Derivative Financial Instrument

Derivative Financial Instruments	6 Months Ended
	Jun. 30, 2015
General Discussion of Derivative Instruments and Hedging Activities [Abstract]
Derivative financial instruments	Derivative financial instruments Our primary objective in entering into derivative financial instruments is to manage our exposure to commodity price fluctuations, protect our returns on investments and achieve a more predictable cash flow from operations. These transactions limit exposure to declines in commodity prices, but also limit the benefits we would realize if commodity prices increase. When prices for oil and natural gas are volatile, a significant portion of the effect of our derivative financial instruments consists of non-cash income or expense due to changes in the fair value. Cash losses or gains only arise from payments made or received on monthly settlements of contracts or if we terminate a contract prior to its expiration. We do not designate our derivative financial instruments as hedging instruments for financial accounting purposes and, as a result, we recognize the change in the respective instruments’ fair value in earnings. The table below outlines the classification of our derivative financial instruments on our Condensed Consolidated Balance Sheets and their financial impact on our Condensed Consolidated Statements of Operations. Fair Value of Derivative Financial Instruments (in thousands) June 30, 2015 December 31, 2014 Derivative financial instruments - Current assets $ 55,111 $ 97,278 Derivative financial instruments - Long-term assets 3,772 2,138 Derivative financial instruments - Current liabilities (320 ) (892 ) Derivative financial instruments - Long-term liabilities — — Net derivative financial instruments $ 58,563 $ 98,524 Effect of Derivative Financial Instruments Three Months Ended June 30, Six Months Ended June 30, (in thousands) 2015 2014 2015 2014 Gain (loss) on derivative financial instruments $ (6,631 ) $ (14,718 ) $ 17,079 $ (57,740 ) Settlements in the normal course of maturities of our derivative financial instrument contracts result in cash receipts from, or cash disbursements to, our derivative contract counterparties. Changes in the fair value of our derivative financial instrument contracts, which includes both cash settlements and non-cash changes in fair value, are included in earnings with a corresponding increase or decrease in the Condensed Consolidated Balance Sheets fair value amounts. Our oil and natural gas derivative instruments are comprised of the following instruments: Swaps : These contracts allow us to receive a fixed price and pay a floating market price to the counterparty for the hedged commodity. Basis swaps : These contracts allow us to receive a fixed price differential between market indices for oil prices based on the delivery point. Our oil basis swaps typically have a positive differential to NYMEX WTI oil prices. Call options : These contracts give our trading counterparties the right, but not the obligation, to buy an agreed quantity of oil or natural gas from us at a certain time and price in the future. At the time of settlement, if the market price exceeds the fixed price of the call option, we pay the counterparty the excess. If the market price settles below the fixed price of the call option, no payment is due from either party. In exchange for selling this option, we received upfront proceeds which we used to obtain a higher fixed price on our swaps. These transactions were conducted contemporaneously with a single counterparty and resulted in a net cashless transaction. Three-way collars : A three-way collar is a combination of options including a sold call, a purchased put and a sold put. These contracts allow us to participate in the upside of commodity prices to the ceiling of the call option and provide us with partial downside protection through the combination of the put options. If the market price is below the strike price of the purchased put at the time of settlement then the counterparty pays us the excess, unless the market price falls below the strike price of the sold put at which point the counterparty pays us the difference between the strike prices of the purchased put and sold put. If the market price is above the strike price of the sold call at the time of settlement, we pay the counterparty the excess. These transactions were conducted contemporaneously with a single counterparty and resulted in a net cashless transaction. We place our derivative financial instruments with the financial institutions that are lenders under our credit agreement that we believe have high quality credit ratings. To mitigate our risk of loss due to default, we have entered into master netting agreements with counterparties to our derivative financial instruments that allow us to offset our asset position with our liability position in the event of a default by the counterparty. The following table presents the volumes and fair value of our oil and natural gas derivative financial instruments as of June 30, 2015 : (in thousands, except prices) Volume Mmbtu/Bbl Weighted average strike price per Mmbtu/Bbl Fair value at June 30, 2015 Natural gas: Swaps: Remainder of 2015 25,300 $ 4.02 $ 28,102 2016 16,470 3.30 2,046 2017 7,300 3.42 409 Call options: Remainder of 2015 10,120 4.29 (150 ) Three-way collars: Remainder of 2015 13,800 6,029 Sold call 4.47 Purchased put 3.83 Sold put 3.33 2016 10,980 3,615 Sold call 4.80 Purchased put 3.90 Sold put 3.40 Total natural gas $ 40,051 Oil: Swaps: Remainder of 2015 644 $ 86.44 $ 16,371 2016 732 64.82 1,986 Basis swaps: Remainder of 2015 46 6.10 158 Call options: Remainder of 2015 184 100.00 (3 ) Total oil $ 18,512 Total oil and natural gas derivative financial instruments $ 58,563 At December 31, 2014 , we had outstanding swap, call option and three-way collar contracts covering 42,888 Mmmbtu, 20,075 Mmmbtu and 38,355 Mmmbtu, respectively, of natural gas and we had outstanding swap, basis swap and call option contracts covering 1,095 Mbbls, 91 Mbbls and 365 Mbbls, respectively, of oil. At June 30, 2015 , the average forward NYMEX WTI oil prices per Bbl for the remainder of 2015 and calendar year 2016 were $60.12 , and $61.90 , respectively, the average forward NYMEX Louisiana Light Sweet ("LLS") oil prices per Bbl for the remainder of 2015 and calendar year 2016 were $62.88 , and $64.51 , respectively, and the average forward NYMEX HH natural gas prices per Mmbtu for the remainder of 2015 and calendar years 2016 and 2017 were $2.93 , $3.17 and $3.36 , respectively. Our derivative financial instruments covered approximately 65% and 67% of production volumes for the three months ended June 30, 2015 and 2014 , respectively, and 65% and 67% of production volumes for the six months ended June 30, 2015 and 2014 , respectively.

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Fair value measurements	Fair value measurements We value our derivatives and other financial instruments according to FASB ASC 820, Fair Value Measurements and Disclosures , which defines fair value as the exchange price that would be received for an asset or paid to transfer a liability ("exit price") in the principal or most advantageous market for the asset or liability in an orderly transaction between market participants on the measurement date. We categorize the inputs used in measuring fair value into a three-tier fair value hierarchy. These tiers include: Level 1 – Observable inputs, such as quoted market prices in active markets, for substantially identical assets and liabilities. Level 2 – Observable inputs other than quoted prices within Level 1 for similar assets and liabilities. These include quoted prices in markets that are not active or other inputs that are observable or can be corroborated by observable market data. If the asset or liability has a specified or contractual term, the input must be observable for substantially the full term of the asset or liability. Level 3 – Unobservable inputs that are supported by little or no market activity, generally requiring development of fair value assumptions by management. Fair value of derivative financial instruments The fair value of our derivative financial instruments may be different from the settlement value based on company-specific inputs, such as credit rating, futures markets and forward curves, and readily available buyers or sellers. During the six months ended June 30, 2015 and 2014 there were no changes in the fair value level classifications. The following table presents a summary of the estimated fair value of our derivative financial instruments as of June 30, 2015 and December 31, 2014 . June 30, 2015 (in thousands) Level 1 Level 2 Level 3 Total Oil and natural gas derivative financial instruments $ — $ 58,563 $ — $ 58,563 December 31, 2014 (in thousands) Level 1 Level 2 Level 3 Total Oil and natural gas derivative financial instruments $ — $ 98,524 $ — $ 98,524 We evaluate derivative assets and liabilities in accordance with master netting agreements with the derivative counterparties, but report them on a gross basis on our Condensed Consolidated Balance Sheets. Net derivative asset values are determined primarily by quoted futures prices and utilization of the counterparties’ credit-adjusted risk-free rate curves and net derivative liabilities are determined by utilization of our credit-adjusted risk-free rate curve. The credit-adjusted risk-free rates of our counterparties are based on an independent market-quoted credit default swap rate curve for the counterparties’ debt plus the London Interbank Offered Rate ("LIBOR") curve as of the end of the reporting period. Our credit-adjusted risk-free rate is based on the blended rate of independent market-quoted credit default swap rate curves for companies that have the same credit rating as us plus the LIBOR curve as of the end of the reporting period. The valuation of our commodity price derivatives, represented by oil and natural gas swaps, basis swaps, call option and three-way collar contracts, is discussed below. Oil derivatives . Our oil derivatives are swap, basis swap and call option contracts for notional Bbls of oil at fixed (in the case of swap and basis swap contracts) or interval (in the case of call option contracts) NYMEX oil index prices. The asset and liability values attributable to our oil derivatives as of the end of the reporting period are based on (i) the contracted notional volumes, (ii) independent active NYMEX futures price quotes for oil index prices, (iii) the applicable credit-adjusted risk-free rate curve, as described above, and (iv) the implied rate of volatility inherent in the call option contracts. The implied rates of volatility were determined based on average NYMEX oil index prices. Natural gas derivatives . Our natural gas derivatives are swap, three-way collar and call option contracts for notional Mmbtus of natural gas at posted price indexes, including NYMEX HH swap and option contracts. The asset and liability values attributable to our natural gas derivatives as of the end of the reporting period are based on (i) the contracted notional volumes, (ii) independent active NYMEX futures price quotes for HH for natural gas swaps, (iii) the applicable credit-adjusted risk-free rate curve, as described above, and (iv) the implied rate of volatility inherent in the option contracts. The implied rates of volatility were determined based on average HH natural gas prices. See further details on the fair value of our derivative financial instruments in “Note 7. Derivative financial instruments”. Fair value of other financial instruments Our financial instruments include cash and cash equivalents, accounts receivable and payable and accrued liabilities. The carrying amount of these instruments approximates fair value because of their short-term nature. The carrying values of our borrowings under the revolving commitment of our credit agreement ("EXCO Resources Credit Agreement") approximate fair value, as these are subject to short-term floating interest rates that approximate the rates available to us for those periods. The estimated fair values of our 7.5% senior unsecured notes due September 15, 2018 ("2018 Notes") and our 8.5% senior unsecured notes due April 15, 2022 ("2022 Notes") have been calculated based on market quotes and are presented below. June 30, 2015 (in thousands) Level 1 Level 2 Level 3 Total 2018 Notes $ 476,250 $ — $ — $ 476,250 2022 Notes 255,310 — — 255,310 December 31, 2014 (in thousands) Level 1 Level 2 Level 3 Total 2018 Notes $ 558,750 $ — $ — $ 558,750 2022 Notes 373,500 — — 373,500

Debt

Debt	6 Months Ended
	Jun. 30, 2015
Long-term Debt, Current and Noncurrent [Abstract]
Debt	Debt Our total debt is summarized as follows: (in thousands) June 30, 2015 December 31, 2014 EXCO Resources Credit Agreement $ 292,492 $ 202,492 2018 Notes 750,000 750,000 Unamortized discount on 2018 Notes (5,249 ) (5,957 ) 2022 Notes 500,000 500,000 Total debt $ 1,537,243 $ 1,446,535 Terms and conditions of our debt obligations as of June 30, 2015 are discussed below. EXCO Resources Credit Agreement As of June 30, 2015 , the EXCO Resources Credit Agreement had $292.5 million of outstanding indebtedness, $725.0 million borrowing base and $425.9 million of unused borrowing base, net of letters of credit. The maturity date of the EXCO Resources Credit Agreement is July 31, 2018 . The interest rate grid for the revolving commitment under the EXCO Resources Credit Agreement ranges from LIBOR plus 175 bps to 275 bps (or alternate base rate ("ABR") plus 75 bps to 175 bps), depending on our borrowing base usage. On June 30, 2015 , the one month LIBOR was 0.2% , which resulted in an interest rate of approximately 2.2% . The financial covenants under the EXCO Resources Credit Agreement include a ratio of consolidated EBITDAX to consolidated interest expense ("Interest Coverage Ratio") and a ratio of senior secured indebtedness to consolidated EBITDAX ("Secured Indebtedness Ratio"). The ratio of consolidated funded indebtedness to consolidated EBITDAX ("Leverage Ratio") is suspended until the fourth quarter of 2016. The following table presents the maximum Leverage Ratio allowed for the following periods: Period Ratio The fiscal quarter ending December 31, 2016 6.00 to 1.00 The fiscal quarter ending March 31, 2017 and June 30, 2017 5.75 to 1.00 The fiscal quarter ending September 30, 2017 5.25 to 1.00 The fiscal quarter ending December 31, 2017 4.75 to 1.00 Each fiscal quarter ending thereafter 4.50 to 1.00 The Leverage Ratio will be calculated based on the consolidated EBITDAX for the trailing four quarter period ending on the last day of such fiscal quarter, except, the consolidated EBITDAX for the quarter period ending December 31, 2016 shall be consolidated EBITDAX for quarter ending December 31, 2016 multiplied by 4.0 , consolidated EBITDAX for the two quarter period ending March 31, 2017 shall be consolidated EBITDAX for such period multiplied by 2.0 , and consolidated EBITDAX for the three quarter period ending June 30, 2017 shall be consolidated EBITDAX for such period multiplied by 4/3. As of June 30, 2015 , we were in compliance with the financial covenants (as defined in the EXCO Resources Credit Agreement), which require that we: • maintain a consolidated current ratio of at least 1.0 to 1.0 as of the end of any fiscal quarter; • maintain an Interest Coverage Ratio of at least 2.0 to 1.0 as of the end of any fiscal quarter; and • not permit our Secured Indebtedness Ratio to be greater than 2.5 to 1.0 as of the end of any fiscal quarter. On July 27, 2015, we amended the EXCO Resources Credit Agreement which decreased our borrowing base from $725.0 million to $600.0 million in connection with our semi-annual borrowing base redetermination. Subsequent redeterminations will occur semi-annually with us and the lenders having the right to request interim unscheduled redeterminations in certain circumstances. The next scheduled borrowing base redetermination for the EXCO Resources Credit Agreement will occur in the first quarter of 2016. The amendment also included modifications to our financial covenants, interest rate grid and borrowing base if we issue certain indebtedness subordinated to the EXCO Resources Credit Agreement. In the event of the incurrence of such indebtedness, the borrowing base will be automatically reduced by an amount equal to 33% of the principal amount of such indebtedness incurred; provided that in no event shall the borrowing base be less than $362.5 million . The interest rate grid will be increased by 50 bps if we incur such indebtedness in excess of $300.0 million . If we have not incurred $300.0 million in such indebtedness by December 31, 2016, the Secured Indebtedness Ratio will be temporarily suspended until the issuance of this indebtedness. The issuance of such indebtedness in excess of $300.0 million would result in a modification to the Interest Coverage Ratio to require that we maintain a ratio of at least 1.25 to 1.00 as of the end of any fiscal quarter and the termination of the Leverage Ratio. While we believe our existing capital resources, including our cash flow from operations and borrowing capacity under the EXCO Resources Credit Agreement are sufficient to conduct our operations through 2015 and 2016, there are certain risks arising from depressed oil and natural gas prices and declines in production volumes that could impact our ability to meet debt covenants in future periods. Our ability to maintain compliance with these covenants may be negatively impacted if oil and/or natural gas prices remain depressed for an extended period of time. We are currently evaluating transactions that would further enhance our liquidity and provide us with additional financial flexibility to accelerate the development of our oil and natural gas properties. This may include, but is not limited to, plans to refinance our existing indebtedness, incur additional senior or subordinated indebtedness, issue equity or divest assets. We may not undertake or be able to complete these transactions, and the extent and timing of these transactions are dependent upon financial, business, economic, regulatory and other factors. The issuance of subordinated indebtedness to the EXCO Resources Credit Agreement may result in a further reduction in our borrowing base. 2018 Notes The 2018 Notes are guaranteed on a senior unsecured basis by a majority of EXCO’s subsidiaries, with the exception of certain non-guarantor subsidiaries and our jointly-held equity investments with BG Group. Our equity investments, other than OPCO, have been designated as unrestricted subsidiaries under the indenture governing the 2018 Notes. As of June 30, 2015 , $750.0 million in principal was outstanding on the 2018 Notes. The unamortized discount on the 2018 Notes at June 30, 2015 was $5.2 million . Interest accrues at 7.5% per annum and is payable semi-annually in arrears on March 15 and September 15 of each year. The indenture governing the 2018 Notes contains covenants, which may limit our ability and the ability of our restricted subsidiaries to: • incur or guarantee additional debt and issue certain types of preferred stock; • pay dividends on our capital stock or redeem, repurchase or retire our capital stock or subordinated debt; • make certain investments; • create liens on our assets; • enter into sale/leaseback transactions; • create restrictions on the ability of our restricted subsidiaries to pay dividends or make other payments to us; • engage in transactions with our affiliates; • transfer or issue shares of stock of subsidiaries; • transfer or sell assets; and • consolidate, merge or transfer all or substantially all of our assets and the assets of our subsidiaries. 2022 Notes As of June 30, 2015 , $500.0 million in principal was outstanding on the 2022 Notes. The 2022 Notes were issued at 100.0% of the principal amount and bear interest at a rate of 8.5% per annum, payable in arrears on April 15 and October 15 of each year. The 2022 Notes rank equally in right of payment to any existing and future senior unsecured indebtedness of the Company (including the 2018 Notes) and are guaranteed on a senior unsecured basis by EXCO’s consolidated subsidiaries that are guarantors of the indebtedness under the EXCO Resources Credit Agreement. The 2022 Notes were issued under the same base indenture governing the 2018 Notes and the supplemental indenture governing the 2022 Notes contains similar covenants to those in the supplemental indenture governing the 2018 Notes.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2015
Income Tax Disclosure [Abstract]
Income taxes	Income taxes We evaluate our estimated annual effective income tax rate based on current and forecasted business results and enacted tax laws on a quarterly basis and apply this tax rate to our ordinary income or loss to calculate our estimated tax liability or benefit. We have accumulated financial deferred tax assets primarily due to losses arising from impairments to the carrying value of our oil and natural gas properties that are subject to valuation allowances. Our valuation allowances increased $299.3 million for the six months ended June 30, 2015 . As a result of cumulative financial operating losses, we have recognized net valuation allowances of approximately $1.1 billion which have fully offset our net deferred tax assets as of June 30, 2015 . The valuation allowances will continue to be recognized until the realization of future deferred tax benefits are more likely than not to become utilized. The valuation allowances do not impact future utilization of the underlying tax attributes.

Related Party Transactions

Related Party Transactions	6 Months Ended
	Jun. 30, 2015
Related Party Transactions [Abstract]
Related party transactions	Related party transactions OPCO serves as the operator of our wells in the Appalachia JV and we advance funds to OPCO on an as needed basis. We did not advance any funds to OPCO for the three and six months ended June 30, 2015 and 2014. OPCO may distribute any excess cash equally between us and BG Group when its operating cash flows are sufficient to meet its capital requirements. There are service agreements between us and OPCO whereby we provide administrative and technical services for which we are reimbursed. For the three and six months ended June 30, 2015 and 2014 , these transactions included the following: Three Months Ended June 30, Six Months Ended June 30, (in thousands) 2015 2014 2015 2014 Amounts received from OPCO $ 8,273 $ 11,259 $ 16,566 $ 20,971 As of June 30, 2015 and December 31, 2014 , the amounts owed were as follows: (in thousands) June 30, 2015 December 31, 2014 Amounts due to EXCO (1) $ 2,447 $ 2,799 Amounts due from EXCO (1) 5,502 — (1) Advances to OPCO are recorded in "Other current assets" on our Condensed Consolidated Balance Sheets. Any amounts we owe to OPCO are netted against the advance until the advances are utilized. If the advances are fully utilized, we record amounts owed in "Accounts payable and accrued liabilities" on our Condensed Consolidated Balance Sheets.

Services and Investment Agreeme

Services and Investment Agreement	6 Months Ended
	Jun. 30, 2015
Services and Investment Agreement [Abstract]
Services and Investment Agreement	Services and Investment Agreement On March 31, 2015 , we entered into a four year services and investment agreement with Energy Strategic Advisory Services LLC (“ESAS”), a wholly-owned subsidiary of Bluescape Resources Company LLC (“Bluescape”). As part of the agreement, ESAS will provide certain strategic advisory services, including the development and execution of a strategic improvement plan. The closing of the transactions contemplated by this agreement will be subject to certain conditions, including, among others, obtaining certain approvals from EXCO’s shareholders at EXCO's 2015 Annual Meeting of Shareholders, to be held on August 5, 2015 ("Annual Meeting"). At the closing, C. John Wilder, Executive Chairman of Bluescape, will become Executive Chairman of EXCO's Board of Directors. Pursuant to the agreement, ESAS has agreed to purchase 5,882,353 common shares from EXCO, par value $0.001 per share, at a price per share of $1.70 , upon the effectiveness of a resale registration statement. In April 2015, ESAS deposited $10.0 million in escrow to be paid to EXCO upon acquisition of such shares. In addition, ESAS will be obligated to purchase at least $40.0 million additional common shares through open market purchases during the one year following the closing such that ESAS will own common shares of EXCO with an aggregate cost basis of at least $50.0 million as of the first anniversary of the closing date, subject to certain extensions and exceptions. As consideration for the services to be provided under the agreement, EXCO will pay ESAS a monthly fee of $300,000 and an annual incentive payment of up to $2.4 million per year that will be based on EXCO’s common share price achieving certain performance hurdles as compared to a peer group, provided that payment for the services will be held in escrow and contingent upon completion of the entire first year of services and required investment in EXCO. If EXCO’s performance rank is in the bottom half of the peer group, then the incentive payment will be zero . The incentive payment increases linearly from $1.0 million to $2.4 million as EXCO’s performance rank increases from the 50th to 75th percentile, as compared to the peer group. If EXCO’s performance rank is in the 75th percentile or above, then the incentive payment will be $2.4 million . As of June 30, 2015, we did not recognize any expense for the annual incentive payment as a result of EXCO's performance rank. As additional performance incentives, EXCO has issued warrants to ESAS in four tranches to purchase an aggregate of 80,000,000 common shares. The table below lists the number of common shares issuable upon exercise of the warrants at each exercise price and the term of the warrants. Number of shares issuable Exercise Price Term (in months) 15,000,000 $2.75 49 20,000,000 $4.00 60 20,000,000 $7.00 72 25,000,000 $10.00 72 The warrants will vest on the fourth anniversary of the agreement and their exercisability is subject to EXCO’s common share price achieving certain performance hurdles as compared to the peer group. If EXCO’s performance rank is in the bottom half of the peer group, then the warrants will be forfeited and void. The number of the exercisable shares under the warrants increases linearly from 32,000,000 to 80,000,000 as EXCO’s performance rank increases from the 50th to 75th percentile, as compared to the peer group. If EXCO’s performance rank is in the 75th percentile or above, then all 80,000,000 warrants will be exercisable. The performance measurement period began on March 31, 2015 and will end on the fourth anniversary of the execution of the agreement. Prior to March 31, 2019, if EXCO terminates the agreement for any reason other than for cause (as defined in the agreement), or ESAS terminates the agreement for cause (as defined in the agreement), then all of the warrants will fully vest and become exercisable. Prior to March 31, 2019, if ESAS terminates the agreement for any reason other than for cause, or EXCO terminates the agreement for cause, then all of the warrants will be canceled and forfeited. The closing of the transactions contemplated by this agreement is subject to certain conditions, including, among others, certain approvals from EXCO's shareholders. The warrants will automatically terminate and become void and of no force or effect if the closing does not occur. At the Annual Meeting, EXCO’s shareholders will be asked to vote on proposals to, among other things, approve (i) the issuance of the warrants, (ii) an amendment to EXCO’s Third Amended and Restated Articles of Incorporation, as amended (the “Charter”), to increase the authorized number of common shares available for issuance to 780,000,000 and (iii) an amendment to the Charter to include a waiver of the duty of directors to present corporate opportunities to EXCO. The approval by our shareholders of these proposals will allow us, subject to the satisfaction or waiver of the other conditions contained in the services and investment agreement, to consummate the closing of the agreement. In accordance with FASB ASC Topic 718, Compensation - Stock Compensation ("ASC 718"), the grant date related to these warrants will be established upon approval of EXCO’s shareholders and closing of the transactions contemplated by the agreement and the related compensation costs will be recognized over the requisite service period from the grant date to the termination of the agreement. The fair value of the warrants on the grant date will be dependent on factors such as our share price, historical volatility, risk-free rate and performance relative to our peer group. The measurement of the warrants will be accounted for in accordance with ASC Topic 505-50, Equity-Based Payments to Non-Employees , which requires the warrants to be re-measured each interim reporting period until the completion of the services under the agreement.

Condensed Consolidating Financi

Condensed Consolidating Financial Statements	6 Months Ended
	Jun. 30, 2015
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed consolidating financial statements	Condensed consolidating financial statements As of June 30, 2015 , the majority of EXCO’s subsidiaries were guarantors under the EXCO Resources Credit Agreement and the indentures governing the 2018 Notes and 2022 Notes. All of our non-guarantor subsidiaries were considered unrestricted subsidiaries under the indentures governing the 2018 Notes and 2022 Notes, with the exception of our equity investment in OPCO. Set forth below are condensed consolidating financial statements of EXCO, the guarantor subsidiaries and the non-guarantor subsidiaries. The 2018 Notes and 2022 Notes, which were issued by EXCO Resources, Inc., are jointly and severally guaranteed by some of our subsidiaries (referred to as Guarantor Subsidiaries). For purposes of this footnote, EXCO Resources, Inc. is referred to as Resources to distinguish it from the Guarantor Subsidiaries. Each of the Guarantor Subsidiaries is a 100% owned subsidiary of Resources and the guarantees are unconditional as they relate to the assets of the Guarantor Subsidiaries. The following financial information presents consolidating financial statements, which include: • Resources; • the Guarantor Subsidiaries; • the Non-Guarantor Subsidiaries; • elimination entries necessary to consolidate Resources, the Guarantor Subsidiaries and the Non-Guarantor Subsidiaries; and • EXCO on a consolidated basis. Investments in subsidiaries are accounted for using the equity method of accounting for the disclosures within this footnote. The financial information for the Guarantor Subsidiaries and the Non-Guarantor Subsidiaries is presented on a combined basis. The elimination entries primarily eliminate investments in subsidiaries and intercompany balances and transactions. EXCO RESOURCES, INC. CONDENSED CONSOLIDATING BALANCE SHEET (Unaudited) June 30, 2015 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 68,969 $ (19,062 ) $ — $ — $ 49,907 Restricted cash 600 16,981 — — 17,581 Other current assets 65,397 101,447 — — 166,844 Total current assets 134,966 99,366 — — 234,332 Equity investments — — 55,188 — 55,188 Oil and natural gas properties (full cost accounting method): Unproved oil and natural gas properties and development costs not being amortized — 248,196 — — 248,196 Proved developed and undeveloped oil and natural gas properties 330,776 3,055,172 — — 3,385,948 Accumulated depletion (330,776 ) (2,206,700 ) — — (2,537,476 ) Oil and natural gas properties, net — 1,096,668 — — 1,096,668 Other property and equipment, net 905 23,032 — — 23,937 Investments in and advances to affiliates, net 1,140,229 — — (1,140,229 ) — Deferred financing costs, net 26,385 — — — 26,385 Derivative financial instruments 3,772 — — — 3,772 Goodwill 13,293 149,862 — — 163,155 Deferred income taxes 18,669 — — — 18,669 Total assets $ 1,338,219 $ 1,368,928 $ 55,188 $ (1,140,229 ) $ 1,622,106 Liabilities and shareholders' equity Current liabilities $ 58,397 $ 247,385 $ — $ — $ 305,782 Long-term debt 1,537,243 — — — 1,537,243 Other long-term liabilities — 36,502 — — 36,502 Payable to parent — 2,183,057 — (2,183,057 ) — Total shareholders' equity (257,421 ) (1,098,016 ) 55,188 1,042,828 (257,421 ) Total liabilities and shareholders' equity $ 1,338,219 $ 1,368,928 $ 55,188 $ (1,140,229 ) $ 1,622,106 EXCO RESOURCES, INC. CONDENSED CONSOLIDATING BALANCE SHEET December 31, 2014 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 86,837 $ (40,532 ) $ — $ — $ 46,305 Restricted cash — 23,970 — — 23,970 Other current assets 110,145 150,346 — — 260,491 Total current assets 196,982 133,784 — — 330,766 Equity investments — — 55,985 — 55,985 Oil and natural gas properties (full cost accounting method): Unproved oil and natural gas properties and development costs not being amortized — 276,025 — — 276,025 Proved developed and undeveloped oil and natural gas properties 335,838 3,516,235 — — 3,852,073 Accumulated depletion (330,771 ) (2,083,690 ) — — (2,414,461 ) Oil and natural gas properties, net 5,067 1,708,570 — — 1,713,637 Other property and equipment, net 1,269 23,375 — — 24,644 Investments in and advances to affiliates, net 1,746,931 — — (1,746,931 ) — Deferred financing costs, net 30,636 — — — 30,636 Derivative financial instruments 2,138 — — — 2,138 Goodwill 13,293 149,862 — — 163,155 Deferred income tax 35,935 — — — 35,935 Total assets $ 2,032,251 $ 2,015,591 $ 55,985 $ (1,746,931 ) $ 2,356,896 Liabilities and shareholders' equity Current liabilities $ 75,441 $ 289,930 $ — $ — $ 365,371 Long-term debt 1,446,535 — — — 1,446,535 Other long-term liabilities 271 34,715 — — 34,986 Payable to parent — 2,058,683 — (2,058,683 ) — Total shareholders' equity 510,004 (367,737 ) 55,985 311,752 510,004 Total liabilities and shareholders' equity $ 2,032,251 $ 2,015,591 $ 55,985 $ (1,746,931 ) $ 2,356,896 EXCO RESOURCES, INC. CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS (Unaudited) For the three months ended June 30, 2015 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Revenues: Oil and natural gas $ (18 ) $ 93,760 $ — $ — $ 93,742 Costs and expenses: Oil and natural gas production (15 ) 19,753 — — 19,738 Gathering and transportation — 24,785 — — 24,785 Depletion, depreciation and amortization 245 61,413 — — 61,658 Impairment of oil and natural gas properties 1,551 392,776 — — 394,327 Accretion of discount on asset retirement obligations — 568 — — 568 General and administrative (3,503 ) 16,100 — — 12,597 Other operating items 1,916 (382 ) — — 1,534 Total costs and expenses 194 515,013 — — 515,207 Operating loss (212 ) (421,253 ) — — (421,465 ) Other income (expense): Interest expense, net (25,571 ) — — — (25,571 ) Loss on derivative financial instruments (6,631 ) — — — (6,631 ) Other income 39 8 — — 47 Equity loss — — (535 ) — (535 ) Net loss from consolidated subsidiaries (421,780 ) — — 421,780 — Total other income (expense) (453,943 ) 8 (535 ) 421,780 (32,690 ) Loss before income taxes (454,155 ) (421,245 ) (535 ) 421,780 (454,155 ) Income tax expense — — — — — Net loss $ (454,155 ) $ (421,245 ) $ (535 ) $ 421,780 $ (454,155 ) EXCO RESOURCES, INC. CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS (Unaudited) For the three months ended June 30, 2014 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Revenues: Oil and natural gas $ 306 $ 169,795 $ 12,865 $ — $ 182,966 Costs and expenses: Oil and natural gas production 76 18,196 4,919 — 23,191 Gathering and transportation — 24,899 1,139 — 26,038 Depletion, depreciation and amortization 727 61,840 4,686 — 67,253 Accretion of discount on asset retirement obligations 4 522 169 — 695 General and administrative 962 17,949 593 — 19,504 Other operating items (12 ) 2,977 8 — 2,973 Total costs and expenses 1,757 126,383 11,514 — 139,654 Operating income (loss) (1,451 ) 43,412 1,351 — 43,312 Other income (expense): Interest expense, net (25,301 ) — (667 ) — (25,968 ) Loss on derivative financial instruments (13,958 ) — (760 ) — (14,718 ) Other income 59 14 4 — 77 Equity loss — — (410 ) — (410 ) Net income from consolidated subsidiaries 42,944 — — (42,944 ) — Total other income (expense) 3,744 14 (1,833 ) (42,944 ) (41,019 ) Income (loss) before income taxes 2,293 43,426 (482 ) (42,944 ) 2,293 Income tax expense — — — — — Net income (loss) $ 2,293 $ 43,426 $ (482 ) $ (42,944 ) $ 2,293 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Revenues: Oil and natural gas $ 4 $ 180,058 $ — $ — $ 180,062 Costs and expenses: Oil and natural gas production 23 39,517 — — 39,540 Gathering and transportation — 50,500 — — 50,500 Depletion, depreciation and amortization 524 123,623 — — 124,147 Impairment of oil and natural gas properties 6,891 663,763 — — 670,654 Accretion of discount on asset retirement obligations 4 1,120 — — 1,124 General and administrative (4,224 ) 32,058 — — 27,834 Other operating items 2,068 (722 ) — — 1,346 Total costs and expenses 5,286 909,859 — — 915,145 Operating loss (5,282 ) (729,801 ) — — (735,083 ) Other income (expense): Interest expense, net (53,061 ) — — — (53,061 ) Gain on derivative financial instruments 17,079 — — — 17,079 Other income 73 25 — — 98 Equity loss — — (1,300 ) — (1,300 ) Net loss from consolidated subsidiaries (731,076 ) — — 731,076 — Total other income (expense) (766,985 ) 25 (1,300 ) 731,076 (37,184 ) Loss before income taxes (772,267 ) (729,776 ) (1,300 ) 731,076 (772,267 ) Income tax expense — — — — — Net loss $ (772,267 ) $ (729,776 ) $ (1,300 ) $ 731,076 $ (772,267 ) EXCO RESOURCES, INC. CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS (Unaudited) For the six months ended June 30, 2015 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating Activities: Net cash provided by operating activities $ 19,024 $ 89,180 $ — $ — $ 108,204 Investing Activities: Additions to oil and natural gas properties, gathering assets and equipment and property acquisitions (1,174 ) (211,034 ) — — (212,208 ) Proceeds from disposition of property and equipment 686 6,711 — — 7,397 Restricted cash — 6,989 — — 6,989 Net changes in advances to joint ventures — 5,756 — — 5,756 Equity method investments — (503 ) — — (503 ) Advances/investments with affiliates (124,371 ) 124,371 — — — Net cash used in investing activities (124,859 ) (67,710 ) — — (192,569 ) Financing Activities: Borrowings under credit agreements 90,000 — — — 90,000 Payments for issuance of common shares, net (2 ) — — — (2 ) Payments of common share dividends (15 ) — — — (15 ) Deferred financing costs and other (2,016 ) — — — (2,016 ) Net cash provided by financing activities 87,967 — — — 87,967 Net increase (decrease) in cash (17,868 ) 21,470 — — 3,602 Cash at beginning of period 86,837 (40,532 ) — — 46,305 Cash at end of period $ 68,969 $ (19,062 ) $ — $ — $ 49,907 EXCO RESOURCES, INC. CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS (Unaudited) For the six months ended June 30, 2014 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating Activities: Net cash provided by (used in) operating activities $ (54,003 ) $ 310,651 $ 11,474 $ — $ 268,122 Investing Activities: Additions to oil and natural gas properties, gathering assets and equipment and property acquisitions (1,639 ) (193,606 ) (2,522 ) — (197,767 ) Proceeds from disposition of property and equipment 68,242 8,017 7 — 76,266 Restricted cash — 5,349 — — 5,349 Net changes in advances to joint ventures — (10,540 ) — — (10,540 ) Equity method investments — 1,749 — — 1,749 Distributions received from Compass 3,311 — — (3,311 ) — Advances/investments with affiliates 107,240 (107,240 ) — — — Net cash provided by (used) in investing activities 177,154 (296,271 ) (2,515 ) (3,311 ) (124,943 ) Financing Activities: Repayments under credit agreements (879,874 ) — (2,550 ) — (882,424 ) Proceeds received from issuance of 2022 Notes 500,000 — — — 500,000 Proceeds from issuance of common shares, net 271,772 — — — 271,772 Payments of common share dividends (27,066 ) — — — (27,066 ) Compass cash distribution — — (3,311 ) 3,311 — Deferred financing costs and other (10,066 ) — — — (10,066 ) Net cash provided by (used in) financing activities (145,234 ) — (5,861 ) 3,311 (147,784 ) Net increase in cash (22,083 ) 14,380 3,098 — (4,605 ) Cash at beginning of period 81,840 (35,892 ) 4,535 — 50,483 Cash at end of period $ 59,757 $ (21,512 ) $ 7,633 $ — $ 45,878

Summary Of Significant Accoun20

Summary Of Significant Accounting Policies (Policy)	6 Months Ended
	Jun. 30, 2015
Accounting Policies [Abstract]
Industry Specific Policies, Oil and Gas	Oil and natural gas properties We use the full cost method of accounting, which involves capitalizing all acquisition, exploration, exploitation and development costs of oil and natural gas properties. Once we incur costs, they are recorded in the depletable pool of proved properties or in unproved properties, collectively, the full cost pool. We review our unproved oil and natural gas property costs on a quarterly basis to assess for impairment or the need to transfer unproved costs to proved properties as a result of extensions or discoveries from drilling operations or determination that no proved reserves are attributable to such costs. The majority of our undeveloped properties are held-by-production, which reduces the risk of impairment as a result of lease expirations. There were no impairments of unproved properties during the six months ended June 30, 2015 and 2014 . At the end of each quarterly period, companies that use the full cost method of accounting for their oil and natural gas properties must compute a limitation on capitalized costs ("ceiling test"). The ceiling test involves comparing the net book value of the full cost pool, after taxes, to the full cost ceiling limitation defined below. In the event the full cost ceiling limitation is less than the full cost pool, we are required to record an impairment of our oil and natural gas properties. The full cost ceiling limitation is computed as the sum of the present value of estimated future net revenues from our proved reserves by applying the average price as prescribed by the SEC, less estimated future expenditures (based on current costs) to develop and produce the proved reserves, discounted at 10% , plus the cost of properties not being amortized and the lower of cost or estimated fair value of unproved properties included in the costs being amortized, net of income tax effects. The ceiling test for each period presented was based on the following average spot prices, in each case adjusted for quality factors and regional differentials to derive estimated future net revenues. Prices presented in the table below are the trailing 12 month simple average spot prices at the first of the month for natural gas at Henry Hub ("HH") and West Texas Intermediate ("WTI") crude oil at Cushing, Oklahoma. The fluctuations demonstrate the volatility in oil and natural gas prices between each of the periods and have a significant impact on our ceiling test limitation. Trailing 12 month simple average spot prices Oil (per Bbl) Natural gas (per Mmbtu) June 30, 2015 $ 71.68 $ 3.39 March 31, 2015 82.72 3.88 December 31, 2014 94.99 4.35 We recognized an impairment to our proved oil and natural gas properties of $394.3 million and $670.7 million for the three and six months ended June 30, 2015 , respectively. The impairments were primarily due to the decline in oil and natural gas prices. We did no t recognize impairments to our proved oil and natural gas properties for the three and six months ended June 30, 2014 . We may incur additional impairments to our oil and natural gas properties in 2015 if prices do not increase. The possibility and amount of any future impairment is difficult to predict, and will depend, in part, upon future oil and natural gas prices to be utilized in the ceiling test, estimates of proved reserves and future capital expenditures and operating costs. The evaluation of impairment of our oil and natural gas properties includes estimates of proved reserves. There are numerous uncertainties inherent in estimating quantities of proved reserves, in projecting the future rates of production and in the timing of development activities. The accuracy of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing and production subsequent to the date of the estimate may justify revisions of such estimate. Accordingly, reserve estimates often differ from the quantities of oil and natural gas that are ultimately recovered.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2015
Asset Retirement Obligation [Abstract]
Schedule of Asset Retirement Obligations	The following is a reconciliation of our asset retirement obligations for the six months ended June 30, 2015 : (in thousands) Asset retirement obligations at beginning of period $ 36,755 Activity during the period: Liabilities incurred during the period 693 Liabilities settled during the period (65 ) Adjustment to liability due to acquisitions 43 Adjustment to liability due to divestitures (279 ) Accretion of discount 1,124 Asset retirement obligations at end of period 38,271 Less current portion 1,769 Long-term portion $ 36,502

Oil and Natural Gas Properties

Oil and Natural Gas Properties Oil and Natural Gas Properties (Tables)	6 Months Ended
	Jun. 30, 2015
Oil and Gas Property [Abstract]
Average spot price	Trailing 12 month simple average spot prices Oil (per Bbl) Natural gas (per Mmbtu) June 30, 2015 $ 71.68 $ 3.39 March 31, 2015 82.72 3.88 December 31, 2014 94.99 4.35

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2015
Earnings Per Share [Abstract]
Basic And Diluted Earnings Per Share Computations	The following table presents the basic and diluted earnings (loss) per share computations for the three and six months ended June 30, 2015 and 2014 : Three Months Ended June 30, Six Months Ended June 30, (in thousands, except per share data) 2015 2014 2015 2014 Basic net income (loss) per common share: Net income (loss) $ (454,155 ) $ 2,293 $ (772,267 ) $ (2,313 ) Weighted average common shares outstanding 271,549 270,492 271,536 265,631 Net income (loss) per basic common share $ (1.67 ) $ 0.01 $ (2.84 ) $ (0.01 ) Diluted net income (loss) per common share: Net income (loss) $ (454,155 ) $ 2,293 $ (772,267 ) $ (2,313 ) Weighted average common shares outstanding 271,549 270,492 271,536 265,631 Dilutive effect of: Stock options — — — — Restricted shares and restricted share units — 734 — — Weighted average common shares and common share equivalents outstanding 271,549 271,226 271,536 265,631 Net income (loss) per diluted common share $ (1.67 ) $ 0.01 $ (2.84 ) $ (0.01 )

Derivative Financial Instrume24

Derivative Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2015
General Discussion of Derivative Instruments and Hedging Activities [Abstract]
Fair Value Of Derivative Financial Instruments	Fair Value of Derivative Financial Instruments (in thousands) June 30, 2015 December 31, 2014 Derivative financial instruments - Current assets $ 55,111 $ 97,278 Derivative financial instruments - Long-term assets 3,772 2,138 Derivative financial instruments - Current liabilities (320 ) (892 ) Derivative financial instruments - Long-term liabilities — — Net derivative financial instruments $ 58,563 $ 98,524
Effect Of Derivative Financial Instruments	Effect of Derivative Financial Instruments Three Months Ended June 30, Six Months Ended June 30, (in thousands) 2015 2014 2015 2014 Gain (loss) on derivative financial instruments $ (6,631 ) $ (14,718 ) $ 17,079 $ (57,740 )
Fair Value Of Oil And Natural Gas Derivative Financial Instruments	The following table presents the volumes and fair value of our oil and natural gas derivative financial instruments as of June 30, 2015 : (in thousands, except prices) Volume Mmbtu/Bbl Weighted average strike price per Mmbtu/Bbl Fair value at June 30, 2015 Natural gas: Swaps: Remainder of 2015 25,300 $ 4.02 $ 28,102 2016 16,470 3.30 2,046 2017 7,300 3.42 409 Call options: Remainder of 2015 10,120 4.29 (150 ) Three-way collars: Remainder of 2015 13,800 6,029 Sold call 4.47 Purchased put 3.83 Sold put 3.33 2016 10,980 3,615 Sold call 4.80 Purchased put 3.90 Sold put 3.40 Total natural gas $ 40,051 Oil: Swaps: Remainder of 2015 644 $ 86.44 $ 16,371 2016 732 64.82 1,986 Basis swaps: Remainder of 2015 46 6.10 158 Call options: Remainder of 2015 184 100.00 (3 ) Total oil $ 18,512 Total oil and natural gas derivative financial instruments $ 58,563

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Summary Of Estimated Fair Value Of Derivative Financial Instruments	The following table presents a summary of the estimated fair value of our derivative financial instruments as of June 30, 2015 and December 31, 2014 . June 30, 2015 (in thousands) Level 1 Level 2 Level 3 Total Oil and natural gas derivative financial instruments $ — $ 58,563 $ — $ 58,563 December 31, 2014 (in thousands) Level 1 Level 2 Level 3 Total Oil and natural gas derivative financial instruments $ — $ 98,524 $ — $ 98,524
Schedule Of Estimated Fair Value Of Other Financial Instruments	The estimated fair values of our 7.5% senior unsecured notes due September 15, 2018 ("2018 Notes") and our 8.5% senior unsecured notes due April 15, 2022 ("2022 Notes") have been calculated based on market quotes and are presented below. June 30, 2015 (in thousands) Level 1 Level 2 Level 3 Total 2018 Notes $ 476,250 $ — $ — $ 476,250 2022 Notes 255,310 — — 255,310 December 31, 2014 (in thousands) Level 1 Level 2 Level 3 Total 2018 Notes $ 558,750 $ — $ — $ 558,750 2022 Notes 373,500 — — 373,500

Debt (Tables)

Debt (Tables)	6 Months Ended
	Jun. 30, 2015
Long-term Debt, Current and Noncurrent [Abstract]
Schedule Of Debt	Our total debt is summarized as follows: (in thousands) June 30, 2015 December 31, 2014 EXCO Resources Credit Agreement $ 292,492 $ 202,492 2018 Notes 750,000 750,000 Unamortized discount on 2018 Notes (5,249 ) (5,957 ) 2022 Notes 500,000 500,000 Total debt $ 1,537,243 $ 1,446,535

Related Party Transactions (Tab

Related Party Transactions (Tables)	6 Months Ended
	Jun. 30, 2015
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	For the three and six months ended June 30, 2015 and 2014 , these transactions included the following: Three Months Ended June 30, Six Months Ended June 30, (in thousands) 2015 2014 2015 2014 Amounts received from OPCO $ 8,273 $ 11,259 $ 16,566 $ 20,971 As of June 30, 2015 and December 31, 2014 , the amounts owed were as follows: (in thousands) June 30, 2015 December 31, 2014 Amounts due to EXCO (1) $ 2,447 $ 2,799 Amounts due from EXCO (1) 5,502 — (1) Advances to OPCO are recorded in "Other current assets" on our Condensed Consolidated Balance Sheets. Any amounts we owe to OPCO are netted against the advance until the advances are utilized. If the advances are fully utilized, we record amounts owed in "Accounts payable and accrued liabilities" on our Condensed Consolidated Balance Sheets.

Services and Investment Agree28

Services and Investment Agreement (Tables)	6 Months Ended
	Jun. 30, 2015
Services and Investment Agreement [Abstract]
Schedule of Stockholders' Equity Note, Warrants or Rights	The table below lists the number of common shares issuable upon exercise of the warrants at each exercise price and the term of the warrants. Number of shares issuable Exercise Price Term (in months) 15,000,000 $2.75 49 20,000,000 $4.00 60 20,000,000 $7.00 72 25,000,000 $10.00 72

Condensed Consolidating Finan29

Condensed Consolidating Financial Statements (Tables)	6 Months Ended
	Jun. 30, 2015
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Schedule Of Condensed Consolidating Balance Sheet	EXCO RESOURCES, INC. CONDENSED CONSOLIDATING BALANCE SHEET (Unaudited) June 30, 2015 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 68,969 $ (19,062 ) $ — $ — $ 49,907 Restricted cash 600 16,981 — — 17,581 Other current assets 65,397 101,447 — — 166,844 Total current assets 134,966 99,366 — — 234,332 Equity investments — — 55,188 — 55,188 Oil and natural gas properties (full cost accounting method): Unproved oil and natural gas properties and development costs not being amortized — 248,196 — — 248,196 Proved developed and undeveloped oil and natural gas properties 330,776 3,055,172 — — 3,385,948 Accumulated depletion (330,776 ) (2,206,700 ) — — (2,537,476 ) Oil and natural gas properties, net — 1,096,668 — — 1,096,668 Other property and equipment, net 905 23,032 — — 23,937 Investments in and advances to affiliates, net 1,140,229 — — (1,140,229 ) — Deferred financing costs, net 26,385 — — — 26,385 Derivative financial instruments 3,772 — — — 3,772 Goodwill 13,293 149,862 — — 163,155 Deferred income taxes 18,669 — — — 18,669 Total assets $ 1,338,219 $ 1,368,928 $ 55,188 $ (1,140,229 ) $ 1,622,106 Liabilities and shareholders' equity Current liabilities $ 58,397 $ 247,385 $ — $ — $ 305,782 Long-term debt 1,537,243 — — — 1,537,243 Other long-term liabilities — 36,502 — — 36,502 Payable to parent — 2,183,057 — (2,183,057 ) — Total shareholders' equity (257,421 ) (1,098,016 ) 55,188 1,042,828 (257,421 ) Total liabilities and shareholders' equity $ 1,338,219 $ 1,368,928 $ 55,188 $ (1,140,229 ) $ 1,622,106 EXCO RESOURCES, INC. CONDENSED CONSOLIDATING BALANCE SHEET December 31, 2014 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 86,837 $ (40,532 ) $ — $ — $ 46,305 Restricted cash — 23,970 — — 23,970 Other current assets 110,145 150,346 — — 260,491 Total current assets 196,982 133,784 — — 330,766 Equity investments — — 55,985 — 55,985 Oil and natural gas properties (full cost accounting method): Unproved oil and natural gas properties and development costs not being amortized — 276,025 — — 276,025 Proved developed and undeveloped oil and natural gas properties 335,838 3,516,235 — — 3,852,073 Accumulated depletion (330,771 ) (2,083,690 ) — — (2,414,461 ) Oil and natural gas properties, net 5,067 1,708,570 — — 1,713,637 Other property and equipment, net 1,269 23,375 — — 24,644 Investments in and advances to affiliates, net 1,746,931 — — (1,746,931 ) — Deferred financing costs, net 30,636 — — — 30,636 Derivative financial instruments 2,138 — — — 2,138 Goodwill 13,293 149,862 — — 163,155 Deferred income tax 35,935 — — — 35,935 Total assets $ 2,032,251 $ 2,015,591 $ 55,985 $ (1,746,931 ) $ 2,356,896 Liabilities and shareholders' equity Current liabilities $ 75,441 $ 289,930 $ — $ — $ 365,371 Long-term debt 1,446,535 — — — 1,446,535 Other long-term liabilities 271 34,715 — — 34,986 Payable to parent — 2,058,683 — (2,058,683 ) — Total shareholders' equity 510,004 (367,737 ) 55,985 311,752 510,004 Total liabilities and shareholders' equity $ 2,032,251 $ 2,015,591 $ 55,985 $ (1,746,931 ) $ 2,356,896
Schedule Of Condensed Consolidating Statement Of Operations	EXCO RESOURCES, INC. CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS (Unaudited) For the three months ended June 30, 2015 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Revenues: Oil and natural gas $ (18 ) $ 93,760 $ — $ — $ 93,742 Costs and expenses: Oil and natural gas production (15 ) 19,753 — — 19,738 Gathering and transportation — 24,785 — — 24,785 Depletion, depreciation and amortization 245 61,413 — — 61,658 Impairment of oil and natural gas properties 1,551 392,776 — — 394,327 Accretion of discount on asset retirement obligations — 568 — — 568 General and administrative (3,503 ) 16,100 — — 12,597 Other operating items 1,916 (382 ) — — 1,534 Total costs and expenses 194 515,013 — — 515,207 Operating loss (212 ) (421,253 ) — — (421,465 ) Other income (expense): Interest expense, net (25,571 ) — — — (25,571 ) Loss on derivative financial instruments (6,631 ) — — — (6,631 ) Other income 39 8 — — 47 Equity loss — — (535 ) — (535 ) Net loss from consolidated subsidiaries (421,780 ) — — 421,780 — Total other income (expense) (453,943 ) 8 (535 ) 421,780 (32,690 ) Loss before income taxes (454,155 ) (421,245 ) (535 ) 421,780 (454,155 ) Income tax expense — — — — — Net loss $ (454,155 ) $ (421,245 ) $ (535 ) $ 421,780 $ (454,155 ) EXCO RESOURCES, INC. CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS (Unaudited) For the three months ended June 30, 2014 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Revenues: Oil and natural gas $ 306 $ 169,795 $ 12,865 $ — $ 182,966 Costs and expenses: Oil and natural gas production 76 18,196 4,919 — 23,191 Gathering and transportation — 24,899 1,139 — 26,038 Depletion, depreciation and amortization 727 61,840 4,686 — 67,253 Accretion of discount on asset retirement obligations 4 522 169 — 695 General and administrative 962 17,949 593 — 19,504 Other operating items (12 ) 2,977 8 — 2,973 Total costs and expenses 1,757 126,383 11,514 — 139,654 Operating income (loss) (1,451 ) 43,412 1,351 — 43,312 Other income (expense): Interest expense, net (25,301 ) — (667 ) — (25,968 ) Loss on derivative financial instruments (13,958 ) — (760 ) — (14,718 ) Other income 59 14 4 — 77 Equity loss — — (410 ) — (410 ) Net income from consolidated subsidiaries 42,944 — — (42,944 ) — Total other income (expense) 3,744 14 (1,833 ) (42,944 ) (41,019 ) Income (loss) before income taxes 2,293 43,426 (482 ) (42,944 ) 2,293 Income tax expense — — — — — Net income (loss) $ 2,293 $ 43,426 $ (482 ) $ (42,944 ) $ 2,293 EXCO RESOURCES, INC. CONDENSED CONSOLIDATING STATEMENT OF OPERATIONS (Unaudited) For the six months ended June 30, 2015 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Revenues: Oil and natural gas $ 4 $ 180,058 $ — $ — $ 180,062 Costs and expenses: Oil and natural gas production 23 39,517 — — 39,540 Gathering and transportation — 50,500 — — 50,500 Depletion, depreciation and amortization 524 123,623 — — 124,147 Impairment of oil and natural gas properties 6,891 663,763 — — 670,654 Accretion of discount on asset retirement obligations 4 1,120 — — 1,124 General and administrative (4,224 ) 32,058 — — 27,834 Other operating items 2,068 (722 ) — — 1,346 Total costs and expenses 5,286 909,859 — — 915,145 Operating loss (5,282 ) (729,801 ) — — (735,083 ) Other income (expense): Interest expense, net (53,061 ) — — — (53,061 ) Gain on derivative financial instruments 17,079 — — — 17,079 Other income 73 25 — — 98 Equity loss — — (1,300 ) — (1,300 ) Net loss from consolidated subsidiaries (731,076 ) — — 731,076 — Total other income (expense) (766,985 ) 25 (1,300 ) 731,076 (37,184 ) Loss before income taxes (772,267 ) (729,776 ) (1,300 ) 731,076 (772,267 ) Income tax expense — — — — — Net loss $ (772,267 ) $ (729,776 ) $ (1,300 ) $ 731,076 $ (772,267 )
Schedule Of Condensed Consolidating Statement Of Cash Flows	EXCO RESOURCES, INC. CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS (Unaudited) For the six months ended June 30, 2015 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating Activities: Net cash provided by operating activities $ 19,024 $ 89,180 $ — $ — $ 108,204 Investing Activities: Additions to oil and natural gas properties, gathering assets and equipment and property acquisitions (1,174 ) (211,034 ) — — (212,208 ) Proceeds from disposition of property and equipment 686 6,711 — — 7,397 Restricted cash — 6,989 — — 6,989 Net changes in advances to joint ventures — 5,756 — — 5,756 Equity method investments — (503 ) — — (503 ) Advances/investments with affiliates (124,371 ) 124,371 — — — Net cash used in investing activities (124,859 ) (67,710 ) — — (192,569 ) Financing Activities: Borrowings under credit agreements 90,000 — — — 90,000 Payments for issuance of common shares, net (2 ) — — — (2 ) Payments of common share dividends (15 ) — — — (15 ) Deferred financing costs and other (2,016 ) — — — (2,016 ) Net cash provided by financing activities 87,967 — — — 87,967 Net increase (decrease) in cash (17,868 ) 21,470 — — 3,602 Cash at beginning of period 86,837 (40,532 ) — — 46,305 Cash at end of period $ 68,969 $ (19,062 ) $ — $ — $ 49,907 EXCO RESOURCES, INC. CONDENSED CONSOLIDATING STATEMENT OF CASH FLOWS (Unaudited) For the six months ended June 30, 2014 (in thousands) Resources Guarantor Subsidiaries Non-Guarantor Subsidiaries Eliminations Consolidated Operating Activities: Net cash provided by (used in) operating activities $ (54,003 ) $ 310,651 $ 11,474 $ — $ 268,122 Investing Activities: Additions to oil and natural gas properties, gathering assets and equipment and property acquisitions (1,639 ) (193,606 ) (2,522 ) — (197,767 ) Proceeds from disposition of property and equipment 68,242 8,017 7 — 76,266 Restricted cash — 5,349 — — 5,349 Net changes in advances to joint ventures — (10,540 ) — — (10,540 ) Equity method investments — 1,749 — — 1,749 Distributions received from Compass 3,311 — — (3,311 ) — Advances/investments with affiliates 107,240 (107,240 ) — — — Net cash provided by (used) in investing activities 177,154 (296,271 ) (2,515 ) (3,311 ) (124,943 ) Financing Activities: Repayments under credit agreements (879,874 ) — (2,550 ) — (882,424 ) Proceeds received from issuance of 2022 Notes 500,000 — — — 500,000 Proceeds from issuance of common shares, net 271,772 — — — 271,772 Payments of common share dividends (27,066 ) — — — (27,066 ) Compass cash distribution — — (3,311 ) 3,311 — Deferred financing costs and other (10,066 ) — — — (10,066 ) Net cash provided by (used in) financing activities (145,234 ) — (5,861 ) 3,311 (147,784 ) Net increase in cash (22,083 ) 14,380 3,098 — (4,605 ) Cash at beginning of period 81,840 (35,892 ) 4,535 — 50,483 Cash at end of period $ 59,757 $ (21,512 ) $ 7,633 $ — $ 45,878

Organization And Basis Of Pre30

Organization And Basis Of Presentation (Narrative) (Details) - Jun. 30, 2015	Total
OPCO [Member]
Working interest in equity investment	0.50%
Percentage of ownership interest	50.00%
East Texas/North Louisiana JV [Member]
Ownership percentage in joint venture	50.00%
Appalachia JV [Member]
Ownership percentage in joint venture	50.00%
Proportional working interest	49.75%

Acquisitions (Details)

Acquisitions (Details) - Participation Agreement [Member] $ in Millions	Mar. 11, 2015USD ($)wells	Jul. 31, 2015USD ($)wells	Sep. 30, 2015wells	Jun. 30, 2015
Business Acquisition [Line Items]
Period of Production, Productive Wells, Threshold to Offer Purchase				1 year
Number of Productive Wells Acquired, Gross	3
Number of Productive Wells Acquired, Net	1.4
Business Combination, Consideration Transferred | $	$ 7.6
Business Acquisition, Optional Ownership Percentage Retained				15.00%
Scenario, Forecast [Member]
Business Acquisition [Line Items]
Number of Productive Wells Offered, Gross			26
Number of Productive Wells Offered, Net			13.6
Subsequent Event [Member]
Business Acquisition [Line Items]
Number of Productive Wells Offered, Gross		10
Number of Productive Wells Offered, Net		5.2
Business Combination, Consideration Offered | $		$ 16.3

Asset Retirement Obligations (S

Asset Retirement Obligations (Schedule of Reconciliation of Asset Retirement Obligations) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligations at beginning of period			$ 36,755
Liabilities incurred during the period			693
Liabilities settled during the period			(65)
Adjustment to liability due to acquisitions			43
Adjustment to liability due to divestitures			(279)
Accretion of discount	$ 568	$ 695	1,124	$ 1,376
Asset retirement obligations at end of period	38,271		38,271
Less current portion	1,769		1,769		$ 1,769
Long-term portion	$ 36,502		$ 36,502		$ 34,986

Oil and Natural Gas Propertie33

Oil and Natural Gas Properties (Narrative) (Details)	3 Months Ended			6 Months Ended		12 Months Ended
	Jun. 30, 2015USD ($)	Mar. 31, 2015$ / bbl$ / MMBTU	Jun. 30, 2014USD ($)	Jun. 30, 2015USD ($)$ / bbl$ / MMBTU	Jun. 30, 2014USD ($)	Dec. 31, 2014$ / bbl$ / MMBTU
Oil and Gas Property [Abstract]
Impairment of unproved costs to proved properties				$ 0	$ 0
Full cost ceiling limitation discount rate				10.00%
Reference prices per mmbtu of natural gas | $ / MMBTU		3.88		3.39		4.35
Reference Prices Per Bbl Of Oil | $ / bbl		82.72		71.68		94.99
Impairment of oil and natural gas properties	$ 394,327,000		$ 0	$ 670,654,000	$ 0

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Net income (loss)	$ (454,155)	$ 2,293	$ (772,267)	$ (2,313)
Weighted average common shares outstanding	271,549	270,492	271,536	265,631
Net income (loss) per basic common share	$ (1.67)	$ 0.01	$ (2.84)	$ (0.01)
Weighted average common and common equivalent shares outstanding	271,549	271,226	271,536	265,631
Net income (loss) per diluted common share	$ (1.67)	$ 0.01	$ (2.84)	$ (0.01)
Stock Options [Member]
Dilutive effect of stock equivalents	0	0	0	0
Restricted Stock [Member]
Dilutive effect of stock equivalents	0	734	0	0

Earnings Per Share Earnings Per

Earnings Per Share Earnings Per Share (Details Textual) - shares	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Earnings Per Share [Abstract]
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount	12,152,822	12,855,434	12,657,675	13,853,885

Derivative Financial Instrume36

Derivative Financial Instruments (Narrative) (Details) bbl in Thousands, MMBTU in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015MMBTU$ / MMBTU$ / bblbbl	Jun. 30, 2014	Jun. 30, 2015MMBTU$ / MMBTU$ / bblbbl	Jun. 30, 2014	Dec. 31, 2014MMBTUbbl
Derivative [Line Items]
Percentage Of Derivative Instruments To Equivalent Production	65.00%	67.00%	65.00%	67.00%
2015 [Member] | Natural Gas [Member]
Derivative [Line Items]
Derivative, Average Forward Price | $ / MMBTU	2.93		2.93
2016 [Member] | Natural Gas [Member]
Derivative [Line Items]
Derivative, Average Forward Price | $ / MMBTU	3.17		3.17
2017 [Member] | Natural Gas [Member]
Derivative [Line Items]
Derivative, Average Forward Price | $ / MMBTU	3.36		3.36
NYMEX WTI [Member] | 2015 [Member] | Oil [Member]
Derivative [Line Items]
Derivative, Average Forward Price | $ / bbl	60.12		60.12
NYMEX WTI [Member] | 2016 [Member] | Oil [Member]
Derivative [Line Items]
Derivative, Average Forward Price | $ / bbl	61.90		61.90
NYMEX LLS [Member] | 2015 [Member] | Oil [Member]
Derivative [Line Items]
Derivative, Average Forward Price | $ / bbl	62.88		62.88
NYMEX LLS [Member] | 2016 [Member] | Oil [Member]
Derivative [Line Items]
Derivative, Average Forward Price | $ / bbl	64.51		64.51
Swap [Member] | Oil [Member]
Derivative [Line Items]
Investment Contract Volume | bbl					1,095
Swap [Member] | Natural Gas [Member]
Derivative [Line Items]
Natural gas volume					42,888
Swap [Member] | 2015 [Member] | Oil [Member]
Derivative [Line Items]
Investment Contract Volume | bbl	644		644
Swap [Member] | 2015 [Member] | Natural Gas [Member]
Derivative [Line Items]
Natural gas volume	25,300		25,300
Swap [Member] | 2016 [Member] | Oil [Member]
Derivative [Line Items]
Investment Contract Volume | bbl	732		732
Swap [Member] | 2016 [Member] | Natural Gas [Member]
Derivative [Line Items]
Natural gas volume	16,470		16,470
Swap [Member] | 2017 [Member] | Natural Gas [Member]
Derivative [Line Items]
Natural gas volume	7,300		7,300
Call Option [Member] | Oil [Member]
Derivative [Line Items]
Investment Contract Volume | bbl					365
Call Option [Member] | Natural Gas [Member]
Derivative [Line Items]
Natural gas volume					20,075
Call Option [Member] | 2015 [Member] | Oil [Member]
Derivative [Line Items]
Investment Contract Volume | bbl	184		184
Call Option [Member] | 2015 [Member] | Natural Gas [Member]
Derivative [Line Items]
Natural gas volume	10,120		10,120
Three Way Collars [Member] | Natural Gas [Member]
Derivative [Line Items]
Natural gas volume					38,355
Three Way Collars [Member] | 2015 [Member] | Natural Gas [Member]
Derivative [Line Items]
Natural gas volume	13,800		13,800
Three Way Collars [Member] | 2016 [Member] | Natural Gas [Member]
Derivative [Line Items]
Natural gas volume	10,980		10,980
Basis Swap [Member] | Oil [Member]
Derivative [Line Items]
Investment Contract Volume | bbl					91
Basis Swap [Member] | 2015 [Member] | Oil [Member]
Derivative [Line Items]
Investment Contract Volume | bbl	46		46

Derivative Financial Instrume37

Derivative Financial Instruments (Fair Value Of Derivative Financial Instruments) (Details) - Derivative Contract [Domain] - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Derivative financial instruments - Current assets	$ 55,111	$ 97,278
Derivative financial instruments - Long-term assets	3,772	2,138
Derivative financial instruments - Current liabilities	(320)	(892)
Derivative financial instruments - Long-term liabilities	0	0
Net derivative financial instruments	$ 58,563	$ 98,524

Derivative Financial Instrume38

Derivative Financial Instruments (Effect Of Derivative Financial Instruments) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
General Discussion of Derivative Instruments and Hedging Activities [Abstract]
Gain (Loss) on derivative financial instruments	$ (6,631)	$ (14,718)	$ 17,079	$ (57,740)

Derivative Financial Instrume39

Derivative Financial Instruments (Fair Value Of Oil And Natural Gas Derivative Financial Instruments) (Details) bbl in Thousands, MMBTU in Thousands, $ in Thousands	Jun. 30, 2015USD ($)MMBTU$ / MMBTU$ / bblbbl	Dec. 31, 2014USD ($)MMBTUbbl
Derivatives, Fair Value [Line Items]
Fair Value of Derivative Financial Instruments	$ 58,563	$ 98,524
Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Fair Value of Derivative Financial Instruments	40,051
Oil [Member]
Derivatives, Fair Value [Line Items]
Fair Value of Derivative Financial Instruments	$ 18,512
Swap [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Natural Gas Mmbtu | MMBTU		42,888
Swap [Member] | Oil [Member]
Derivatives, Fair Value [Line Items]
Volume (oil) | bbl		1,095
Swap [Member] | 2015 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Natural Gas Mmbtu | MMBTU	25,300
Weighted average strike price per Mmbtu/Bbl | $ / MMBTU	4.02
Fair Value of Derivative Financial Instruments	$ 28,102
Swap [Member] | 2015 [Member] | Oil [Member]
Derivatives, Fair Value [Line Items]
Volume (oil) | bbl	644
Weighted average strike price per Mmbtu/Bbl | $ / bbl	86.44
Fair Value of Derivative Financial Instruments	$ 16,371
Swap [Member] | 2016 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Natural Gas Mmbtu | MMBTU	16,470
Weighted average strike price per Mmbtu/Bbl | $ / MMBTU	3.30
Fair Value of Derivative Financial Instruments	$ 2,046
Swap [Member] | 2016 [Member] | Oil [Member]
Derivatives, Fair Value [Line Items]
Volume (oil) | bbl	732
Weighted average strike price per Mmbtu/Bbl | $ / bbl	64.82
Fair Value of Derivative Financial Instruments	$ 1,986
Swap [Member] | 2017 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Natural Gas Mmbtu | MMBTU	7,300
Weighted average strike price per Mmbtu/Bbl | $ / MMBTU	3.42
Fair Value of Derivative Financial Instruments	$ 409
Call Option [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Natural Gas Mmbtu | MMBTU		20,075
Call Option [Member] | Oil [Member]
Derivatives, Fair Value [Line Items]
Volume (oil) | bbl		365
Call Option [Member] | 2015 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Natural Gas Mmbtu | MMBTU	10,120
Weighted average strike price per Mmbtu/Bbl | $ / MMBTU	4.29
Fair Value of Derivative Financial Instruments	$ (150)
Call Option [Member] | 2015 [Member] | Oil [Member]
Derivatives, Fair Value [Line Items]
Volume (oil) | bbl	184
Weighted average strike price per Mmbtu/Bbl | $ / bbl	100
Fair Value of Derivative Financial Instruments	$ (3)
Three Way Collars [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Natural Gas Mmbtu | MMBTU		38,355
Three Way Collars [Member] | 2015 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Natural Gas Mmbtu | MMBTU	13,800
Fair Value of Derivative Financial Instruments	$ 6,029
Three Way Collars [Member] | 2016 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Natural Gas Mmbtu | MMBTU	10,980
Fair Value of Derivative Financial Instruments	$ 3,615
Three Way Collars [Member] | Short [Member] | Call Option [Member] | 2015 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Weighted average strike price per Mmbtu/Bbl | $ / MMBTU	4.47
Three Way Collars [Member] | Short [Member] | Call Option [Member] | 2016 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Weighted average strike price per Mmbtu/Bbl | $ / MMBTU	4.80
Three Way Collars [Member] | Short [Member] | Put Option [Member] | 2015 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Weighted average strike price per Mmbtu/Bbl | $ / MMBTU	3.33
Three Way Collars [Member] | Short [Member] | Put Option [Member] | 2016 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Weighted average strike price per Mmbtu/Bbl | $ / MMBTU	3.40
Three Way Collars [Member] | Long [Member] | Put Option [Member] | 2015 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Weighted average strike price per Mmbtu/Bbl | $ / MMBTU	3.83
Three Way Collars [Member] | Long [Member] | Put Option [Member] | 2016 [Member] | Natural Gas [Member]
Derivatives, Fair Value [Line Items]
Weighted average strike price per Mmbtu/Bbl | $ / MMBTU	3.90
Basis Swap [Member] | Oil [Member]
Derivatives, Fair Value [Line Items]
Volume (oil) | bbl		91
Basis Swap [Member] | 2015 [Member] | Oil [Member]
Derivatives, Fair Value [Line Items]
Volume (oil) | bbl	46
Weighted average strike price per Mmbtu/Bbl | $ / bbl	6.10
Fair Value of Derivative Financial Instruments	$ 158

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Details)	Jun. 30, 2015
Senior Unsecured Notes due 2018 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate	7.50%
Senior Unsecured Notes due 2022 [Member]
Debt Instrument [Line Items]
Debt instrument, interest rate	8.50%

Fair Value Measurements (Summar

Fair Value Measurements (Summary Of Estimated Fair Value Of Derivative Financial Instruments) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value of Derivative Financial Instruments	$ 58,563	$ 98,524
Level 1 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value of Derivative Financial Instruments	0	0
Level 2 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value of Derivative Financial Instruments	58,563	98,524
Level 3 [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair Value of Derivative Financial Instruments	$ 0	$ 0

Fair Value Measurements (Schedu

Fair Value Measurements (Schedule Of Estimated Fair Value Of Other Financial Instruments) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Senior Unsecured Notes due 2018 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	$ 476,250	$ 558,750
Senior Unsecured Notes due 2018 [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	476,250	558,750
Senior Unsecured Notes due 2018 [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	0	0
Senior Unsecured Notes due 2018 [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	0	0
Senior Unsecured Notes due 2022 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	255,310	373,500
Senior Unsecured Notes due 2022 [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	255,310	373,500
Senior Unsecured Notes due 2022 [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	0	0
Senior Unsecured Notes due 2022 [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Debt Instrument, Fair Value Disclosure	$ 0	$ 0

Debt (Narrative) (Details)

Debt (Narrative) (Details)	3 Months Ended				6 Months Ended			9 Months Ended
	Mar. 31, 2018	Dec. 31, 2017	Sep. 30, 2017	Dec. 31, 2016	Jun. 30, 2017	Mar. 31, 2017	Jun. 30, 2015USD ($)	Jun. 30, 2017	Jul. 27, 2015USD ($)	Dec. 31, 2014USD ($)
Senior Unsecured Notes due 2018 [Member]
Debt Instrument [Line Items]
Debt instrument, principal outstanding							$ 750,000,000			$ 750,000,000
Debt instrument, interest rate							7.50%
Unamortized discount							$ 5,249,000			5,957,000
Senior Unsecured Notes due 2022 [Member]
Debt Instrument [Line Items]
Debt instrument, principal outstanding							$ 500,000,000			500,000,000
Debt instrument, interest rate							8.50%
Debt Instrument, Issued Price, Percentage							100.00%
Revolving Credit Facility [Member] | EXCO Resources Credit Agreement [Member]
Debt Instrument [Line Items]
Outstanding indebtedness							$ 292,492,000			$ 202,492,000
Borrowing base							725,000,000
Unused borrowing base							$ 425,900,000
Line of credit facility, maturity date							Jul. 31, 2018
LIBOR rate to compute the variable rate on the debt instrument							0.20%
Line of Credit Facility, Interest Rate at Period End							2.20%
Current ratio, numerator							1
Current ratio, denominator							1
Debt Instrument, Covenant, Minimum Ratio of Consolidated EBITDAX to Consolidated Interest Expense							2
Debt Instrument, Covenant, Maximum Ratio of Senior Secured Indebtedness to Consolidated EBITDAX							2.5
Revolving Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Minimum [Member] | EXCO Resources Credit Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate							1.75%
Revolving Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member] | Maximum [Member] | EXCO Resources Credit Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate							2.75%
Revolving Credit Facility [Member] | Alternate Base Rate (ABR) [Member] | Minimum [Member] | EXCO Resources Credit Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate							0.75%
Revolving Credit Facility [Member] | Alternate Base Rate (ABR) [Member] | Maximum [Member] | EXCO Resources Credit Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Basis Spread on Variable Rate							1.75%
Scenario, Forecast [Member] | Revolving Credit Facility [Member] | EXCO Resources Credit Agreement [Member]
Debt Instrument [Line Items]
Debt Instrument, Covenant, Maximum Ratio of Consolidated Funded Indebtedness to Consolidated EBITDAX	4.50	4.75	5.25	6	5.75
Debt Instrument, Covenant, Maximum Ratio of Consolidated Funded Indebtedness to Consolidated EBITDAX, Multiplier to Use When calculating EBITDAX for the Period				4		2		1.3
Subsequent Event [Member] | Revolving Credit Facility [Member] | EXCO Resources Credit Agreement [Member]
Debt Instrument [Line Items]
Borrowing base									$ 600,000,000
Indebtedness threshold, reduction in borrowing base									33.00%
Minimum borrowing base									$ 362,500,000
Indebtedness threshold, increase in interest rate									0.005
Indebtedness threshold									$ 300,000,000
Debt Instrument, Covenant, Minimum Ratio of Consolidated EBITDAX to Consolidated Interest Expense									1.25

Debt (Schedule Of Long-Term Deb

Debt (Schedule Of Long-Term Debt) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Total Debt	$ 1,537,243	$ 1,446,535
Senior Unsecured Notes due 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument	750,000	750,000
Unamortized discount	(5,249)	(5,957)
Senior Unsecured Notes due 2022 [Member]
Debt Instrument [Line Items]
Debt Instrument	500,000	500,000
Revolving Credit Facility [Member] | EXCO Resources Credit Agreement [Member]
Debt Instrument [Line Items]
Revolving credit facility under credit agreement	$ 292,492	$ 202,492

Income Taxes (Details)

Income Taxes (Details) - Jun. 30, 2015 - USD ($) $ in Millions	Total
Income Tax Disclosure [Abstract]
Change in valuation allowance	$ 299.3
Recognized net valuation allowance	$ 1,100

Related Party Transactions (Det

Related Party Transactions (Details) - OPCO [Member] - USD ($) $ in Thousands		3 Months Ended		6 Months Ended
		Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Advances to OPCP		$ 0	$ 0	$ 0	$ 0
Amounts received from OPCO		8,273	$ 11,259	16,566	$ 20,971
Amounts due to EXCO	[1]	2,447		2,447		$ 2,799
Amounts due from EXCO	[1]	$ 5,502		$ 5,502		$ 0
[1]	Advances to OPCO are recorded in "Other current assets" on our Condensed Consolidated Balance Sheets. Any amounts we owe to OPCO are netted against the advance until the advances are utilized. If the advances are fully utilized, we record amounts owed in "Accounts payable and accrued liabilities" on our Condensed Consolidated Balance Sheets.

Services and Investment Agree47

Services and Investment Agreement (Narrative) (Details) - USD ($)	Mar. 31, 2015	Aug. 05, 2015	Jun. 30, 2015	Dec. 31, 2014
Services and Investment Agreement [Line Items]
Common stock, par value			$ 0.001	$ 0.001
Common stock, authorized shares			350,000,000	350,000,000
Scenario, Forecast [Member]
Services and Investment Agreement [Line Items]
Common stock, authorized shares		780,000,000
Energy Strategic Advisory Services LLC (ESAS) [Member]
Services and Investment Agreement [Line Items]
Services and Investment Agreement, Escrow Deposit for Shares			$ 10,000,000
Services and Investment Agreement, Share Purchase Obligation, Due in 12 Months After Closing			40,000,000
Services and Investment Agreement, Share Purchase Obligation, Total			$ 50,000,000
Energy Strategic Advisory Services LLC (ESAS) [Member]
Services and Investment Agreement [Line Items]
Services and Investment Agreement, Term	4 years
Services and Investment Agreement, Shares Agreed to Purchase			5,882,353
Services and Investment Agreement, Price Per Share			$ 1.70
Services and Investment Agreement, Monthly Fee			$ 300,000
Services and Investment Agreement, Annual Incentive Payment			$ 2,400,000
Number of shares issuable			80,000,000
Energy Strategic Advisory Services LLC (ESAS) [Member] | Bottom Half of Peer Group [Member]
Services and Investment Agreement [Line Items]
Services and Investment Agreement, Annual Incentive Payment			$ 0
Energy Strategic Advisory Services LLC (ESAS) [Member] | 50th to 74th Percentile of Peer Group [Member]
Services and Investment Agreement [Line Items]
Services and Investment Agreement, Annual Incentive Payment			$ 1,000,000
Number of shares issuable			32,000,000
Energy Strategic Advisory Services LLC (ESAS) [Member] | 75th Percentile or Above of Peer Group [Member]
Services and Investment Agreement [Line Items]
Services and Investment Agreement, Annual Incentive Payment			$ 2,400,000
Number of shares issuable			80,000,000

Services and Investment Agree48

Services and Investment Agreement (Warrants) (Details) - $ / shares	Mar. 31, 2015	Jun. 30, 2015
Tranche One [Member]
Class of Warrant or Right [Line Items]
Number of shares issuable		15,000,000
Exercise Price		$ 2.75
Term (in months)	49 months
Tranche Two [Member]
Class of Warrant or Right [Line Items]
Number of shares issuable		20,000,000
Exercise Price		$ 4
Term (in months)	60 months
Tranche Three [Member]
Class of Warrant or Right [Line Items]
Number of shares issuable		20,000,000
Exercise Price		$ 7
Term (in months)	72 months
Tranche Four [Member]
Class of Warrant or Right [Line Items]
Number of shares issuable		25,000,000
Exercise Price		$ 10
Term (in months)	72 months

Condensed Consolidating Finan49

Condensed Consolidating Financial Statements (Schedule Of Condensed Consolidating Balance Sheet) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014	Jun. 30, 2014	Dec. 31, 2013
Current assets:
Cash and cash equivalents	$ 49,907	$ 46,305	$ 45,878	$ 50,483
Restricted cash	17,581	23,970
Other current assets	166,844	260,491
Total current assets	234,332	330,766
Equity investments	55,188	55,985
Unproved oil and natural gas properties and development costs not being amortized	248,196	276,025
Proved developed and undeveloped oil and natural gas properties	3,385,948	3,852,073
Accumulated depletion	(2,537,476)	(2,414,461)
Oil and natural gas properties, net	1,096,668	1,713,637
Other property and equipment, net	23,937	24,644
Investments in and advances to affiliates, net	0	0
Deferred financing costs, net	26,385	30,636
Derivative financial instruments	3,772	2,138
Goodwill	163,155	163,155
Deferred income taxes	18,669	35,935
Total assets	1,622,106	2,356,896
Liabilities and shareholders’ equity
Current liabilities	305,782	365,371
Long-term debt	1,537,243	1,446,535
Other long-term liabilities	36,502	34,986
Payable to parent	0	0
Total shareholders' equity	(257,421)	510,004	396,582	147,905
Total liabilities and shareholders' equity	1,622,106	2,356,896
Resources [Member]
Current assets:
Cash and cash equivalents	68,969	86,837	59,757	81,840
Restricted cash	600	0
Other current assets	65,397	110,145
Total current assets	134,966	196,982
Equity investments	0	0
Unproved oil and natural gas properties and development costs not being amortized	0	0
Proved developed and undeveloped oil and natural gas properties	330,776	335,838
Accumulated depletion	(330,776)	(330,771)
Oil and natural gas properties, net	0	5,067
Other property and equipment, net	905	1,269
Investments in and advances to affiliates, net	1,140,229	1,746,931
Deferred financing costs, net	26,385	30,636
Derivative financial instruments	3,772	2,138
Goodwill	13,293	13,293
Deferred income taxes	18,669	35,935
Total assets	1,338,219	2,032,251
Liabilities and shareholders’ equity
Current liabilities	58,397	75,441
Long-term debt	1,537,243	1,446,535
Other long-term liabilities	0	271
Payable to parent	0	0
Total shareholders' equity	(257,421)	510,004
Total liabilities and shareholders' equity	1,338,219	2,032,251
Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	(19,062)	(40,532)	(21,512)	(35,892)
Restricted cash	16,981	23,970
Other current assets	101,447	150,346
Total current assets	99,366	133,784
Equity investments	0	0
Unproved oil and natural gas properties and development costs not being amortized	248,196	276,025
Proved developed and undeveloped oil and natural gas properties	3,055,172	3,516,235
Accumulated depletion	(2,206,700)	(2,083,690)
Oil and natural gas properties, net	1,096,668	1,708,570
Other property and equipment, net	23,032	23,375
Investments in and advances to affiliates, net	0	0
Deferred financing costs, net	0	0
Derivative financial instruments	0	0
Goodwill	149,862	149,862
Deferred income taxes	0	0
Total assets	1,368,928	2,015,591
Liabilities and shareholders’ equity
Current liabilities	247,385	289,930
Long-term debt	0	0
Other long-term liabilities	36,502	34,715
Payable to parent	2,183,057	2,058,683
Total shareholders' equity	(1,098,016)	(367,737)
Total liabilities and shareholders' equity	1,368,928	2,015,591
Non-Guarantor Subsidiaries [Member]
Current assets:
Cash and cash equivalents	0	0	7,633	4,535
Restricted cash	0	0
Other current assets	0	0
Total current assets	0	0
Equity investments	55,188	55,985
Unproved oil and natural gas properties and development costs not being amortized	0	0
Proved developed and undeveloped oil and natural gas properties	0	0
Accumulated depletion	0	0
Oil and natural gas properties, net	0	0
Other property and equipment, net	0	0
Investments in and advances to affiliates, net	0	0
Deferred financing costs, net	0	0
Derivative financial instruments	0	0
Goodwill	0	0
Deferred income taxes	0	0
Total assets	55,188	55,985
Liabilities and shareholders’ equity
Current liabilities	0	0
Long-term debt	0	0
Other long-term liabilities	0	0
Payable to parent	0	0
Total shareholders' equity	55,188	55,985
Total liabilities and shareholders' equity	55,188	55,985
Eliminations [Member]
Current assets:
Cash and cash equivalents	0	0	$ 0	$ 0
Restricted cash	0	0
Other current assets	0	0
Total current assets	0	0
Equity investments	0	0
Unproved oil and natural gas properties and development costs not being amortized	0	0
Proved developed and undeveloped oil and natural gas properties	0	0
Accumulated depletion	0	0
Oil and natural gas properties, net	0	0
Other property and equipment, net	0	0
Investments in and advances to affiliates, net	(1,140,229)	(1,746,931)
Deferred financing costs, net	0	0
Derivative financial instruments	0	0
Goodwill	0	0
Deferred income taxes	0	0
Total assets	(1,140,229)	(1,746,931)
Liabilities and shareholders’ equity
Current liabilities	0	0
Long-term debt	0	0
Other long-term liabilities	0	0
Payable to parent	(2,183,057)	(2,058,683)
Total shareholders' equity	1,042,828	311,752
Total liabilities and shareholders' equity	$ (1,140,229)	$ (1,746,931)

Condensed Consolidating Finan50

Condensed Consolidating Financial Statements (Schedule Of Condensed Consolidating Statement Of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Oil and natural gas	$ 93,742	$ 182,966	$ 180,062	$ 381,438
Oil and natural gas production	19,738	23,191	39,540	49,587
Gathering and transportation	24,785	26,038	50,500	50,651
Depletion, depreciation and amortization	61,658	67,253	124,147	136,528
Impairment of oil and natural gas properties	394,327	0	670,654	0
Accretion of discount on asset retirement obligations	568	695	1,124	1,376
General and administrative	12,597	19,504	27,834	36,842
Other operating items	1,534	2,973	1,346	5,719
Total costs and expenses	515,207	139,654	915,145	280,703
Operating income (loss)	(421,465)	43,312	(735,083)	100,735
Interest expense, net	(25,571)	(25,968)	(53,061)	(46,132)
Gain (loss) on derivative financial instruments	(6,631)	(14,718)	17,079	(57,740)
Other income (loss)	47	77	98	123
Equity income (loss)	(535)	(410)	(1,300)	701
Net earnings (loss) from consolidated subsidiaries	0	0	0	0
Total other income (expense)	(32,690)	(41,019)	(37,184)	(103,048)
Income (loss) before income taxes	(454,155)	2,293	(772,267)	(2,313)
Income tax expense	0	0	0	0
Net income (loss)	(454,155)	2,293	(772,267)	(2,313)
Resources [Member]
Oil and natural gas	(18)	306	4	3,296
Oil and natural gas production	(15)	76	23	375
Gathering and transportation	0	0	0	0
Depletion, depreciation and amortization	245	727	524	1,884
Impairment of oil and natural gas properties	1,551	0	6,891	0
Accretion of discount on asset retirement obligations	0	4	4	9
General and administrative	(3,503)	962	(4,224)	727
Other operating items	1,916	(12)	2,068	(16)
Total costs and expenses	194	1,757	5,286	2,979
Operating income (loss)	(212)	(1,451)	(5,282)	317
Interest expense, net	(25,571)	(25,301)	(53,061)	(44,796)
Gain (loss) on derivative financial instruments	(6,631)	(13,958)	17,079	(54,637)
Other income (loss)	39	59	73	152
Equity income (loss)	0	0	0	0
Net earnings (loss) from consolidated subsidiaries	(421,780)	42,944	(731,076)	96,651
Total other income (expense)	(453,943)	3,744	(766,985)	(2,630)
Income (loss) before income taxes	(454,155)	2,293	(772,267)	(2,313)
Income tax expense	0	0	0	0
Net income (loss)	(454,155)	2,293	(772,267)	(2,313)
Guarantor Subsidiaries [Member]
Oil and natural gas	93,760	169,795	180,058	351,856
Oil and natural gas production	19,753	18,196	39,517	39,617
Gathering and transportation	24,785	24,899	50,500	48,348
Depletion, depreciation and amortization	61,413	61,840	123,623	125,507
Impairment of oil and natural gas properties	392,776	0	663,763	0
Accretion of discount on asset retirement obligations	568	522	1,120	1,032
General and administrative	16,100	17,949	32,058	34,795
Other operating items	(382)	2,977	(722)	5,731
Total costs and expenses	515,013	126,383	909,859	255,030
Operating income (loss)	(421,253)	43,412	(729,801)	96,826
Interest expense, net	0	0	0	0
Gain (loss) on derivative financial instruments	0	0	0	0
Other income (loss)	8	14	25	(37)
Equity income (loss)	0	0	0	0
Net earnings (loss) from consolidated subsidiaries	0	0	0	0
Total other income (expense)	8	14	25	(37)
Income (loss) before income taxes	(421,245)	43,426	(729,776)	96,789
Income tax expense	0	0	0	0
Net income (loss)	(421,245)	43,426	(729,776)	96,789
Non-Guarantor Subsidiaries [Member]
Oil and natural gas	0	12,865	0	26,286
Oil and natural gas production	0	4,919	0	9,595
Gathering and transportation	0	1,139	0	2,303
Depletion, depreciation and amortization	0	4,686	0	9,137
Impairment of oil and natural gas properties	0	0	0	0
Accretion of discount on asset retirement obligations	0	169	0	335
General and administrative	0	593	0	1,320
Other operating items	0	8	0	4
Total costs and expenses	0	11,514	0	22,694
Operating income (loss)	0	1,351	0	3,592
Interest expense, net	0	(667)	0	(1,336)
Gain (loss) on derivative financial instruments	0	(760)	0	(3,103)
Other income (loss)	0	4	0	8
Equity income (loss)	(535)	(410)	(1,300)	701
Net earnings (loss) from consolidated subsidiaries	0	0	0	0
Total other income (expense)	(535)	(1,833)	(1,300)	(3,730)
Income (loss) before income taxes	(535)	(482)	(1,300)	(138)
Income tax expense	0	0	0	0
Net income (loss)	(535)	(482)	(1,300)	(138)
Eliminations [Member]
Oil and natural gas	0	0	0	0
Oil and natural gas production	0	0	0	0
Gathering and transportation	0	0	0	0
Depletion, depreciation and amortization	0	0	0	0
Impairment of oil and natural gas properties	0	0	0	0
Accretion of discount on asset retirement obligations	0	0	0	0
General and administrative	0	0	0	0
Other operating items	0	0	0	0
Total costs and expenses	0	0	0	0
Operating income (loss)	0	0	0	0
Interest expense, net	0	0	0	0
Gain (loss) on derivative financial instruments	0	0	0	0
Other income (loss)	0	0	0	0
Equity income (loss)	0	0	0	0
Net earnings (loss) from consolidated subsidiaries	421,780	(42,944)	731,076	(96,651)
Total other income (expense)	421,780	(42,944)	731,076	(96,651)
Income (loss) before income taxes	421,780	(42,944)	731,076	(96,651)
Income tax expense	0	0	0	0
Net income (loss)	$ 421,780	$ (42,944)	$ 731,076	$ (96,651)

Condensed Consolidating Finan51

Condensed Consolidating Financial Statements (Schedule Of Condensed Consolidating Statement Of Cash Flows) (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
Net cash provided by (used in) operating activities	$ 108,204	$ 268,122
Additions to oil and natural gas properties, gathering assets and equipment and property acquisitions	(212,208)	(197,767)
Proceeds from disposition of property and equipment	7,397	76,266
Restricted cash	6,989	5,349
Net changes in advances to joint ventures	5,756	(10,540)
Equity method investments	(503)	1,749
Distributions received from Compass		0
Advances/investments with affiliates	0	0
Net cash provided by (used in) investing activities	(192,569)	(124,943)
Borrowings under credit agreements	90,000	0
Repayments under credit agreements	0	(882,424)
Proceeds received from issuance of 2022 Notes	0	500,000
Proceeds (payments) for issuance of common shares, net	(2)	271,772
Payments of common share dividends	(15)	(27,066)
Compass cash distribution		0
Deferred financing costs and other	(2,016)	(10,066)
Net cash provided by (used in) financing activities	87,967	(147,784)
Net increase (decrease) in cash	3,602	(4,605)
Cash at beginning of period	46,305	50,483
Cash at end of period	49,907	45,878
Resources [Member]
Net cash provided by (used in) operating activities	19,024	(54,003)
Additions to oil and natural gas properties, gathering assets and equipment and property acquisitions	(1,174)	(1,639)
Proceeds from disposition of property and equipment	686	68,242
Restricted cash	0	0
Net changes in advances to joint ventures	0	0
Equity method investments	0	0
Distributions received from Compass		3,311
Advances/investments with affiliates	(124,371)	107,240
Net cash provided by (used in) investing activities	(124,859)	177,154
Borrowings under credit agreements	90,000
Repayments under credit agreements		(879,874)
Proceeds received from issuance of 2022 Notes		500,000
Proceeds (payments) for issuance of common shares, net	(2)	271,772
Payments of common share dividends	(15)	(27,066)
Compass cash distribution		0
Deferred financing costs and other	(2,016)	(10,066)
Net cash provided by (used in) financing activities	87,967	(145,234)
Net increase (decrease) in cash	(17,868)	(22,083)
Cash at beginning of period	86,837	81,840
Cash at end of period	68,969	59,757
Guarantor Subsidiaries [Member]
Net cash provided by (used in) operating activities	89,180	310,651
Additions to oil and natural gas properties, gathering assets and equipment and property acquisitions	(211,034)	(193,606)
Proceeds from disposition of property and equipment	6,711	8,017
Restricted cash	6,989	5,349
Net changes in advances to joint ventures	5,756	(10,540)
Equity method investments	(503)	1,749
Distributions received from Compass		0
Advances/investments with affiliates	124,371	(107,240)
Net cash provided by (used in) investing activities	(67,710)	(296,271)
Borrowings under credit agreements	0
Repayments under credit agreements		0
Proceeds received from issuance of 2022 Notes		0
Proceeds (payments) for issuance of common shares, net	0	0
Payments of common share dividends	0	0
Compass cash distribution		0
Deferred financing costs and other	0	0
Net cash provided by (used in) financing activities	0	0
Net increase (decrease) in cash	21,470	14,380
Cash at beginning of period	(40,532)	(35,892)
Cash at end of period	(19,062)	(21,512)
Non-Guarantor Subsidiaries [Member]
Net cash provided by (used in) operating activities	0	11,474
Additions to oil and natural gas properties, gathering assets and equipment and property acquisitions	0	(2,522)
Proceeds from disposition of property and equipment	0	7
Restricted cash	0	0
Net changes in advances to joint ventures	0	0
Equity method investments	0	0
Distributions received from Compass		0
Advances/investments with affiliates	0	0
Net cash provided by (used in) investing activities	0	(2,515)
Borrowings under credit agreements	0
Repayments under credit agreements		(2,550)
Proceeds received from issuance of 2022 Notes		0
Proceeds (payments) for issuance of common shares, net	0	0
Payments of common share dividends	0	0
Compass cash distribution		(3,311)
Deferred financing costs and other	0	0
Net cash provided by (used in) financing activities	0	(5,861)
Net increase (decrease) in cash	0	3,098
Cash at beginning of period	0	4,535
Cash at end of period	0	7,633
Eliminations [Member]
Net cash provided by (used in) operating activities	0	0
Additions to oil and natural gas properties, gathering assets and equipment and property acquisitions	0	0
Proceeds from disposition of property and equipment	0	0
Restricted cash	0	0
Net changes in advances to joint ventures	0	0
Equity method investments	0	0
Distributions received from Compass		(3,311)
Advances/investments with affiliates	0	0
Net cash provided by (used in) investing activities	0	(3,311)
Borrowings under credit agreements	0
Repayments under credit agreements		0
Proceeds received from issuance of 2022 Notes		0
Proceeds (payments) for issuance of common shares, net	0	0
Payments of common share dividends	0	0
Compass cash distribution		3,311
Deferred financing costs and other	0	0
Net cash provided by (used in) financing activities	0	3,311
Net increase (decrease) in cash	0	0
Cash at beginning of period	0	0
Cash at end of period	$ 0	$ 0