Gulfport Energy (GPOR) 10-Q 5 Aug 16 2016 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	6 Months Ended
	Jun. 30, 2016	Aug. 01, 2016
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2016
Entity Registrant Name	GULFPORT ENERGY CORP
Entity Central Index Key	874,499
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2,016
Entity Filer Category	Large Accelerated Filer
Document Fiscal Period Focus	Q2
Entity Common Stock, Shares Outstanding		125,367,167

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 396,437	$ 112,974
Accounts receivable—oil and gas	91,462	71,872
Accounts receivable—related parties	23	16
Prepaid expenses and other current assets	7,782	3,905
Short-term derivative instruments	44,672	142,794
Deferred tax asset	292	0
Total current assets	540,668	331,561
Property and equipment:
Oil and natural gas properties, full-cost accounting, $1,762,439 and $1,817,701 excluded from amortization in 2016 and 2015, respectively	5,686,188	5,424,342
Other property and equipment	48,107	33,171
Accumulated depletion, depreciation, amortization and impairment	(3,339,087)	(2,829,110)
Property and equipment, net	2,395,208	2,628,403
Other assets:
Equity investments	253,047	242,393
Long-term derivative instruments	14,644	51,088
Deferred tax asset	24,284	74,925
Other assets	11,336	6,364
Total other assets	303,311	374,770
Total assets	3,239,187	3,334,734
Current liabilities:
Accounts payable and accrued liabilities	289,750	265,128
Asset retirement obligation—current	75	75
Short-term derivative instruments	49,906	437
Deferred tax liability	0	50,697
Current maturities of long-term debt	0	179
Total current liabilities	339,731	316,516
Long-term derivative instrument	29,269	6,935
Asset retirement obligation—long-term	29,993	26,362
Long-term debt, net of current maturities	956,754	946,084
Total liabilities	1,355,747	1,295,897
Commitments and contingencies (Note 10)
Preferred stock, $.01 par value; 5,000,000 authorized, 30,000 authorized as redeemable 12% cumulative preferred stock, Series A; 0 issued and outstanding	0	0
Stockholders’ equity:
Common stock - $.01 par value, 200,000,000 authorized, 125,365,166 issued and outstanding at June 30, 2016 and 108,322,250 at December 31, 2015	1,253	1,082
Paid-in capital	3,242,404	2,824,303
Accumulated other comprehensive loss	(46,803)	(55,177)
Retained deficit	(1,313,414)	(731,371)
Total stockholders’ equity	1,883,440	2,038,837
Total liabilities and stockholders’ equity	$ 3,239,187	$ 3,334,734

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2016	Dec. 31, 2015
Statement of Financial Position [Abstract]
Capitalized costs of oil and natural gas properties excluded from amortization	$ 1,762,439	$ 1,817,701
Preferred stock, par value (usd per share)	$ 0.01	$ 0.01
Preferred stock, shares authorized (shares)	5,000,000	5,000,000
Preferred stock dividend rate, percent	12.00%	12.00%
Temporary Equity, Shares Authorized (shares)	30,000	30,000
Preferred stock Series A, issued (shares)	0	0
Preferred stock Series A, outstanding (shares)	0	0
Common stock, par value (usd per share)	$ 0.01	$ 0.01
Common Stock, Shares Authorized (shares)	200,000,000	200,000,000
Common Stock, Shares, Issued (shares)	125,365,166	108,322,250
Common Stock, Shares, Outstanding (shares)	125,365,166	108,322,250

Consolidated Statements of Oper

Consolidated Statements of Operations (Unaudited) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenues:
Gas sales	$ (57,860,000)	$ 65,871,000	$ 73,234,000	$ 184,441,000
Oil and condensate sales	20,533,000	34,465,000	37,654,000	69,965,000
Natural gas liquid sales	9,168,000	11,958,000	17,914,000	33,965,000
Other income (expense)	7,000	(24,000)	9,000	216,000
Total revenues	(28,152,000)	112,270,000	128,811,000	288,587,000
Costs and expenses:
Lease operating expenses	14,661,000	16,863,000	31,318,000	33,843,000
Production taxes	2,856,000	3,285,000	5,967,000	7,570,000
Midstream gathering and processing	39,349,000	32,904,000	77,001,000	58,285,000
Depreciation, depletion and amortization	55,652,000	71,155,000	121,129,000	161,064,000
Impairment of oil and gas properties	170,621,000	0	389,612,000	0
General and administrative	11,854,000	9,515,000	22,474,000	20,314,000
Accretion expense	261,000	192,000	508,000	382,000
Total costs and expenses	295,254,000	133,914,000	648,009,000	281,458,000
(LOSS) INCOME FROM OPERATIONS	(323,406,000)	(21,644,000)	(519,198,000)	7,129,000
OTHER (INCOME) EXPENSE:
Interest expense	16,082,000	12,023,000	32,105,000	20,782,000
Interest income	(391,000)	(248,000)	(485,000)	(257,000)
Loss (income) from equity method investments	836,000	15,120,000	31,573,000	(4,855,000)
Total Other (Income) Expense	16,527,000	26,895,000	63,193,000	15,670,000
LOSS BEFORE INCOME TAXES	(339,933,000)	(48,539,000)	(582,391,000)	(8,541,000)
INCOME TAX BENEFIT	(157,000)	(17,214,000)	(348,000)	(2,735,000)
NET LOSS	$ (339,776,000)	$ (31,325,000)	$ (582,043,000)	$ (5,806,000)
NET LOSS PER COMMON SHARE:
Basic (in usd per share)	$ (2.71)	$ (0.32)	$ (4.91)	$ (0.06)
Diluted (in usd per share)	$ (2.71)	$ (0.32)	$ (4.91)	$ (0.06)
Weighted average common shares outstanding - Basic (shares)	125,343,723	96,663,358	118,426,654	91,201,824
Weighted average common shares outstanding-Diluted (shares)	125,343,723	96,663,358	118,426,654	91,201,824

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Loss (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Statement of Comprehensive Income [Abstract]
Net loss	$ (339,776)	$ (31,325)	$ (582,043)	$ (5,806)
Foreign currency translation adjustment	(684)	3,247	8,374	(11,737)
Other comprehensive (loss) income	(684)	3,247	8,374	(11,737)
Comprehensive loss	$ (340,460)	$ (28,078)	$ (573,669)	$ (17,543)

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity (Unaudited) - USD ($) $ in Thousands	Total	Common Stock	Paid-in Capital	Accumulated Other Comprehensive (Loss) Income	Retained Earnings
Beginning Balance (in shares) at Dec. 31, 2014		85,655,438
Beginning Balance at Dec. 31, 2014	$ 2,296,296	$ 856	$ 1,828,602	$ (26,675)	$ 493,513
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	(5,806)				(5,806)
Other Comprehensive Income (Loss)	(11,737)			(11,737)
Stock Compensation	6,735		6,735
Issuance of Common Stock in public offerings, net of related expenses (shares)		22,425,000
Issuance of Common Stock in public offerings, net of related expenses	981,818	$ 224	981,594
Issuance of Restricted Stock (in shares)		123,543
Issuance of Restricted Stock	0	$ 1	(1)
Ending Balance (in shares) at Jun. 30, 2015		108,203,981
Ending Balance at Jun. 30, 2015	$ 3,267,306	$ 1,081	2,816,930	(38,412)	487,707
Beginning Balance (in shares) at Dec. 31, 2015	108,322,250	108,322,250
Beginning Balance at Dec. 31, 2015	$ 2,038,837	$ 1,082	2,824,303	(55,177)	(731,371)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net loss	(582,043)				(582,043)
Other Comprehensive Income (Loss)	8,374			8,374
Stock Compensation	6,561		6,561
Issuance of Common Stock in public offerings, net of related expenses (shares)		16,905,000
Issuance of Common Stock in public offerings, net of related expenses	411,711	$ 169	411,542
Issuance of Restricted Stock (in shares)		137,916
Issuance of Restricted Stock	$ 0	$ 2	(2)
Ending Balance (in shares) at Jun. 30, 2016	125,365,166	125,365,166
Ending Balance at Jun. 30, 2016	$ 1,883,440	$ 1,253	$ 3,242,404	$ (46,803)	$ (1,313,414)

Consolidated Statements of Cash

Consolidated Statements of Cash Flows (Unaudited) - USD ($)	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015
Cash flows from operating activities:
Net loss	$ (582,043,000)	$ (5,806,000)
Adjustments to reconcile net loss to net cash provided by operating activities:
Accretion of discount—Asset Retirement Obligation	508,000	382,000
Depletion, depreciation and amortization	121,129,000	161,064,000
Impairment of oil and gas properties	389,612,000	0
Stock-based compensation expense	3,936,000	4,041,000
Loss from equity investments	31,732,000	2,171,000
Loss on derivative instruments	206,370,000	3,309,000
Deferred income tax benefit	(348,000)	(2,735,000)
Amortization of loan commitment fees	1,921,000	1,416,000
Amortization of note discount and premium	(1,135,000)	(1,065,000)
Changes in operating assets and liabilities:
(Increase) decrease in accounts receivable	(19,590,000)	17,237,000
Increase in accounts receivable—related party	(7,000)	(44,000)
Increase in prepaid expenses	(3,877,000)	(11,454,000)
Decrease in accounts payable and accrued liabilities	(5,412,000)	(28,522,000)
Settlement of asset retirement obligation	(72,000)	(1,120,000)
Net cash provided by operating activities	142,724,000	138,874,000
Cash flows from investing activities:
Deductions to cash held in escrow	8,000	8,000
Additions to other property and equipment	(13,410,000)	(4,154,000)
Additions to oil and gas properties	(257,222,000)	(898,639,000)
Proceeds from sale of oil and gas properties	1,612,000	1,679,000
Funding of restricted cash	0	(75,005,000)
Contributions to equity method investments	(16,690,000)	(8,267,000)
Distributions from equity method investments	4,658,000	4,612,000
Net cash used in investing activities	(281,044,000)	(979,766,000)
Cash flows from financing activities:
Principal payments on borrowings	(1,685,000)	(350,088,000)
Borrowings on line of credit	0	250,000,000
Proceeds from bond issuance	0	350,000,000
Borrowings on term loan	11,962,000	0
Debt issuance costs and loan commitment fees	(205,000)	(7,738,000)
Proceeds from issuance of common stock, net of offering costs	411,711,000	981,866,000
Net cash provided by financing activities	421,783,000	1,224,040,000
Net increase in cash and cash equivalents	283,463,000	383,148,000
Cash and cash equivalents at beginning of period	112,974,000	142,340,000
Cash and cash equivalents at end of period	396,437,000	525,488,000
Supplemental disclosure of cash flow information:
Interest payments	35,026,000	24,176,000
Income tax payments		29,753,000
Supplemental disclosure of non-cash transactions:
Capitalized stock based compensation	2,625,000	2,694,000
Asset retirement obligation capitalized	3,195,000	4,077,000
Interest capitalized	3,707,000	8,399,000
Foreign currency translation gain (loss) on equity method investments	$ 8,374,000	$ (11,737,000)

Acquisitions

Acquisitions	6 Months Ended
	Jun. 30, 2016
Business Combinations [Abstract]
Acquisitions	ACQUISITIONS In April 2015, the Company entered into an agreement to acquire Paloma Partners III, LLC ("Paloma") for a total purchase price of approximately $301.9 million , subject to certain adjustments. Paloma holds approximately 24,000 net nonproducing acres in the Utica Shale of Ohio. In accordance with the agreement, the Company deposited $75.0 million into an escrow account. At the closing of the transaction the deposit was credited toward the purchase price. This transaction closed on August 31, 2015 for a purchase price of approximately $302.3 million , net of purchase price adjustments. At closing, approximately $30.1 million of the purchase price was placed in escrow as security to the Company for potential indemnification claims that may occur as a result of the sale. On June 9, 2015, the Company completed the acquisition of 6,198 gross and net acres located in Belmont and Jefferson Counties, Ohio from American Energy-Utica, LLC ("AEU") for a purchase price of approximately $68.2 million , subject to adjustment. On June 12, 2015, the Company completed the acquisition of 38,965 gross ( 27,228 net) acres located in Monroe County, Ohio, 14.6 MMcf per day of average net production (estimated for April 2015), 18 gross ( 11.3 net) drilled but uncompleted wells, an 11 mile gas gathering system and a four well pad location from AEU for a total purchase price of approximately $319.0 million (the "Monroe Acquisition"). On June 29, 2015, the Company acquired an additional 4,950 gross ( 1,900 net) acres in Monroe County for an additional $18.2 million from AEU. The total purchase price of these transactions, collectively referred to as the ("AEU Acquisition"), was approximately $405.4 million ( $405.0 million net of purchase price adjustments). At closing, approximately $67.1 million of the purchase price was placed in escrow pending completion of title review after the closing. In December 2015, approximately $2.4 million of the escrow was released and returned to the Company with the balance of the escrow account distributed to the seller based on final title review. The AEU Acquisition qualified as a business combination for accounting purposes and, as such, the Company estimated the fair value of the acquired properties as of the June 12, 2015 acquisition date. The fair value of the assets and liabilities acquired was estimated using assumptions that represent Level 3 inputs. See Note 12 for additional discussion of the measurement inputs. The Company estimated that the consideration paid in the AEU Acquisition for these properties approximated the fair value that would be paid by a typical market participant. As a result, no goodwill or bargain purchase gain was recognized in conjunction with the purchase. The following table summarizes the consideration paid in the AEU Acquisition to acquire the properties and the fair value amount of the assets acquired as of June 12, 2015. Both the consideration paid and the fair value assigned to the assets is preliminary and subject to adjustment upon final closing. (In thousands) Consideration paid Cash, net of purchase price adjustments $ 405,029 Fair value of identifiable assets acquired Oil and natural gas properties Proved $ 70,804 Unevaluated 334,225 Fair value of net identifiable assets acquired $ 405,029

Property And Equipment

Property And Equipment	6 Months Ended
	Jun. 30, 2016
Property, Plant and Equipment [Abstract]
Property And Equipment	PROPERTY AND EQUIPMENT The major categories of property and equipment and related accumulated depletion, depreciation, amortization and impairment as of June 30, 2016 and December 31, 2015 are as follows: June 30, 2016 December 31, 2015 (In thousands) Oil and natural gas properties $ 5,686,188 $ 5,424,342 Office furniture and fixtures 13,139 12,589 Building 31,301 16,915 Land 3,667 3,667 Total property and equipment 5,734,295 5,457,513 Accumulated depletion, depreciation, amortization and impairment (3,339,087 ) (2,829,110 ) Property and equipment, net $ 2,395,208 $ 2,628,403 At June 30, 2016 , the net book value of the Company's oil and natural gas properties was above the calculated ceiling as a result of the reduced commodity prices for the period leading up to June 30, 2016 . As a result, the Company recorded an impairment of its oil and natural gas properties under the full cost method of accounting of $389.6 million for the six months ended June 30, 2016 . No impairment of oil and natural gas properties was required under the ceiling test for the six months ended June 30, 2015 . Included in oil and natural gas properties at June 30, 2016 is the cumulative capitalization of $115.6 million in general and administrative costs incurred and capitalized to the full cost pool. General and administrative costs capitalized to the full cost pool represent management’s estimate of costs incurred directly related to exploration and development activities such as geological and other administrative costs associated with overseeing the exploration and development activities. All general and administrative costs not directly associated with exploration and development activities were charged to expense as they were incurred. Capitalized general and administrative costs were approximately $ 7.9 million and $ 15.0 million for the three and six months ended June 30, 2016 , respectively, and $ 6.3 million and $ 13.5 million for the three and six months ended June 30, 2015 , respectively. The following table summarizes the Company’s non-producing properties excluded from amortization by area at June 30, 2016 : June 30, 2016 (In thousands) Utica $ 1,757,014 Niobrara 4,853 Southern Louisiana 431 Bakken 96 Other 45 $ 1,762,439 At December 31, 2015 , approximately $1.8 billion of non-producing leasehold costs was not subject to amortization. The Company evaluates the costs excluded from its amortization calculation at least annually. Subject to industry conditions and the level of the Company’s activities, the inclusion of most of the above referenced costs into the Company’s amortization calculation typically occurs within three to five years. However, the majority of the Company's non-producing leases have five-year extension terms which could extend this time frame beyond five years. A reconciliation of the Company's asset retirement obligation for the six months ended June 30, 2016 and 2015 is as follows: June 30, 2016 June 30, 2015 (In thousands) Asset retirement obligation, beginning of period $ 26,437 $ 17,938 Liabilities incurred 3,195 4,077 Liabilities settled (72 ) (1,120 ) Accretion expense 508 382 Asset retirement obligation as of end of period 30,068 21,277 Less current portion 75 75 Asset retirement obligation, long-term $ 29,993 $ 21,202

Equity Investments

Equity Investments	6 Months Ended
	Jun. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Equity Investments	EQUITY INVESTMENTS Investments accounted for by the equity method consist of the following as of June 30, 2016 and December 31, 2015 : Carrying value Loss (income) from equity method investments Approximate ownership % June 30, 2016 December 31, 2015 Three months ended June 30, Six months ended June 30, 2016 2015 2016 2015 (In thousands) Investment in Tatex Thailand II, LLC 23.5 % $ — $ — $ — $ — $ (159 ) $ — Investment in Tatex Thailand III, LLC 17.9 % — — — 189 — 189 Investment in Grizzly Oil Sands ULC 24.9999 % 49,556 50,645 763 8,494 24,448 12,636 Investment in Timber Wolf Terminals LLC 50.0 % 996 999 1 7 4 13 Investment in Windsor Midstream LLC 22.5 % 26,147 27,955 (2,881 ) 881 (3,048 ) (17,906 ) Investment in Stingray Cementing LLC 50.0 % 2,359 2,487 78 105 108 172 Investment in Blackhawk Midstream LLC 48.5 % — — — — — (7,217 ) Investment in Stingray Energy Services LLC 50.0 % 4,981 5,908 139 311 641 321 Investment in Sturgeon Acquisitions LLC 25.0 % 22,258 22,769 134 (491 ) 511 (1,059 ) Investment in Mammoth Energy Partners LP 30.5 % 121,309 131,630 2,543 5,624 9,009 7,996 Investment in Strike Force Midstream LLC 25.0 % 25,441 — 59 — 59 — $ 253,047 $ 242,393 $ 836 $ 15,120 $ 31,573 $ (4,855 ) The tables below summarize financial information for the Company's equity investments as of June 30, 2016 and December 31, 2015 . Summarized balance sheet information: June 30, 2016 December 31, 2015 (In thousands) Current assets $ 105,614 $ 105,537 Noncurrent assets $ 1,330,877 $ 1,293,925 Current liabilities $ 41,238 $ 56,559 Noncurrent liabilities $ 146,642 $ 155,995 Summarized results of operations: Three months ended June 30, Six months ended June 30, 2016 2015 2016 2015 (In thousands) Gross revenue $ 86,732 $ 130,134 $ 130,039 $ 263,690 Net (loss) income $ (560 ) $ (45,246 ) $ (25,868 ) $ 45,422 Tatex Thailand II, LLC The Company has an indirect ownership interest in Tatex Thailand II, LLC (“Tatex II”). Tatex II holds 85,122 of the 1,000,000 outstanding shares of APICO, LLC (“APICO”), an international oil and gas exploration company. APICO has a reserve base located in Southeast Asia through its ownership of concessions covering approximately 243,000 acres which includes the Phu Horm Field. During the six months ended June 30, 2016 , the Company received $0.2 million in distributions from Tatex II. Tatex Thailand III, LLC The Company has an ownership interest in Tatex Thailand III, LLC ("Tatex III"). Tatex III previously owned a concession covering approximately 245,000 acres in Southeast Asia. As of December 31, 2014, the Company reviewed its investment in Tatex III and made the decision to allow the concession to expire in January 2015. As such, the Company fully impaired the asset as of December 31, 2014. Grizzly Oil Sands ULC The Company, through its wholly owned subsidiary Grizzly Holdings Inc. ("Grizzly Holdings"), owns an interest in Grizzly Oil Sands ULC ("Grizzly"), a Canadian unlimited liability company. The remaining interest in Grizzly is owned by Grizzly Oil Sands Inc. ("Oil Sands"). As of June 30, 2016 , Grizzly had approximately 830,000 acres under lease in the Athabasca and Peace River oil sands regions of Alberta, Canada. Initiation of steam injection at its first project, Algar Lake Phase 1, commenced in January 2014 and first bitumen production was achieved during the second quarter of 2014. In April 2015, Grizzly determined to cease bitumen production at its Algar Lake facility due to the level of commodity prices. Grizzly continues to monitor market conditions as it assesses future plans for the facility. The Company reviewed its investment in Grizzly at March 31, 2016 for impairment based on FASB ASC 323 due to certain qualitative factors and engaged an independent third party to assist management in determining fair value calculations of its investment. As a result of the calculated fair values and other qualitative factors, the Company concluded that an other than temporary impairment was required under FASB ASC 323, resulting in an impairment loss of $23.1 million for the three months ended March 31, 2016, which is included in loss (income) from equity method investments in the consolidated statements of operations. As of June 30, 2016 , commodity prices had increased as compared to the prior quarter and there were no impairment indicators that required further evaluation for impairment. If commodity prices decline in the future, however, further impairment of the investment in Grizzly may be necessary. During the six months ended June 30, 2016 , Gulfport paid $13.7 million in cash calls. Grizzly’s functional currency is the Canadian dollar. The Company's investment in Grizzly was decreased by $0.6 million as a result of a foreign currency translation loss and increased by $9.7 million as a result of a foreign currency translation gain for the three and six months ended June 30, 2016 , respectively. The Company's investment in Grizzly was increased by $3.2 million as a result of a foreign currency translation gain and decreased by $11.7 million as a result of a foreign currency translation loss for the three and six months ended June 30, 2015 , respectively. Effective October 5, 2012, Grizzly entered into a $125.0 million revolving credit facility, under which $57.2 million was outstanding at June 30, 2016 . Grizzly has agreed to pay the outstanding balance by the payoff date in July 2016. Gulfport paid its share of this amount on June 30, 2016. Timber Wolf Terminals LLC During 2012, the Company invested in Timber Wolf Terminals LLC (“Timber Wolf”). Timber Wolf was formed to operate a crude/condensate terminal and a sand transloading facility in Ohio. Windsor Midstream LLC During 2012, the Company purchased an ownership interest in Windsor Midstream LLC (“Midstream”). Midstream owned a 28.4% interest in Coronado Midstream LLC ("Coronado"), a gas processing plant in West Texas. In March 2015, Coronado was sold to Enlink Midstream Partners, LP ("EnLink") for proceeds of approximately $600.0 million , consisting of cash and units representing a limited partnership interest in Enlink. Midstream recorded an $ 81.6 million gain on the sale of its investment in Coronado. The Company received $4.9 million in distributions from Midstream during the six months ended June 30, 2016 . Stingray Cementing LLC During 2012, the Company invested in Stingray Cementing LLC ("Stingray Cementing"). Stingray Cementing provides well cementing services. The loss (income) from equity method investments presented in the table above reflects any intercompany profit eliminations. Blackhawk Midstream LLC During 2012, the Company invested in Blackhawk Midstream LLC ("Blackhawk"). Blackhawk was formed to coordinate gathering, compression, processing and marketing activities for the Company in connection with the development of its Utica Shale acreage. On January 28, 2014, Blackhawk completed the sale of its equity interests in Ohio Gathering Company, LLC and Ohio Condensate Company, LLC for a purchase price of $190.0 million , of which $14.3 million was placed in escrow. During the first quarter of 2015, the Company received net proceeds of approximately $7.2 million from the release of escrow from the Blackhawk sale, which is included in loss (income) from equity method investments in the consolidated statements of operations. Stingray Energy Services LLC During 2013, the Company invested in Stingray Energy Services LLC ("Stingray Energy"). Stingray Energy provides rental tools for land-based oil and natural gas drilling, completion and workover activities as well as the transfer of fresh water to wellsites. The loss (income) from equity method investments presented in the table above reflects any intercompany profit eliminations. Sturgeon Acquisitions LLC During 2014, the Company invested $20.7 million and received an ownership interest of 25% in Sturgeon Acquisitions LLC ("Sturgeon"). Sturgeon owns and operates sand mines that produce hydraulic fracturing grade sand. Mammoth Energy Partners LP In the fourth quarter of 2014, the Company contributed its investments in four entities to Mammoth Energy Partners LP ("Mammoth") for a 30.5% interest in this entity. Mammoth originally intended to pursue its initial public offering in 2014 or 2015; however, Mammoth continues to evaluate market conditions and expects to undertake this offering when commodity prices have recovered. The Company reviewed its investment in Mammoth at June 30, 2016 and determined no impairment was needed. If commodity prices decline in the future, an impairment of the investment in Mammoth may result. The Company's investment in Mammoth was decreased by $1.3 million as a result of a foreign currency loss from Mammoth's foreign subsidiary for the six months ended June 30, 2016 . The loss (income) from equity method investments presented in the table above reflects any intercompany profit eliminations. Strike Force Midstream LLC In February 2016, the Company, through its wholly owned subsidiary Gulfport Midstream Holdings, LLC ("Midstream Holdings"), entered into an agreement with Rice Midstream Holdings LLC ("Rice"), a subsidiary of Rice Energy Inc., to develop natural gas gathering assets in eastern Belmont County and Monroe County, Ohio (the "dedicated areas"). The Company contributed certain gathering assets for a 25% interest in the newly formed entity called Strike Force Midstream LLC ("Strike Force"). Rice acts as operator and owns the remaining 75% interest in Strike Force. Construction of the gathering assets, which is underway, is expected to provide gathering services for Gulfport operated wells and connectivity of existing dry gas gathering systems. Strike Force has completed the first phase of the projects: a lateral that connects two existing dry gas gathering systems on which the Company currently flows the majority of its dry gas volumes. First flow from the lateral commenced on February 1, 2016. During the six months ended June 30, 2016 , Gulfport paid $3.0 million in cash calls to Strike Force. The Company accounted for its contribution to Strike Force at fair value under applicable codification guidance. The Company estimated the fair market value of its investment in Strike Force as of the contribution date using the discounted cash flow method under the income approach, based on an independently prepared valuation of the contributed assets. The fair market value was reduced by a discount factor for the lack of marketability due to the Company's minority interest, resulting in a fair value of $22.5 million for the Company's 25% interest. The fair value of the assets contributed was estimated using assumptions that represent Level 3 inputs. See "Note 12 - Fair Value Measurements" for additional discussion of the measurement inputs. The Company has elected to report its proportionate share of Strike Force's earnings on a one-quarter lag as permitted under FASB ASC 323. The loss (income) from equity method investments presented in the table above reflects any intercompany profit eliminations.

Variable Interest Entities

Variable Interest Entities	6 Months Ended
	Jun. 30, 2016
Related Party Transactions [Abstract]
Variable Interest Entities	VARIABLE INTEREST ENTITIES As of June 30, 2016 , the Company held variable interests in the following variable interest entities ("VIEs"), but was not the primary beneficiary: Mammoth, Stingray Energy, Stingray Cementing, Sturgeon, Midstream and Timber Wolf. These entities have governing provisions that are the functional equivalent of a limited partnership and are considered VIEs because the limited partners or non-managing members lack substantive kick-out or participating rights which causes the equity owners, as a group, to lack a controlling financial interest. The Company is a limited partner or non-managing member in each of these VIEs and is not the primary beneficiary because it does not have a controlling financial interest. The general partner or managing member has power to direct the activities that most significantly impact the VIEs’ economic performance. The Company also held a variable interest in Strike Force due to the fact that it does not have sufficient equity capital at risk. The Company is not the primary beneficiary of this entity. The Company accounts for its investment in these VIEs following the equity method of accounting. The carrying amounts of the Company’s equity investments are classified as other non-current assets on the accompanying consolidated balance sheets. The Company’s maximum exposure to loss as a result of its involvement with these VIEs is based on the Company’s capital contributions and the economic performance of the VIEs, and is equal to the carrying value of the Company’s investments which is the maximum loss the Company could be required to record in the consolidated statements of operations. See Note 3 for further discussion of these entities, including the carrying amounts of each investment.

Other Assets

Other Assets	6 Months Ended
	Jun. 30, 2016
Other Assets, Noncurrent Disclosure [Abstract]
Other Assets	OTHER ASSETS Other assets consist of the following as of June 30, 2016 and December 31, 2015 : June 30, 2016 December 31, 2015 (In thousands) Plugging and abandonment escrow account on the WCBB properties (Note 10) $ 3,081 $ 3,089 Certificates of Deposit securing letter of credit 276 276 Prepaid drilling costs 5,404 58 Loan commitment fees 2,496 2,870 Deposits 34 34 Other 45 37 $ 11,336 $ 6,364

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2016
Long-term Debt, Unclassified [Abstract]
Long-Term Debt	LONG-TERM DEBT Long-term debt consisted of the following items as of June 30, 2016 and December 31, 2015 : June 30, 2016 December 31, 2015 (In thousands) Revolving credit agreement (1) $ — $ — Building loan (2) — 1,653 7.75% senior unsecured notes due 2020 (3) 600,000 600,000 6.625% senior unsecured notes due 2023 (4) 350,000 350,000 Net unamortized original issue premium, net (5) 11,359 12,493 Net unamortized debt issuance costs (6) (16,567 ) (17,883 ) Construction loan (7) 11,962 — Less: current maturities of long term debt — (179 ) Debt reflected as long term $ 956,754 $ 946,084 The Company capitalized approximately $1.4 million and $3.0 million in interest expense to undeveloped oil and natural gas properties during the three and six months ended June 30, 2016 , respectively. The Company capitalized approximately $4.7 million and $8.4 million in interest expense to oil and natural gas properties during the three and six months ended June 30, 2015 , respectively. During the three and six months ended June 30, 2016 , the Company also capitalized approximately $0.4 million and $0.7 million , respectively, in interest expense related to building construction. (1) The Company has entered into a senior secured revolving credit facility, as amended, with The Bank of Nova Scotia, as the lead arranger and administrative agent and certain lenders from time to time party thereto. The credit agreement provides for a maximum facility amount of $1.5 billion and matures on June 6, 2018. On February 19, 2016, the Company further amended its revolving credit facility to, among other things, (a) increase the basket for unsecured debt issuances to $1.4 billion from $1.2 billion (of which $950 million was then outstanding), (b) reaffirm the Company’s borrowing base of $700.0 million , and (c) increase the percentage of projected oil and gas production that may be hedged by the Company during 2016. As of June 30, 2016 , no balance was outstanding under this revolving credit facility and total funds available for borrowing, after giving effect to an aggregate of $205.8 million of letters of credit, were $494.2 million . This facility is secured by substantially all of the Company's assets. The wholly-owned subsidiaries of the Company guarantee the obligations under the revolving credit facility. Advances under this revolving credit facility may be in the form of either base rate loans or eurodollar loans. The interest rate for base rate loans is equal to (1) the applicable rate, which ranges from 0.50% to 1.50% , plus (2) the highest of: (a) the federal funds rate plus 0.50% , (b) the rate of interest in effect for such day as publicly announced from time to time by agent as its “prime rate,” and (c) the eurodollar rate for an interest period of one month plus 1.00% . The interest rate for eurodollar loans is equal to (1) the applicable rate, which ranges from 1.50% to 2.50% , plus (2) the London interbank offered rate that appears on pages LIBOR01 or LIBOR02 of the Reuters screen that displays such rate for deposits in U.S. dollars, or, if such rate is not available, the rate as administered by ICE Benchmark Administration (or any other person that takes over administration of such rate) per annum equal to the offered rate on such other page or other service that displays an average London interbank offered rate as administered by ICE Benchmark Administration (or any other person that takes over the administration of such rate) for deposits in U.S. dollars, or, if such rate is not available, the average quotations for three major New York money center banks of whom the agent shall inquire as the “London Interbank Offered Rate” for deposits in U.S. dollars. The Company's revolving credit facility contains customary negative covenants including, but not limited to, restrictions on the Company's and its subsidiaries' ability to: incur indebtedness; grant liens; pay dividends and make other restricted payments; make investments; make fundamental changes; enter into swap contracts and forward sales contracts; dispose of assets; change the nature of their business; and enter into transactions with their affiliates. The negative covenants are subject to certain exceptions as specified in this revolving credit facility. The Company's revolving credit facility also contains certain affirmative covenants, including, but not limited to the following financial covenants: (1) the ratio of net funded debt to EBITDAX (net income, excluding (i) any non-cash revenue or expense associated with swap contracts resulting from ASC 815 and (ii) any cash or non-cash revenue or expense attributable to minority investment plus without duplication and, in the case of expenses, to the extent deducted from revenues in determining net income, the sum of (a) the aggregate amount of consolidated interest expense for such period, (b) the aggregate amount of income, franchise, capital or similar tax expense (other than ad valorem taxes) for such period, (c) all amounts attributable to depletion, depreciation, amortization and asset or goodwill impairment or writedown for such period, (d) all other non-cash charges, (e) exploration costs deducted in determining net income under successful efforts accounting, (f) actual cash distributions received from minority investments, (g) to the extent actually reimbursed by insurance, expenses with respect to liability on casualty events or business interruption, and (h) all reasonable transaction expenses related to dispositions and acquisitions of assets, investments and debt and equity offerings (provided that expenses related to any unsuccessful dispositions will be limited to $3.0 million in the aggregate) for a twelve-month period may not be greater than 4.00 to 1.00; and (2) the ratio of EBITDAX to interest expense for a twelve-month period may not be less than 3.00 to 1.00. The Company was in compliance with these financial covenants at June 30, 2016 . (2) In March 2011, the Company refinanced the $2.4 million then outstanding under its previous building loan for the office building it occupies in Oklahoma City, Oklahoma. This loan agreement, as subsequently amended, bore interest at the rate of 4.00% per annum, required monthly interest and principal payments of approximately $20,000 , was collateralized by the Oklahoma City office building and associated land and had a maturity date of December 2018. The Company paid the balance of the loan in full in February 2016. (3) On October 17, 2012, the Company issued $250.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "October Notes") under an indenture among the Company, its subsidiary guarantors and Wells Fargo Bank, National Association, as the trustee (the "senior note indenture"). On December 21, 2012, the Company issued an additional $50.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "December Notes") as additional securities under the senior note indenture. The Company used a portion of the net proceeds from the October Notes to repay all amounts outstanding at such time under its revolving credit facility. The Company used the remaining net proceeds of the October Notes and the net proceeds of the December Notes for general corporate purposes, which included funding a portion of its 2013 capital development plan. The October Notes and the December Notes were exchanged for substantially identical notes in the same aggregate principal amount that were registered under the Securities Act in October 2013 (the "Exchange Notes"). On August 18, 2014, the Company issued an additional $300.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "August Notes"). The August Notes were issued as additional securities under the senior note indenture. The Company used a portion of the net proceeds from the August Notes to repay all amounts outstanding at such time under its revolving credit facility. The Company used the remaining net proceeds of the August Notes Offering for general corporate purposes, including funding a portion of its 2014 and 2015 capital development plans. The October Notes, December Notes and the August Notes are collectively referred to as the "2020 Notes". In connection with the issuance of the 2020 Notes, the Company and the subsidiary guarantors entered into a registration rights agreement with the initial purchasers, pursuant to which the Company and the subsidiary guarantors agreed to file a registration statement with respect to an offering to exchange the 2020 Notes for a new issue of substantially identical debt securities registered under the Securities Act. The exchange offer for the October Notes and the December Notes was completed in October 2013 and the exchange offer for the August Note was completed in March 2015. Under the senior note indenture relating to the 2020 Notes, interest on the 2020 Notes accrues at a rate of 7.75% per annum on the outstanding principal amount from October 17, 2012, payable semi-annually on May 1 and November 1 of each year, commencing on May 1, 2013. The 2020 Notes are the Company's senior unsecured obligations and rank equally in the right of payment with all of the Company's other senior indebtedness and senior in right of payment to any future subordinated indebtedness. All of the Company's existing and future restricted subsidiaries that guarantee the Company's secured revolving credit facility or certain other debt guarantee the 2020 Notes; provided, however, that the 2020 Notes are not guaranteed by Grizzly Holdings, Inc. and will not be guaranteed by any of the Company's future unrestricted subsidiaries. The Company may redeem some or all of the 2020 Notes at any time on or after November 1, 2016, at the redemption prices listed in the senior note indenture. Prior to November 1, 2016, the Company may redeem the 2020 Notes at a price equal to 100% of the principal amount plus a “make-whole” premium. In addition, prior to November 1, 2015, the Company may redeem up to 35% of the aggregate principal amount of the 2020 Notes with the net proceeds of certain equity offerings, provided that at least 65% of the aggregate principal amount of the 2020 Notes initially issued remains outstanding immediately after such redemption. (4) On April 21, 2015, the Company issued $350.0 million in aggregate principal amount of 6.625% Senior Notes due 2023 (the "2023 Notes" and, together with the "2020 Notes," the "Notes") to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to certain non-U.S. persons in accordance with Regulation S under the Securities Act (the "2023 Notes Offering"). The Company received net proceeds of approximately $343.6 million after initial purchaser discounts and commissions and estimated offering expenses. The 2023 notes were issued under an indenture, dated as of April 21, 2015, among the Company, the subsidiary guarantors party thereto and Wells Fargo Bank, National Association, as trustee. Pursuant to the indenture relating to the 2023 Notes, interest on the 2023 Notes will accrue at a rate of 6.625% per annum on the outstanding principal amount thereof from April 21, 2015, payable semi-annually on May 1 and November 1 of each year, commencing on November 1, 2015. The 2023 Notes are not guaranteed by Grizzly Holdings, Inc. and will not be guaranteed by any of the Company's future unrestricted subsidiaries. In connection with the 2023 Notes Offering, the Company and its subsidiary guarantors entered into a registration rights agreement, dated as of April 21, 2015, pursuant to which the Company agreed to file a registration statement with respect to an offer to exchange the 2023 Notes for a new issue of substantially identical debt securities registered under the Securities Act. The exchange offer for the 2023 Notes was completed on October 13, 2015. (5) The October Notes were issued at a price of 98.534% resulting in a gross discount of $3.7 million and an effective rate of 8.000% . The December Notes were issued at a price of 101.000% resulting in a gross premium of $0.5 million and an effective rate of 7.531% . The August Notes were issued at a price of 106.000% resulting in a gross premium of $18.0 million and an effective rate of 6.561% . The April Notes were issued at par. The premium and discount are being amortized using the effective interest method. (6) In accordance with Accounting Standards Update ("ASU") 2015-03, loan issuance costs related to the Notes have been presented as a reduction to the Notes. At June 30, 2016 , total unamortized debt issuance costs were $4.6 million for the October Notes, $1.0 million for the December Notes, $4.5 million for the August Notes and $6.4 million for the April Notes. (7) On June 4, 2015, the Company entered into a construction loan agreement (the "Construction Loan") with InterBank for the construction of a new corporate headquarters in Oklahoma City. The Construction Loan allows for a maximum principal amount of $24.5 million and requires the Company to fund 30% of the estimated cost of the construction before any funds can be drawn, which occurred in January 2016. Interest accrues daily on the outstanding principal balance at a fixed rate of 4.50% per annum and is payable on the last day of the month through May 31, 2017. Monthly interest and principal payments are due beginning June 30, 2017, with the final payment due June 4, 2025. At June 30, 2016 , the total borrowings under the Construction Loan were approximately $12.0 million .

Common Stock And Changes In Cap

Common Stock And Changes In Capitalization	6 Months Ended
	Jun. 30, 2016
Equity [Abstract]
Common Stock And Changes In Capitalization	COMMON STOCK AND CHANGES IN CAPITALIZATION Sale of Common Stock On March 15, 2016, the Company issued 16,905,000 shares of its common stock in an underwritten public offering (which included 2,205,000 shares sold pursuant to an option to purchase additional shares of the Company's common stock granted by the Company to, and exercised in full by, the underwriters). The net proceeds from this equity offering were approximately $411.7 million , after underwriting discounts and commissions and offering expenses. The Company intends to use the net proceeds from this offering primarily to fund a portion of its 2017 capital development plan and for general corporate purposes.

Stock-Based Compensation

Stock-Based Compensation	6 Months Ended
	Jun. 30, 2016
Share-based Compensation [Abstract]
Stock-Based Compensation	STOCK-BASED COMPENSATION During the three and six months ended June 30, 2016 , the Company’s stock-based compensation cost was $ 3.3 million and $6.6 million , respectively, of which the Company capitalized $1.3 million and $2.6 million , respectively, relating to its exploration and development efforts. During the three and six months ended June 30, 2015 , the Company’s stock-based compensation cost was $3.2 million and $6.7 million , respectively, of which the Company capitalized $1.3 million and $2.7 million , respectively, relating to its exploration and development efforts. The following table summarizes restricted stock activity for the six months ended June 30, 2016 : Number of Unvested Restricted Shares Weighted Average Grant Date Fair Value Unvested shares as of January 1, 2016 484,239 $ 43.51 Granted 255,204 27.71 Vested (137,916 ) 47.31 Forfeited (8,042 ) 34.76 Unvested shares as of June 30, 2016 593,485 $ 35.95 Unrecognized compensation expense as of June 30, 2016 related to restricted shares was $ 16.0 million . The expense is expected to be recognized over a weighted average period of 1.69 years.

Earnings Per Share

Earnings Per Share	6 Months Ended
	Jun. 30, 2016
Earnings Per Share [Abstract]
Earnings Per Share	EARNINGS PER SHARE Reconciliations of the components of basic and diluted net loss per common share are presented in the tables below: Three months ended June 30, 2016 2015 Loss Shares Per Share Loss Shares Per Share (In thousands, except share data) Basic: Net loss $ (339,776 ) 125,343,723 $ (2.71 ) $ (31,325 ) 96,663,358 $ (0.32 ) Effect of dilutive securities: Stock options and awards — — — — Diluted: Net loss $ (339,776 ) 125,343,723 $ (2.71 ) $ (31,325 ) 96,663,358 $ (0.32 ) Six months ended June 30, 2016 2015 Loss Shares Per Loss Shares Per (In thousands, except share data) Basic: Net loss $ (582,043 ) 118,426,654 $ (4.91 ) $ (5,806 ) 91,201,824 $ (0.06 ) Effect of dilutive securities: Stock options and awards — — — — Diluted: Net loss $ (582,043 ) 118,426,654 $ (4.91 ) $ (5,806 ) 91,201,824 $ (0.06 ) There were 573,187 and 558,894 shares of common stock that were considered anti-dilutive for the three and six months ended June 30, 2016 , respectively. There were 378,550 and 382,494 shares of common stock that were considered anti-dilutive for the three and six months ended June 30, 2015 , respectively.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	COMMITMENTS AND CONTINGENCIES Plugging and Abandonment Funds In connection with the Company's acquisition in 1997 of the remaining 50% interest in its WCBB properties, the Company assumed the seller’s (Chevron) obligation to contribute approximately $18,000 per month through March 2004 to a plugging and abandonment trust and the obligation to plug a minimum of 20 wells per year for 20 years commencing March 11, 1997. Chevron retained a security interest in production from these properties until the Company's abandonment obligations to Chevron have been fulfilled. Beginning in 2009, the Company could access the trust for use in plugging and abandonment charges associated with the property, although it has not yet done so. As of June 30, 2016 , the plugging and abandonment trust totaled approximately $3.1 million . At June 30, 2016 , the Company had plugged 463 wells at WCBB since it began its plugging program in 1997, which management believes fulfills its current minimum plugging obligation. Operating Leases The Company leases office facilities under non-cancellable operating leases exceeding one year. Future minimum lease commitments under these leases at June 30, 2016 were as follows: (In thousands) Remaining 2016 $ 386 2017 583 2018 54 Total $ 1,023 Other Commitments Effective October 1, 2014 and subsequently amended on November 3, 2015, the Company entered into a Sand Supply Agreement with Muskie Proppant LLC ("Muskie") that expires on September 30, 2018. Pursuant to this agreement, the Company has agreed to purchase annual and monthly amounts of proppant sand subject to exceptions specified in the agreement at agreed pricing, plus agreed costs and expenses. Failure by either Muskie or the Company to deliver or accept the minimum monthly amount results in damages calculated per ton based on the difference between the monthly obligation amount and the amount actually delivered or accepted, as applicable. The Company incurred $0.7 million and $2.0 million related to non-utilization fees during the three and six months ended June 30, 2016 , respectively. Effective October 1, 2014, the Company entered into an Amended and Restated Master Services Agreement for pressure pumping services with Stingray Pressure Pumping LLC ("Stingray Pressure") that expires on September 30, 2018. Pursuant to this agreement, Stingray Pressure has agreed to provide hydraulic fracturing, stimulation and related completion and rework services to the Company and the Company has agreed to pay Stingray Pressure a monthly service fee plus the associated costs of the services provided. On February 18, 2016, effective January 1, 2016, the Company amended its Master Services Agreement with Stingray Pressure. The amendment adjusted the amount of service fees payable for the period from January 1, 2016 through September 30, 2016. Future minimum commitments under these agreements at June 30, 2016 are as follows: (In thousands) Remaining 2016 $ 26,220 2017 52,440 2018 39,330 Total $ 117,990 Litigation In two separate complaints, one filed by the State of Louisiana and the Parish of Cameron in the 38th Judicial District Court for the Parish of Cameron on February 9, 2016 and the other filed by the State of Louisiana and the District Attorney for the 15 th Judicial District of the State of Louisiana in the 15 th Judicial District Court for the Parish of Vermillion on July 29, 2016, the Company was named as a defendant, among 26 oil and gas companies, in the Cameron Parish complaint and among nine oil and gas companies in the Vermillion Parish complaint. Both complaints were filed under the State and Local Coastal Resources Management Act of 1978, as amended, and the rules, regulations, orders and ordinances adopted thereunder, which the Company referred to collectively as the CZM Laws, and allege that certain of the defendants’ oil and gas exploration, production and transportation operations associated with the development of the East Hackberry and West Hackberry oil and gas fields, in the case of the Cameron Parish complaint, and the Tigre Lagoon oil and gas field, in the case of the Vermillion Parish complaint, were conducted in violation of the CZM Laws. Both complaints allege that such activities caused substantial damage to land and waterbodies located in the coastal zone of the relevant Parish, including due to defendants’ design, construction and use of waste pits and the alleged failure to properly close the waste pits and to clear, re-vegetate, detoxify and return the property affected to its original condition, as well as the defendants’ alleged discharge of waste into the coastal zone. The Cameron Parish complaint also alleges that the defendants’ oil and gas activities have resulted in the dredging of numerous canals, which had a direct and significant impact on the state coastal waters within Cameron Parish and that the defendants, among other things, failed to design, construct and maintain these canals using the best practical techniques to prevent bank slumping, erosion and saltwater intrusion and to minimize the potential for inland movement of storm-generated surges, which activities allegedly have resulted in the erosion of marshes and the degradation of terrestrial and aquatic life therein. The Cameron Parish complaint also alleges that the defendants failed to re-vegetate, refill, clean, detoxify and otherwise restore these canals to their original condition. In these two petitions, the plaintiffs seek damages and other appropriate relief under the CZM Laws, including the payment of costs necessary to clear, re-vegetate, detoxify and otherwise restore the affected coastal zone of the relevant Parish to its original condition, actual restoration of such coastal zone to its original condition, and the payment of reasonable attorney fees and legal expenses and pre-judgment and post judgment interest. Shortly after the Cameron Parish complaint was filed, the Louisiana Attorney General and the Louisiana Department of Natural Resources intervened in the lawsuit asserting similar claims. On April 21, 2016, several of the defendants removed the lawsuit to the United States District Court for the Western District of Louisiana in Lake Charles. The Company was served with this complaint on May 4, 2016. The plaintiffs filed a motion to remand the case back to the 38th Judicial District Court, and the motion to remand is set for hearing on September 1, 2016. The Company has not been served with the Vermillion Parish complaint. The Company has not had the opportunity to evaluate the applicability of the allegations made in such complaints to their operations. Due to the early stages of these matters, management cannot determine the amount of loss, if any, that may result. In addition, due to the nature of the Company's business, it is, from time to time, involved in routine litigation or subject to disputes or claims related to its business activities, including workers' compensation claims and employment related disputes. In the opinion of the Company's management, none of the pending litigation, disputes or claims against the Company, if decided adversely, will have a material adverse effect on its financial condition, cash flows or results of operations.

Derivative Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2016
General Discussion of Derivative Instruments and Hedging Activities [Abstract]
Derivative Instruments	DERIVATIVE INSTRUMENTS Oil, Natural Gas and Natural Gas Liquids Derivative Instruments The Company seeks to reduce its exposure to unfavorable changes in oil, natural gas and natural gas liquids prices, which are subject to significant and often volatile fluctuation, by entering into fixed over-the-counter fixed price swaps, basis swap and various types of option contracts. These contracts allow the Company to predict with greater certainty the effective oil, natural gas and natural gas liquids prices to be received for hedged production and benefit operating cash flows and earnings when market prices are less than the fixed prices provided in the contracts. However, the Company will not benefit from market prices that are higher than the fixed prices in the contracts for hedged production. Fixed price swaps are settled monthly based on differences between the fixed price specified in the contract and the referenced settlement price. When the referenced settlement price is less than the price specified in the contract, the Company receives an amount from the counterparty based on the price difference multiplied by the volume. Similarly, when the referenced settlement price exceeds the price specified in the contract, the Company pays the counterparty an amount based on the price difference multiplied by the volume. The prices contained in these fixed price swaps are based on Argus Louisiana Light Sweet Crude for oil, the NYMEX Henry Hub for natural gas and Mont Belvieu for propane. Below is a summary of the Company's open fixed price swap positions as of June 30, 2016 . Location Daily Volume Weighted July 2016 - June 2017 ARGUS LLS 2,000 $ 51.10 Location Daily Volume (MMBtu/day) Weighted July 2016 NYMEX Henry Hub 550,000 $ 3.06 August 2016 - September 2016 NYMEX Henry Hub 560,000 $ 3.04 October 2016 NYMEX Henry Hub 570,000 $ 3.05 November 2016 - December 2016 NYMEX Henry Hub 525,000 $ 3.18 January 2017 - February 2017 NYMEX Henry Hub 442,500 $ 3.14 March 2017 NYMEX Henry Hub 422,500 $ 3.13 April 2017 - June 2017 NYMEX Henry Hub 367,500 $ 3.15 July 2017 - October 2017 NYMEX Henry Hub 305,000 $ 2.99 November 2017 - December 2017 NYMEX Henry Hub 385,000 $ 3.03 January 2018 - March 2018 NYMEX Henry Hub 240,000 $ 3.07 April 2018 - December 2018 NYMEX Henry Hub 160,000 $ 3.01 January 2019 - March 2019 NYMEX Henry Hub 20,000 $ 3.37 Location Daily Volume Weighted July 2016 - December 2016 Mont Belvieu 1,500 $ 19.95 The Company sold call options and used the associated premiums to enhance the fixed price for a portion of the fixed price natural gas swaps listed above. Each short call option has an established ceiling price. When the referenced settlement price is above the price ceiling established by these short call options, the Company pays its counterparty an amount equal to the difference between the referenced settlement price and the price ceiling multiplied by the hedged contract volume. Location Daily Volume (MMBtu/day) Weighted Average Price January 2017 - March 2017 NYMEX Henry Hub 105,000 $ 3.27 April 2017 - December 2017 NYMEX Henry Hub 125,000 $ 3.21 January 2018 - March 2018 NYMEX Henry Hub 20,000 $ 2.91 For a portion of the combined natural gas derivative instruments containing fixed price swaps and sold call options, the counterparty has an option to extend the original terms an additional twelve months for the period January 2017 through December 2017. The option to extend the terms expires in December 2016. If executed, the Company would have additional fixed price swaps for 30,000 MMBtu per day at a weighted average price of $3.33 per MMBtu and additional short call options for 30,000 MMBtu per day at a weighted average ceiling price of $3.33 per MMBtu. In addition, the Company has entered into natural gas basis swap positions, which settle on the pricing index to basis differential of MichCon or Tetco M2 to the NYMEX Henry Hub natural gas price. As of June 30, 2016 , the Company had the following natural gas basis swap positions for MichCon and Tetco M2, respectively. Location Daily Volume (MMBtu/day) Hedged Differential July 2016 - December 2016 MichCon 40,000 $ 0.02 November 2016 - March 2017 Tetco M2 50,000 $ (0.59 ) Balance Sheet Presentation The Company reports the fair value of derivative instruments on the consolidated balance sheets as derivative instruments under current assets, noncurrent assets, current liabilities and noncurrent liabilities on a gross basis. The Company determines the current and noncurrent classification based on the timing of expected future cash flows of individual trades. The following table presents the fair value of the Company's derivative instruments on a gross basis at June 30, 2016 : (In thousands) Short-term derivative instruments - asset $ 44,672 Long-term derivative instruments - asset $ 14,644 Short-term derivative instruments - liability $ 49,906 Long-term derivative instruments - liability $ 29,269 Gains and Losses For derivatives designated as cash flow hedges and meeting the effectiveness guidelines of FASB ASC 815, changes in fair value are recognized in accumulated other comprehensive income (loss) until the hedged item is recognized in earnings. The Company has no cash flow hedges in place for the three months ended June 30, 2016 and 2015 , as all fixed price swaps, swaptions and basis swaps had either been deemed ineffective at their inception or had been accounted for using the mark-to-market accounting method. The following table presents the net gain and loss recognized in gas sales, oil and condensate sales and natural gas liquids sales in the accompanying consolidated statements of operations for the three and six months ended June 30, 2016 and 2015 . Net (loss) gain on derivative instruments Three months ended June 30, Six months ended June 30, 2016 2015 2016 2015 (In thousands) Gas sales $ (133,621 ) $ (8,087 ) $ (76,621 ) $ 38,453 Oil and condensate sales (2,628 ) (1,995 ) (1,346 ) 1,569 Natural gas liquids sales (1,143 ) — (1,690 ) — Total net (loss) gain $ (137,392 ) $ (10,082 ) $ (79,657 ) $ 40,022 Concentration of Credit Risk By using derivative instruments that are not traded on an exchange, the Company is exposed to the credit risk of its counterparties. Credit risk is the risk of loss from counterparties not performing under the terms of the derivative instrument. When the fair value of a derivative instrument is positive, the counterparty is expected to owe the Company, which creates credit risk. To minimize the credit risk in derivative instruments, it is the Company's policy to enter into derivative contracts only with counterparties that are creditworthy financial institutions deemed by management as competent and competitive market makers. The Company's derivative contracts are with multiple counterparties to lessen its exposure to any individual counterparty. Additionally, the Company uses master netting agreements to minimize credit risk exposure. The creditworthiness of the Company's counterparties is subject to periodic review. Other than as provided by the Company's revolving credit facility, the Company is not required to provide credit support or collateral to any of its counterparties under its derivative instruments, nor are the counterparties required to provide credit support to the Company.

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurements	FAIR VALUE MEASUREMENTS The Company records certain financial and non-financial assets and liabilities on the balance sheet at fair value in accordance with FASB ASC 820, "Fair Value Measurement and Disclosures" ("FASB ASC 820"). FASB ASC 820 defines fair value as the price that would be received to sell an asset or paid to transfer a liability (exit price) in an orderly transaction between market participants at the measurement date. The statement establishes market or observable inputs as the preferred sources of values, followed by assumptions based on hypothetical transactions in the absence of market inputs. The statement requires fair value measurements be classified and disclosed in one of the following categories: Level 1 – Quoted prices in active markets for identical assets and liabilities. Level 2 – Quoted prices in active markets for similar assets and liabilities, quoted prices for identical or similar instruments in markets that are not active and model-derived valuations whose inputs are observable or whose significant value drivers are observable. Level 3 – Significant inputs to the valuation model are unobservable. Valuation techniques that maximize the use of observable inputs are favored. Financial assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement. The assessment of the significance of a particular input to the fair value measurement requires judgment and may affect the placement of assets and liabilities within the levels of the fair value hierarchy. Reclassifications of fair value between Level 1, Level 2 and Level 3 of the fair value hierarchy, if applicable, are made at the end of each quarter. The following tables summarize the Company’s financial and non-financial assets and liabilities by FASB ASC 820 valuation level as of June 30, 2016 : June 30, 2016 Level 1 Level 2 Level 3 (In thousands) Assets: Derivative Instruments $ — $ 59,316 $ — Liabilities: Derivative Instruments $ — $ 79,175 $ — The Company estimates the fair value of all derivative instruments industry-standard models that considered various assumptions including current market and contractual prices for the underlying instruments, implied volatility, time value, nonperformance risk, as well as other relevant economic measures. Substantially all of these inputs are observable in the marketplace throughout the full term of the instrument and can be supported by observable data. The estimated fair values of proved oil and gas properties assumed in business combinations are based on a discounted cash flow model and market assumptions as to future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development and operating costs, projections of future rates of production, expected recovery rates and risk-adjusted discount rates. The estimated fair values of unevaluated oil and gas properties was based on geological studies, historical well performance, location and applicable mineral lease terms. Based on the unobservable nature of certain of the inputs, the estimated fair value of the oil and gas properties assumed is deemed to use Level 3 inputs. See Note 1 for further discussion of the Company's acquisitions. The Company estimates asset retirement obligations pursuant to the provisions of FASB ASC Topic 410, Asset Retirement and Environmental Obligations (“FASB ASC 410”). The initial measurement of asset retirement obligations at fair value is calculated using discounted cash flow techniques and based on internal estimates of future retirement costs associated with oil and gas properties. Given the unobservable nature of the inputs, including plugging costs and reserve lives, the initial measurement of the asset retirement obligation liability is deemed to use Level 3 inputs. See Note 2 for further discussion of the Company’s asset retirement obligations. Asset retirement obligations incurred during the six months ended June 30, 2016 were approximately $3.2 million . Due to the unobservable nature of the inputs, the fair value of the Company's investment in Grizzly was estimated using assumptions that represent Level 3 inputs. The Company estimated the fair value of the investment as of March 31, 2016 to be approximately $39.1 million . See Note 3 for further discussion of the Company's investment in Grizzly. Due to the unobservable nature of the inputs, the fair value of the Company's investment in Strike Force was estimated using assumptions that represent Level 3 inputs. The Company's estimated fair value of the investment as of the February 1, 2016 contribution date was $22.5 million . See Note 3 for further discussion of the Company's contribution to Strike Force.

Fair Value Of Financial Instrum

Fair Value Of Financial Instruments	6 Months Ended
	Jun. 30, 2016
Investments, All Other Investments [Abstract]
Fair Value Of Financial Instruments	FAIR VALUE OF FINANCIAL INSTRUMENTS The carrying amounts on the accompanying consolidated balance sheet for cash and cash equivalents, accounts receivable, accounts payable and accrued liabilities, and current debt are carried at cost, which approximates market value due to their short-term nature. Long-term debt related to the Construction Loan is carried at cost, which approximates market value based on the borrowing rates currently available to the Company with similar terms and maturities. At June 30, 2016 , the carrying value of the outstanding debt represented by the Notes was approximately $944.8 million , including the remaining unamortized discount of approximately $2.3 million related to the October Notes, the remaining unamortized premium of approximately $ 0.3 million related to the December Notes and $13.3 million related to the August Notes. Also, included in the carrying value of the Notes is unamortized debt issuance cost of approximately $4.6 million related to the October Notes, approximately $1.0 million related to the December Notes, approximately $4.5 million related to the August Notes and approximately $6.4 million related to the 2023 Notes. Based on the quoted market price, the fair value of the Notes was determined to be approximately $960.4 million at June 30, 2016 .

Condensed Consolidating Financi

Condensed Consolidating Financial Information	6 Months Ended
	Jun. 30, 2016
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed Consolidating Financial Information	CONDENSED CONSOLIDATING FINANCIAL INFORMATION On October 17, 2012, December 21, 2012 and August 18, 2014, the Company issued an aggregate of $600.0 million principal amount of its 7.75% Senior Notes. The October Notes, December Notes, and the August Notes are collectively referred to as the "2020 Notes". The 2020 Notes are guaranteed on a senior unsecured basis by all existing consolidated subsidiaries that guarantee the Company's secured revolving credit facility or certain other debt (the "Guarantors"). The 2020 Notes are not guaranteed by Grizzly Holdings, Inc. (the "Non-Guarantor"). The Guarantors are 100% owned by Gulfport (the "Parent"), and the guarantees are full, unconditional, joint and several. There are no significant restrictions on the ability of the Parent or the Guarantors to obtain funds from each other in the form of a dividend or loan. In connection with the issuance of the 2020 Notes, the Company and the subsidiary guarantors entered into registration rights agreements with the initial purchasers, pursuant to which the Company and the subsidiary guarantors agreed to file a registration statement with respect to an offer to exchange the 2020 Notes for a new issue of substantially identical debt securities registered under the Securities Act. The exchange offer for the October Notes and December Notes was completed in October 2013 and the exchange offer for the August Notes was completed in March 2015. On April 21, 2015, the Company issued $350.0 million in aggregate principal amount of 6.625% Senior Notes due 2023 to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to certain non-U.S. persons in accordance with Regulation S under the Securities Act. In connection with the 2023 Notes Offering, the Company and its subsidiary guarantors entered into a registration rights agreement, dated as of April 21, 2015, pursuant to which the Company agreed to file a registration statement with respect to an offer to exchange the 2023 Notes for a new issue of substantially identical debt securities registered under the Securities Act. The exchange offer for the 2023 Notes was completed on October 13, 2015. The following condensed consolidating balance sheets, statements of operations, statements of comprehensive (loss) income and statements of cash flows are provided for the Parent, the Guarantors and the Non-Guarantor and include the consolidating adjustments and eliminations necessary to arrive at the information for the Company on a condensed consolidated basis. The information has been presented using the equity method of accounting for the Parent's ownership of the Guarantors and the Non-Guarantor. CONDENSED CONSOLIDATING BALANCE SHEETS (Amounts in thousands) June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 395,703 $ 733 $ 1 $ — $ 396,437 Accounts receivable - oil and gas 90,758 7,721 — (7,017 ) 91,462 Accounts receivable - related parties 23 — — — 23 Accounts receivable - intercompany 355,924 1,904 — (357,828 ) — Prepaid expenses and other current assets 7,782 — — — 7,782 Short-term derivative instruments 44,672 — — — 44,672 Deferred tax asset 292 — — — 292 Total current assets 895,154 10,358 1 (364,845 ) 540,668 Property and equipment: Oil and natural gas properties, full-cost accounting 5,334,096 352,821 — (729 ) 5,686,188 Other property and equipment 48,064 43 — — 48,107 Accumulated depletion, depreciation, amortization and impairment (3,339,056 ) (31 ) — — (3,339,087 ) Property and equipment, net 2,043,104 352,833 — (729 ) 2,395,208 Other assets: Equity investments 242,627 25,441 49,557 (64,578 ) 253,047 Long-term derivative instruments 14,644 — — — 14,644 Deferred tax asset 24,284 — — — 24,284 Other assets 11,336 — — — 11,336 Total other assets 292,891 25,441 49,557 (64,578 ) 303,311 Total assets $ 3,231,149 $ 388,632 $ 49,558 $ (430,152 ) $ 3,239,187 Liabilities and Stockholders' Equity Current liabilities: Accounts payable and accrued liabilities $ 281,712 $ 16,768 $ — $ (8,730 ) $ 289,750 Accounts payable - intercompany — 355,991 125 (356,116 ) — Asset retirement obligation - current 75 — — — 75 Short-term derivative instruments 49,906 — — — 49,906 Total current liabilities 331,693 372,759 125 (364,846 ) 339,731 Long-term derivative instrument 29,269 — — — 29,269 Asset retirement obligation - long-term 29,993 — — — 29,993 Long-term debt 956,754 — — — 956,754 Total liabilities 1,347,709 372,759 125 (364,846 ) 1,355,747 Stockholders' equity: Common stock 1,253 — — — 1,253 Paid-in capital 3,242,404 25,822 255,244 (281,066 ) 3,242,404 Accumulated other comprehensive (loss) income (46,803 ) — (45,507 ) 45,507 (46,803 ) Retained (deficit) earnings (1,313,414 ) (9,949 ) (160,304 ) 170,253 (1,313,414 ) Total stockholders' equity 1,883,440 15,873 49,433 (65,306 ) 1,883,440 Total liabilities and stockholders' equity $ 3,231,149 $ 388,632 $ 49,558 $ (430,152 ) $ 3,239,187 CONDENSED CONSOLIDATING BALANCE SHEETS (Amounts in thousands) December 31, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 112,494 $ 479 $ 1 $ — $ 112,974 Accounts receivable - oil and gas 72,241 54 — (423 ) 71,872 Accounts receivable - related parties 16 — — — 16 Accounts receivable - intercompany 326,475 60 — (326,535 ) — Prepaid expenses and other current assets 3,905 — — — 3,905 Short-term derivative instruments 142,794 — — — 142,794 Total current assets 657,925 593 1 (326,958 ) 331,561 Property and equipment: Oil and natural gas properties, full-cost accounting, 5,108,258 316,813 — (729 ) 5,424,342 Other property and equipment 33,128 43 — — 33,171 Accumulated depletion, depreciation, amortization and impairment (2,829,081 ) (29 ) — — (2,829,110 ) Property and equipment, net 2,312,305 316,827 — (729 ) 2,628,403 Other assets: Equity investments 231,892 — 50,644 (40,143 ) 242,393 Long-term derivative instruments 51,088 — — — 51,088 Deferred tax assets 74,925 — — — 74,925 Other assets 6,364 — — — 6,364 Total other assets 364,269 — 50,644 (40,143 ) 374,770 Total assets $ 3,334,499 $ 317,420 $ 50,645 $ (367,830 ) $ 3,334,734 Liabilities and Stockholders' Equity Current liabilities: Accounts payable and accrued liabilities $ 264,893 $ 527 $ — $ (292 ) $ 265,128 Accounts payable - intercompany 326,541 124 (326,665 ) — Asset retirement obligation - current 75 — — — — 75 Short-term derivative instruments 437 — — — 437 Deferred tax liability 50,697 — — — 50,697 Current maturities of long-term debt 179 — — — 179 Total current liabilities 316,281 327,068 124 (326,957 ) 316,516 Long-term derivative instrument 6,935 — — — 6,935 Asset retirement obligation - long-term 26,362 — — — 26,362 Long-term debt, net of current maturities 946,084 — — — 946,084 Total liabilities 1,295,662 327,068 124 (326,957 ) 1,295,897 Stockholders' equity: Common stock 1,082 — — — 1,082 Paid-in capital 2,824,303 322 241,553 (241,875 ) 2,824,303 Accumulated other comprehensive (loss) income (55,177 ) — (55,177 ) 55,177 (55,177 ) Retained (deficit) earnings (731,371 ) (9,970 ) (135,855 ) 145,825 (731,371 ) Total stockholders' equity 2,038,837 (9,648 ) 50,521 (40,873 ) 2,038,837 Total liabilities and stockholders' equity $ 3,334,499 $ 317,420 $ 50,645 $ (367,830 ) $ 3,334,734 CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Three months ended June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ (28,580 ) $ 428 $ — $ — $ (28,152 ) Costs and expenses: Lease operating expenses 14,491 170 — — 14,661 Production taxes 2,828 28 — — 2,856 Midstream gathering and processing 39,242 107 — — 39,349 Depreciation, depletion, and amortization 55,651 1 — — 55,652 Impairment of oil and gas properties 170,621 — — — 170,621 General and administrative 11,846 8 — — 11,854 Accretion expense 261 — — — 261 294,940 314 — — 295,254 (LOSS) INCOME FROM OPERATIONS (323,520 ) 114 — — (323,406 ) OTHER (INCOME) EXPENSE: Interest expense 16,082 — — — 16,082 Interest income (391 ) — — — (391 ) Loss (income) from equity method investments and investments in subsidiaries 722 59 762 (707 ) 836 16,413 59 762 (707 ) 16,527 (LOSS) INCOME BEFORE INCOME TAXES (339,933 ) 55 (762 ) 707 (339,933 ) INCOME TAX BENEFIT (157 ) — — — (157 ) NET (LOSS) INCOME $ (339,776 ) $ 55 $ (762 ) $ 707 $ (339,776 ) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Three months ended June 30, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ 112,027 $ 243 $ — $ — $ 112,270 Costs and expenses: Lease operating expenses 16,685 178 — — 16,863 Production taxes 3,260 25 — — 3,285 Midstream gathering and processing 32,892 12 — — 32,904 Depreciation, depletion, and amortization 71,154 1 — — 71,155 General and administrative 9,488 5 22 — 9,515 Accretion expense 192 — — — 192 133,671 221 22 — 133,914 (LOSS) INCOME FROM OPERATIONS (21,644 ) 22 (22 ) — (21,644 ) OTHER (INCOME) EXPENSE: Interest expense 12,023 — — — 12,023 Interest income (248 ) — — — (248 ) Loss (income) from equity method investments and investments in subsidiaries 15,120 — 8,494 (8,494 ) 15,120 26,895 — 8,494 (8,494 ) 26,895 (LOSS) INCOME BEFORE INCOME TAXES (48,539 ) 22 (8,516 ) 8,494 (48,539 ) INCOME TAX BENEFIT (17,214 ) — — — (17,214 ) NET (LOSS) INCOME $ (31,325 ) $ 22 $ (8,516 ) $ 8,494 $ (31,325 ) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Six months ended June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ 128,171 $ 640 $ — $ — $ 128,811 Costs and expenses: Lease operating expenses 30,963 355 — — 31,318 Production taxes 5,915 52 — — 5,967 Midstream gathering and processing 76,865 136 — — 77,001 Depreciation, depletion, and amortization 121,127 2 121,129 Impairment of oil and gas properties 389,612 — — — 389,612 General and administrative 22,458 14 2 — 22,474 Accretion expense 508 — — — 508 647,448 559 2 — 648,009 (LOSS) INCOME FROM OPERATIONS (519,277 ) 81 (2 ) — (519,198 ) OTHER (INCOME) EXPENSE: Interest expense 32,104 1 — — 32,105 Interest income (485 ) — — — (485 ) Loss (income) from equity method investments and investments in subsidiaries 31,495 59 24,447 (24,428 ) 31,573 63,114 60 24,447 (24,428 ) 63,193 (LOSS) INCOME BEFORE INCOME TAXES (582,391 ) 21 (24,449 ) 24,428 (582,391 ) INCOME TAX BENEFIT (348 ) — — — (348 ) NET (LOSS) INCOME $ (582,043 ) $ 21 $ (24,449 ) $ 24,428 $ (582,043 ) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Six months ended June 30, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ 287,859 $ 728 $ — $ — $ 288,587 Costs and expenses: Lease operating expenses 33,472 371 — — 33,843 Production taxes 7,513 57 — — 7,570 Midstream gathering and processing 58,266 19 — — 58,285 Depreciation, depletion, and amortization 161,062 2 — — 161,064 General and administrative 20,249 41 24 — 20,314 Accretion expense 382 — — — 382 280,944 490 24 — 281,458 INCOME (LOSS) FROM OPERATIONS 6,915 238 (24 ) — 7,129 OTHER (INCOME) EXPENSE: Interest expense 20,782 — — — 20,782 Interest income (257 ) — — — (257 ) (Income) loss from equity method investments and investments in subsidiaries (5,069 ) — 12,636 (12,422 ) (4,855 ) 15,456 — 12,636 (12,422 ) 15,670 (LOSS) INCOME BEFORE INCOME TAXES (8,541 ) 238 (12,660 ) 12,422 (8,541 ) INCOME TAX BENEFIT (2,735 ) — — — (2,735 ) NET (LOSS) INCOME $ (5,806 ) $ 238 $ (12,660 ) $ 12,422 $ (5,806 ) CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE (LOSS) INCOME (Amounts in thousands) Three months ended June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Net (loss) income $ (339,776 ) $ 55 $ (762 ) $ 707 $ (339,776 ) Foreign currency translation adjustment (684 ) — (604 ) 604 (684 ) Other comprehensive (loss) income (684 ) — (604 ) 604 (684 ) Comprehensive (loss) income $ (340,460 ) $ 55 $ (1,366 ) $ 1,311 $ (340,460 ) Three months ended June 30, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Net (loss) income $ (31,325 ) $ 22 $ (8,516 ) $ 8,494 $ (31,325 ) Foreign currency translation adjustment 3,247 — 3,247 (3,247 ) 3,247 Other comprehensive income (loss) 3,247 — 3,247 (3,247 ) 3,247 Comprehensive (loss) income $ (28,078 ) $ 22 $ (5,269 ) $ 5,247 $ (28,078 ) Six months ended June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Net (loss) income $ (582,043 ) $ 21 $ (24,449 ) $ 24,428 $ (582,043 ) Foreign currency translation adjustment 8,374 — 9,669 (9,669 ) 8,374 Other comprehensive income (loss) 8,374 — 9,669 (9,669 ) 8,374 Comprehensive (loss) income $ (573,669 ) $ 21 $ (14,780 ) $ 14,759 $ (573,669 ) Six months ended June 30, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Net (loss) income $ (5,806 ) $ 238 $ (12,660 ) $ 12,422 $ (5,806 ) Foreign currency translation adjustment (11,737 ) — (11,737 ) 11,737 (11,737 ) Other comprehensive (loss) income (11,737 ) — (11,737 ) 11,737 (11,737 ) Comprehensive (loss) income $ (17,543 ) $ 238 $ (24,397 ) $ 24,159 $ (17,543 ) CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS (Amounts in thousands) Six months ended June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Net cash provided by operating activities $ 142,470 $ 254 $ — $ — $ 142,724 Net cash (used in) provided by investing activities (281,044 ) (25,500 ) (13,690 ) 39,190 (281,044 ) Net cash provided by (used in) financing activities 421,783 25,500 13,690 (39,190 ) 421,783 Net increase in cash and cash equivalents 283,209 254 — — 283,463 Cash and cash equivalents at beginning of period 112,494 479 1 — 112,974 Cash and cash equivalents at end of period $ 395,703 $ 733 $ 1 $ — $ 396,437 Six months ended June 30, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Net cash provided by (used in) operating activities $ 135,485 $ 3,389 $ (1 ) $ 1 $ 138,874 Net cash (used in) provided by investing activities (976,820 ) (2,946 ) (8,267 ) 8,267 (979,766 ) Net cash provided by (used in) financing activities 1,224,040 — 8,268 (8,268 ) 1,224,040 Net increase in cash and cash equivalents 382,705 443 — — 383,148 Cash and cash equivalents at beginning of period 141,535 804 1 — 142,340 Cash and cash equivalents at end of period $ 524,240 $ 1,247 $ 1 $ — $ 525,488

Recent Accounting Pronouncement

Recent Accounting Pronouncements	6 Months Ended
	Jun. 30, 2016
Accounting Changes and Error Corrections [Abstract]
Recent Accounting Pronouncements	RECENT ACCOUNTING PRONOUNCEMENTS In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2014-09, Revenue from Contracts with Customers , which supersedes the revenue recognition requirements in Topic 605, Revenue Recognition , and most industry-specific guidance. The core principle of the new standard is for the recognition of revenue to depict the transfer of goods or services to customers in amounts that reflect the payment to which the company expects to be entitled in exchange for those goods or services. The new standard will also result in enhanced revenue disclosures, provide guidance for transactions that were not previously addressed comprehensively and improve guidance for multiple-element arrangements. The ASU is effective for annual periods beginning after December 15, 2016, and interim periods within those years, using either a full or a modified retrospective application approach. In July 2015, the FASB decided to defer the effective date by one year (until 2018). The Company is in the process of evaluating the impact of this ASU on its consolidated financial statements. In August 2014, the FASB issued ASU No. 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40). The new guidance addresses management's responsibility to evaluate whether there is substantial doubt about an entity's ability to continue as a going concern and in certain circumstances to provide related footnote disclosures. The standard is effective for periods after December 15, 2016, with early adoption permitted. The Company does not believe that the adoption of this guidance will have a material impact on its consolidated financial statements. In April 2015, the FASB issued ASU No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysi s. This ASU provides additional guidance to reporting entities in evaluating whether certain legal entities, such as limited partnerships, limited liability corporation and securitization structure, should be consolidated. The ASU is considered to be an improvement on current accounting requirements as it reduces the number of existing consolidation models. The ASU is effective for annual and interim periods beginning in 2016 and is required to be adopted using a retrospective or modified retrospective approach, with early adoption permitted. The Company adopted this ASU on January 1, 2016. As a result, certain of the Company's equity investments were determined to be variable interest entites; however, the Company was not required to consolidate these investments. In April 2015, the FASB issued ASU No. 2015-03, Simplifying the Presentation of Debt Issuance Costs . To simplify the presentation of debt issuance costs, ASU 2015-03 requires that debt issuance costs be presented in the balance sheet as a direct deduction from the carrying amount of the debt liability, consistent with debt discounts. This guidance is effective for periods after December 15, 2015. The Company adopted this guidance effective December 31, 2015, and has reclassified $16.6 million and $17.9 million of debt issuance costs to offset long-term debt at June 30, 2016 and December 31, 2015 , respectively, as shown in Note 6. In September 2015, the FASB issued ASU No. 2015-16, Simplifying the Accounting for Measurement-Period Adjustments. The guidance eliminates the requirement to retrospectively adjust the financial statements for measurement-period adjustments that occur in periods after a business combination is consummated. Measurement period adjustments are calculated as if they were known at the acquisition date, but are recognized in the reporting period in which they are determined. Additional disclosures are required about the impact on current-period income statement line items of adjustments that would have been recognized in prior periods if the prior-period information had been revised. The guidance is effective for periods after December 15, 2015. The Company adopted this guidance in the first quarter of 2016 and there was no impact to its consolidated financial statements. In November 2015, the FASB issued ASU No. 2015-17, Balance Sheet Classification of Deferred Taxes (Topic 705) . Current guidance requires an entity to separate deferred income tax liabilities and assets into current and noncurrent amounts in a classified statement of financial position. Deferred tax liabilities and assets are classified as current or noncurrent based on the classification of the related asset or liability for financial reporting. Deferred tax liabilities and assets that are not related to an asset or liability for financial reporting are classified according to the expected reversal date of the temporary difference. To simplify the presentation of deferred income taxes, the amendments in this update require that deferred income tax liabilities and assets be classified as noncurrent in a classified statement of financial position. This guidance is effective for periods after December 15, 2016, with early adoption permitted. The Company is in the process of evaluating the impact of this guidance on its consolidated financial statements. In February 2016, the FASB issued ASU No. 2016-02, Leases . The guidance requires the lessee to recognize most leases on the balance sheet thereby resulting in the recognition of lease assets and liability for those leases currently classified as operating leases. The accounting for lessors is largely unchanged. The guidance is effective for periods after December 15, 2018, with early adoption permitted. The Company is in the process of evaluating the impact of this guidance on its consolidated financial statements. In March 2016, the FASB issued ASU No. 2016-05, Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships. The guidance was issued to clarify that change in the counterparty to a derivative instrument that had been designated as the hedging instrument under Topic 815, does not require designation of that hedging relationship provided that all other hedge accounting criteria continue to be met. This guidance is effective for periods after December 15, 2017, with early adoption permitted. The Company is in the process of evaluating the impact on its consolidated financial statements. The Company does not believe that the adoption of this guidance will have a material impact on its consolidated financial statements because all current derivative instruments are not designated for hedge accounting. In March 2016, the FASB issued ASU No. 2016-07, Equity Method and Joint Ventures. This guidance simplified current requirements by eliminating the need to retrospectively apply the equity method of accounting upon obtaining significant influence over an investment that it previously accounted for under the cost basis or at fair value. This guidance is effective for periods after December 15, 2016, with early adoption permitted. The Company is in the process of evaluating the impact on its consolidated financial statements. The Company does not believe that the adoption of this guidance will have a material impact on its consolidated financial statements because all current investments are accounted under the equity method investment. In March 2016, the FASB issued ASU No. 2016-09, Improvements to Employee Share-Based Payment Accounting . This guidance was intended to simplify the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities and classification on the statement of cash flows. This guidance is effective for periods after December 15, 2016, with early adoption permitted. The Company is in the process of evaluating the impact of this guidance on its consolidated financial statements. In May 2016, the FASB issued ASU No. 2016-11, Revenue Recognition and Derivatives and Hedging: Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting. This guidance rescinds SEC Staff Observer comments that are codified in Topic 606, Revenue Recognition, and Topic 932, Extractive Activities--Oil and Gas. This amendment is effective upon adoption of Topic 606. The Company is in the process of evaluating the impact of this guidance on its consolidated financial statements.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2016
Subsequent Events [Abstract]
Subsequent Events	SUBSEQUENT EVENTS None

Recent Accounting Pronounceme24

Recent Accounting Pronouncements (Policies)	6 Months Ended
	Jun. 30, 2016
Accounting Changes and Error Corrections [Abstract]
Recent Accounting Pronouncements	RECENT ACCOUNTING PRONOUNCEMENTS In May 2014, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") No. 2014-09, Revenue from Contracts with Customers , which supersedes the revenue recognition requirements in Topic 605, Revenue Recognition , and most industry-specific guidance. The core principle of the new standard is for the recognition of revenue to depict the transfer of goods or services to customers in amounts that reflect the payment to which the company expects to be entitled in exchange for those goods or services. The new standard will also result in enhanced revenue disclosures, provide guidance for transactions that were not previously addressed comprehensively and improve guidance for multiple-element arrangements. The ASU is effective for annual periods beginning after December 15, 2016, and interim periods within those years, using either a full or a modified retrospective application approach. In July 2015, the FASB decided to defer the effective date by one year (until 2018). The Company is in the process of evaluating the impact of this ASU on its consolidated financial statements. In August 2014, the FASB issued ASU No. 2014-15, Presentation of Financial Statements - Going Concern (Subtopic 205-40). The new guidance addresses management's responsibility to evaluate whether there is substantial doubt about an entity's ability to continue as a going concern and in certain circumstances to provide related footnote disclosures. The standard is effective for periods after December 15, 2016, with early adoption permitted. The Company does not believe that the adoption of this guidance will have a material impact on its consolidated financial statements. In April 2015, the FASB issued ASU No. 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysi s. This ASU provides additional guidance to reporting entities in evaluating whether certain legal entities, such as limited partnerships, limited liability corporation and securitization structure, should be consolidated. The ASU is considered to be an improvement on current accounting requirements as it reduces the number of existing consolidation models. The ASU is effective for annual and interim periods beginning in 2016 and is required to be adopted using a retrospective or modified retrospective approach, with early adoption permitted. The Company adopted this ASU on January 1, 2016. As a result, certain of the Company's equity investments were determined to be variable interest entites; however, the Company was not required to consolidate these investments. In April 2015, the FASB issued ASU No. 2015-03, Simplifying the Presentation of Debt Issuance Costs . To simplify the presentation of debt issuance costs, ASU 2015-03 requires that debt issuance costs be presented in the balance sheet as a direct deduction from the carrying amount of the debt liability, consistent with debt discounts. This guidance is effective for periods after December 15, 2015. The Company adopted this guidance effective December 31, 2015, and has reclassified $16.6 million and $17.9 million of debt issuance costs to offset long-term debt at June 30, 2016 and December 31, 2015 , respectively, as shown in Note 6. In September 2015, the FASB issued ASU No. 2015-16, Simplifying the Accounting for Measurement-Period Adjustments. The guidance eliminates the requirement to retrospectively adjust the financial statements for measurement-period adjustments that occur in periods after a business combination is consummated. Measurement period adjustments are calculated as if they were known at the acquisition date, but are recognized in the reporting period in which they are determined. Additional disclosures are required about the impact on current-period income statement line items of adjustments that would have been recognized in prior periods if the prior-period information had been revised. The guidance is effective for periods after December 15, 2015. The Company adopted this guidance in the first quarter of 2016 and there was no impact to its consolidated financial statements. In November 2015, the FASB issued ASU No. 2015-17, Balance Sheet Classification of Deferred Taxes (Topic 705) . Current guidance requires an entity to separate deferred income tax liabilities and assets into current and noncurrent amounts in a classified statement of financial position. Deferred tax liabilities and assets are classified as current or noncurrent based on the classification of the related asset or liability for financial reporting. Deferred tax liabilities and assets that are not related to an asset or liability for financial reporting are classified according to the expected reversal date of the temporary difference. To simplify the presentation of deferred income taxes, the amendments in this update require that deferred income tax liabilities and assets be classified as noncurrent in a classified statement of financial position. This guidance is effective for periods after December 15, 2016, with early adoption permitted. The Company is in the process of evaluating the impact of this guidance on its consolidated financial statements. In February 2016, the FASB issued ASU No. 2016-02, Leases . The guidance requires the lessee to recognize most leases on the balance sheet thereby resulting in the recognition of lease assets and liability for those leases currently classified as operating leases. The accounting for lessors is largely unchanged. The guidance is effective for periods after December 15, 2018, with early adoption permitted. The Company is in the process of evaluating the impact of this guidance on its consolidated financial statements. In March 2016, the FASB issued ASU No. 2016-05, Effect of Derivative Contract Novations on Existing Hedge Accounting Relationships. The guidance was issued to clarify that change in the counterparty to a derivative instrument that had been designated as the hedging instrument under Topic 815, does not require designation of that hedging relationship provided that all other hedge accounting criteria continue to be met. This guidance is effective for periods after December 15, 2017, with early adoption permitted. The Company is in the process of evaluating the impact on its consolidated financial statements. The Company does not believe that the adoption of this guidance will have a material impact on its consolidated financial statements because all current derivative instruments are not designated for hedge accounting. In March 2016, the FASB issued ASU No. 2016-07, Equity Method and Joint Ventures. This guidance simplified current requirements by eliminating the need to retrospectively apply the equity method of accounting upon obtaining significant influence over an investment that it previously accounted for under the cost basis or at fair value. This guidance is effective for periods after December 15, 2016, with early adoption permitted. The Company is in the process of evaluating the impact on its consolidated financial statements. The Company does not believe that the adoption of this guidance will have a material impact on its consolidated financial statements because all current investments are accounted under the equity method investment. In March 2016, the FASB issued ASU No. 2016-09, Improvements to Employee Share-Based Payment Accounting . This guidance was intended to simplify the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities and classification on the statement of cash flows. This guidance is effective for periods after December 15, 2016, with early adoption permitted. The Company is in the process of evaluating the impact of this guidance on its consolidated financial statements. In May 2016, the FASB issued ASU No. 2016-11, Revenue Recognition and Derivatives and Hedging: Rescission of SEC Guidance Because of Accounting Standards Updates 2014-09 and 2014-16 Pursuant to Staff Announcements at the March 3, 2016 EITF Meeting. This guidance rescinds SEC Staff Observer comments that are codified in Topic 606, Revenue Recognition, and Topic 932, Extractive Activities--Oil and Gas. This amendment is effective upon adoption of Topic 606. The Company is in the process of evaluating the impact of this guidance on its consolidated financial statements.

Acquisitions (Tables)

Acquisitions (Tables)	6 Months Ended
	Jun. 30, 2016
American Energy - Utica, LLC
Business Acquisition [Line Items]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The following table summarizes the consideration paid in the AEU Acquisition to acquire the properties and the fair value amount of the assets acquired as of June 12, 2015. Both the consideration paid and the fair value assigned to the assets is preliminary and subject to adjustment upon final closing. (In thousands) Consideration paid Cash, net of purchase price adjustments $ 405,029 Fair value of identifiable assets acquired Oil and natural gas properties Proved $ 70,804 Unevaluated 334,225 Fair value of net identifiable assets acquired $ 405,029

Property And Equipment (Tables)

Property And Equipment (Tables)	6 Months Ended
	Jun. 30, 2016
Property, Plant and Equipment [Abstract]
Schedule Of Property And Equipment	The major categories of property and equipment and related accumulated depletion, depreciation, amortization and impairment as of June 30, 2016 and December 31, 2015 are as follows: June 30, 2016 December 31, 2015 (In thousands) Oil and natural gas properties $ 5,686,188 $ 5,424,342 Office furniture and fixtures 13,139 12,589 Building 31,301 16,915 Land 3,667 3,667 Total property and equipment 5,734,295 5,457,513 Accumulated depletion, depreciation, amortization and impairment (3,339,087 ) (2,829,110 ) Property and equipment, net $ 2,395,208 $ 2,628,403
Summary Of Oil And Gas Properties Not Subject To Amortization	The following table summarizes the Company’s non-producing properties excluded from amortization by area at June 30, 2016 : June 30, 2016 (In thousands) Utica $ 1,757,014 Niobrara 4,853 Southern Louisiana 431 Bakken 96 Other 45 $ 1,762,439
Schedule Of Asset Retirement Obligation	A reconciliation of the Company's asset retirement obligation for the six months ended June 30, 2016 and 2015 is as follows: June 30, 2016 June 30, 2015 (In thousands) Asset retirement obligation, beginning of period $ 26,437 $ 17,938 Liabilities incurred 3,195 4,077 Liabilities settled (72 ) (1,120 ) Accretion expense 508 382 Asset retirement obligation as of end of period 30,068 21,277 Less current portion 75 75 Asset retirement obligation, long-term $ 29,993 $ 21,202

Equity Investments (Tables)

Equity Investments (Tables)	6 Months Ended
	Jun. 30, 2016
Equity Method Investments and Joint Ventures [Abstract]
Investments Accounted For By The Equity Method	Investments accounted for by the equity method consist of the following as of June 30, 2016 and December 31, 2015 : Carrying value Loss (income) from equity method investments Approximate ownership % June 30, 2016 December 31, 2015 Three months ended June 30, Six months ended June 30, 2016 2015 2016 2015 (In thousands) Investment in Tatex Thailand II, LLC 23.5 % $ — $ — $ — $ — $ (159 ) $ — Investment in Tatex Thailand III, LLC 17.9 % — — — 189 — 189 Investment in Grizzly Oil Sands ULC 24.9999 % 49,556 50,645 763 8,494 24,448 12,636 Investment in Timber Wolf Terminals LLC 50.0 % 996 999 1 7 4 13 Investment in Windsor Midstream LLC 22.5 % 26,147 27,955 (2,881 ) 881 (3,048 ) (17,906 ) Investment in Stingray Cementing LLC 50.0 % 2,359 2,487 78 105 108 172 Investment in Blackhawk Midstream LLC 48.5 % — — — — — (7,217 ) Investment in Stingray Energy Services LLC 50.0 % 4,981 5,908 139 311 641 321 Investment in Sturgeon Acquisitions LLC 25.0 % 22,258 22,769 134 (491 ) 511 (1,059 ) Investment in Mammoth Energy Partners LP 30.5 % 121,309 131,630 2,543 5,624 9,009 7,996 Investment in Strike Force Midstream LLC 25.0 % 25,441 — 59 — 59 — $ 253,047 $ 242,393 $ 836 $ 15,120 $ 31,573 $ (4,855 )
Equity Method Investment Balance Sheet Summary	The tables below summarize financial information for the Company's equity investments as of June 30, 2016 and December 31, 2015 . Summarized balance sheet information: June 30, 2016 December 31, 2015 (In thousands) Current assets $ 105,614 $ 105,537 Noncurrent assets $ 1,330,877 $ 1,293,925 Current liabilities $ 41,238 $ 56,559 Noncurrent liabilities $ 146,642 $ 155,995
Equity Method Investment Income Statement Summary	Summarized results of operations: Three months ended June 30, Six months ended June 30, 2016 2015 2016 2015 (In thousands) Gross revenue $ 86,732 $ 130,134 $ 130,039 $ 263,690 Net (loss) income $ (560 ) $ (45,246 ) $ (25,868 ) $ 45,422

Other Assets (Tables)

Other Assets (Tables)	6 Months Ended
	Jun. 30, 2016
Other Assets, Noncurrent Disclosure [Abstract]
Schedule Of Other Assets	Other assets consist of the following as of June 30, 2016 and December 31, 2015 : June 30, 2016 December 31, 2015 (In thousands) Plugging and abandonment escrow account on the WCBB properties (Note 10) $ 3,081 $ 3,089 Certificates of Deposit securing letter of credit 276 276 Prepaid drilling costs 5,404 58 Loan commitment fees 2,496 2,870 Deposits 34 34 Other 45 37 $ 11,336 $ 6,364

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2016
Long-term Debt, Unclassified [Abstract]
Break-Down of Long-Term Debt	Long-term debt consisted of the following items as of June 30, 2016 and December 31, 2015 : June 30, 2016 December 31, 2015 (In thousands) Revolving credit agreement (1) $ — $ — Building loan (2) — 1,653 7.75% senior unsecured notes due 2020 (3) 600,000 600,000 6.625% senior unsecured notes due 2023 (4) 350,000 350,000 Net unamortized original issue premium, net (5) 11,359 12,493 Net unamortized debt issuance costs (6) (16,567 ) (17,883 ) Construction loan (7) 11,962 — Less: current maturities of long term debt — (179 ) Debt reflected as long term $ 956,754 $ 946,084 The Company capitalized approximately $1.4 million and $3.0 million in interest expense to undeveloped oil and natural gas properties during the three and six months ended June 30, 2016 , respectively. The Company capitalized approximately $4.7 million and $8.4 million in interest expense to oil and natural gas properties during the three and six months ended June 30, 2015 , respectively. During the three and six months ended June 30, 2016 , the Company also capitalized approximately $0.4 million and $0.7 million , respectively, in interest expense related to building construction. (1) The Company has entered into a senior secured revolving credit facility, as amended, with The Bank of Nova Scotia, as the lead arranger and administrative agent and certain lenders from time to time party thereto. The credit agreement provides for a maximum facility amount of $1.5 billion and matures on June 6, 2018. On February 19, 2016, the Company further amended its revolving credit facility to, among other things, (a) increase the basket for unsecured debt issuances to $1.4 billion from $1.2 billion (of which $950 million was then outstanding), (b) reaffirm the Company’s borrowing base of $700.0 million , and (c) increase the percentage of projected oil and gas production that may be hedged by the Company during 2016. As of June 30, 2016 , no balance was outstanding under this revolving credit facility and total funds available for borrowing, after giving effect to an aggregate of $205.8 million of letters of credit, were $494.2 million . This facility is secured by substantially all of the Company's assets. The wholly-owned subsidiaries of the Company guarantee the obligations under the revolving credit facility. Advances under this revolving credit facility may be in the form of either base rate loans or eurodollar loans. The interest rate for base rate loans is equal to (1) the applicable rate, which ranges from 0.50% to 1.50% , plus (2) the highest of: (a) the federal funds rate plus 0.50% , (b) the rate of interest in effect for such day as publicly announced from time to time by agent as its “prime rate,” and (c) the eurodollar rate for an interest period of one month plus 1.00% . The interest rate for eurodollar loans is equal to (1) the applicable rate, which ranges from 1.50% to 2.50% , plus (2) the London interbank offered rate that appears on pages LIBOR01 or LIBOR02 of the Reuters screen that displays such rate for deposits in U.S. dollars, or, if such rate is not available, the rate as administered by ICE Benchmark Administration (or any other person that takes over administration of such rate) per annum equal to the offered rate on such other page or other service that displays an average London interbank offered rate as administered by ICE Benchmark Administration (or any other person that takes over the administration of such rate) for deposits in U.S. dollars, or, if such rate is not available, the average quotations for three major New York money center banks of whom the agent shall inquire as the “London Interbank Offered Rate” for deposits in U.S. dollars. The Company's revolving credit facility contains customary negative covenants including, but not limited to, restrictions on the Company's and its subsidiaries' ability to: incur indebtedness; grant liens; pay dividends and make other restricted payments; make investments; make fundamental changes; enter into swap contracts and forward sales contracts; dispose of assets; change the nature of their business; and enter into transactions with their affiliates. The negative covenants are subject to certain exceptions as specified in this revolving credit facility. The Company's revolving credit facility also contains certain affirmative covenants, including, but not limited to the following financial covenants: (1) the ratio of net funded debt to EBITDAX (net income, excluding (i) any non-cash revenue or expense associated with swap contracts resulting from ASC 815 and (ii) any cash or non-cash revenue or expense attributable to minority investment plus without duplication and, in the case of expenses, to the extent deducted from revenues in determining net income, the sum of (a) the aggregate amount of consolidated interest expense for such period, (b) the aggregate amount of income, franchise, capital or similar tax expense (other than ad valorem taxes) for such period, (c) all amounts attributable to depletion, depreciation, amortization and asset or goodwill impairment or writedown for such period, (d) all other non-cash charges, (e) exploration costs deducted in determining net income under successful efforts accounting, (f) actual cash distributions received from minority investments, (g) to the extent actually reimbursed by insurance, expenses with respect to liability on casualty events or business interruption, and (h) all reasonable transaction expenses related to dispositions and acquisitions of assets, investments and debt and equity offerings (provided that expenses related to any unsuccessful dispositions will be limited to $3.0 million in the aggregate) for a twelve-month period may not be greater than 4.00 to 1.00; and (2) the ratio of EBITDAX to interest expense for a twelve-month period may not be less than 3.00 to 1.00. The Company was in compliance with these financial covenants at June 30, 2016 . (2) In March 2011, the Company refinanced the $2.4 million then outstanding under its previous building loan for the office building it occupies in Oklahoma City, Oklahoma. This loan agreement, as subsequently amended, bore interest at the rate of 4.00% per annum, required monthly interest and principal payments of approximately $20,000 , was collateralized by the Oklahoma City office building and associated land and had a maturity date of December 2018. The Company paid the balance of the loan in full in February 2016. (3) On October 17, 2012, the Company issued $250.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "October Notes") under an indenture among the Company, its subsidiary guarantors and Wells Fargo Bank, National Association, as the trustee (the "senior note indenture"). On December 21, 2012, the Company issued an additional $50.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "December Notes") as additional securities under the senior note indenture. The Company used a portion of the net proceeds from the October Notes to repay all amounts outstanding at such time under its revolving credit facility. The Company used the remaining net proceeds of the October Notes and the net proceeds of the December Notes for general corporate purposes, which included funding a portion of its 2013 capital development plan. The October Notes and the December Notes were exchanged for substantially identical notes in the same aggregate principal amount that were registered under the Securities Act in October 2013 (the "Exchange Notes"). On August 18, 2014, the Company issued an additional $300.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "August Notes"). The August Notes were issued as additional securities under the senior note indenture. The Company used a portion of the net proceeds from the August Notes to repay all amounts outstanding at such time under its revolving credit facility. The Company used the remaining net proceeds of the August Notes Offering for general corporate purposes, including funding a portion of its 2014 and 2015 capital development plans. The October Notes, December Notes and the August Notes are collectively referred to as the "2020 Notes". In connection with the issuance of the 2020 Notes, the Company and the subsidiary guarantors entered into a registration rights agreement with the initial purchasers, pursuant to which the Company and the subsidiary guarantors agreed to file a registration statement with respect to an offering to exchange the 2020 Notes for a new issue of substantially identical debt securities registered under the Securities Act. The exchange offer for the October Notes and the December Notes was completed in October 2013 and the exchange offer for the August Note was completed in March 2015. Under the senior note indenture relating to the 2020 Notes, interest on the 2020 Notes accrues at a rate of 7.75% per annum on the outstanding principal amount from October 17, 2012, payable semi-annually on May 1 and November 1 of each year, commencing on May 1, 2013. The 2020 Notes are the Company's senior unsecured obligations and rank equally in the right of payment with all of the Company's other senior indebtedness and senior in right of payment to any future subordinated indebtedness. All of the Company's existing and future restricted subsidiaries that guarantee the Company's secured revolving credit facility or certain other debt guarantee the 2020 Notes; provided, however, that the 2020 Notes are not guaranteed by Grizzly Holdings, Inc. and will not be guaranteed by any of the Company's future unrestricted subsidiaries. The Company may redeem some or all of the 2020 Notes at any time on or after November 1, 2016, at the redemption prices listed in the senior note indenture. Prior to November 1, 2016, the Company may redeem the 2020 Notes at a price equal to 100% of the principal amount plus a “make-whole” premium. In addition, prior to November 1, 2015, the Company may redeem up to 35% of the aggregate principal amount of the 2020 Notes with the net proceeds of certain equity offerings, provided that at least 65% of the aggregate principal amount of the 2020 Notes initially issued remains outstanding immediately after such redemption. (4) On April 21, 2015, the Company issued $350.0 million in aggregate principal amount of 6.625% Senior Notes due 2023 (the "2023 Notes" and, together with the "2020 Notes," the "Notes") to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to certain non-U.S. persons in accordance with Regulation S under the Securities Act (the "2023 Notes Offering"). The Company received net proceeds of approximately $343.6 million after initial purchaser discounts and commissions and estimated offering expenses. The 2023 notes were issued under an indenture, dated as of April 21, 2015, among the Company, the subsidiary guarantors party thereto and Wells Fargo Bank, National Association, as trustee. Pursuant to the indenture relating to the 2023 Notes, interest on the 2023 Notes will accrue at a rate of 6.625% per annum on the outstanding principal amount thereof from April 21, 2015, payable semi-annually on May 1 and November 1 of each year, commencing on November 1, 2015. The 2023 Notes are not guaranteed by Grizzly Holdings, Inc. and will not be guaranteed by any of the Company's future unrestricted subsidiaries. In connection with the 2023 Notes Offering, the Company and its subsidiary guarantors entered into a registration rights agreement, dated as of April 21, 2015, pursuant to which the Company agreed to file a registration statement with respect to an offer to exchange the 2023 Notes for a new issue of substantially identical debt securities registered under the Securities Act. The exchange offer for the 2023 Notes was completed on October 13, 2015. (5) The October Notes were issued at a price of 98.534% resulting in a gross discount of $3.7 million and an effective rate of 8.000% . The December Notes were issued at a price of 101.000% resulting in a gross premium of $0.5 million and an effective rate of 7.531% . The August Notes were issued at a price of 106.000% resulting in a gross premium of $18.0 million and an effective rate of 6.561% . The April Notes were issued at par. The premium and discount are being amortized using the effective interest method. (6) In accordance with Accounting Standards Update ("ASU") 2015-03, loan issuance costs related to the Notes have been presented as a reduction to the Notes. At June 30, 2016 , total unamortized debt issuance costs were $4.6 million for the October Notes, $1.0 million for the December Notes, $4.5 million for the August Notes and $6.4 million for the April Notes. (7) On June 4, 2015, the Company entered into a construction loan agreement (the "Construction Loan") with InterBank for the construction of a new corporate headquarters in Oklahoma City. The Construction Loan allows for a maximum principal amount of $24.5 million and requires the Company to fund 30% of the estimated cost of the construction before any funds can be drawn, which occurred in January 2016. Interest accrues daily on the outstanding principal balance at a fixed rate of 4.50% per annum and is payable on the last day of the month through May 31, 2017. Monthly interest and principal payments are due beginning June 30, 2017, with the final payment due June 4, 2025. At June 30, 2016 , the total borrowings under the Construction Loan were approximately $12.0 million .

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	6 Months Ended
	Jun. 30, 2016
Share-based Compensation [Abstract]
Summary Of Restricted Stock Award And Unit Activity	The following table summarizes restricted stock activity for the six months ended June 30, 2016 : Number of Unvested Restricted Shares Weighted Average Grant Date Fair Value Unvested shares as of January 1, 2016 484,239 $ 43.51 Granted 255,204 27.71 Vested (137,916 ) 47.31 Forfeited (8,042 ) 34.76 Unvested shares as of June 30, 2016 593,485 $ 35.95

Earnings Per Share (Tables)

Earnings Per Share (Tables)	6 Months Ended
	Jun. 30, 2016
Earnings Per Share [Abstract]
Schedule of Earnings Per Share Reconciliation	Reconciliations of the components of basic and diluted net loss per common share are presented in the tables below: Three months ended June 30, 2016 2015 Loss Shares Per Share Loss Shares Per Share (In thousands, except share data) Basic: Net loss $ (339,776 ) 125,343,723 $ (2.71 ) $ (31,325 ) 96,663,358 $ (0.32 ) Effect of dilutive securities: Stock options and awards — — — — Diluted: Net loss $ (339,776 ) 125,343,723 $ (2.71 ) $ (31,325 ) 96,663,358 $ (0.32 ) Six months ended June 30, 2016 2015 Loss Shares Per Loss Shares Per (In thousands, except share data) Basic: Net loss $ (582,043 ) 118,426,654 $ (4.91 ) $ (5,806 ) 91,201,824 $ (0.06 ) Effect of dilutive securities: Stock options and awards — — — — Diluted: Net loss $ (582,043 ) 118,426,654 $ (4.91 ) $ (5,806 ) 91,201,824 $ (0.06 )

Commitments and Contingencies (

Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 2016
Commitments and Contingencies Disclosure [Abstract]
Schedule of Future Minimum Lease Commitments	Future minimum lease commitments under these leases at June 30, 2016 were as follows: (In thousands) Remaining 2016 $ 386 2017 583 2018 54 Total $ 1,023
Schedule of Future Commitment Payments	Future minimum commitments under these agreements at June 30, 2016 are as follows: (In thousands) Remaining 2016 $ 26,220 2017 52,440 2018 39,330 Total $ 117,990

Derivative Instruments (Tables)

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2016
General Discussion of Derivative Instruments and Hedging Activities [Abstract]
Schedule Of Derivative Instruments	Below is a summary of the Company's open fixed price swap positions as of June 30, 2016 . Location Daily Volume Weighted July 2016 - June 2017 ARGUS LLS 2,000 $ 51.10 Location Daily Volume (MMBtu/day) Weighted July 2016 NYMEX Henry Hub 550,000 $ 3.06 August 2016 - September 2016 NYMEX Henry Hub 560,000 $ 3.04 October 2016 NYMEX Henry Hub 570,000 $ 3.05 November 2016 - December 2016 NYMEX Henry Hub 525,000 $ 3.18 January 2017 - February 2017 NYMEX Henry Hub 442,500 $ 3.14 March 2017 NYMEX Henry Hub 422,500 $ 3.13 April 2017 - June 2017 NYMEX Henry Hub 367,500 $ 3.15 July 2017 - October 2017 NYMEX Henry Hub 305,000 $ 2.99 November 2017 - December 2017 NYMEX Henry Hub 385,000 $ 3.03 January 2018 - March 2018 NYMEX Henry Hub 240,000 $ 3.07 April 2018 - December 2018 NYMEX Henry Hub 160,000 $ 3.01 January 2019 - March 2019 NYMEX Henry Hub 20,000 $ 3.37 Location Daily Volume Weighted July 2016 - December 2016 Mont Belvieu 1,500 $ 19.95 The Company sold call options and used the associated premiums to enhance the fixed price for a portion of the fixed price natural gas swaps listed above. Each short call option has an established ceiling price. When the referenced settlement price is above the price ceiling established by these short call options, the Company pays its counterparty an amount equal to the difference between the referenced settlement price and the price ceiling multiplied by the hedged contract volume. Location Daily Volume (MMBtu/day) Weighted Average Price January 2017 - March 2017 NYMEX Henry Hub 105,000 $ 3.27 April 2017 - December 2017 NYMEX Henry Hub 125,000 $ 3.21 January 2018 - March 2018 NYMEX Henry Hub 20,000 $ 2.91 For a portion of the combined natural gas derivative instruments containing fixed price swaps and sold call options, the counterparty has an option to extend the original terms an additional twelve months for the period January 2017 through December 2017. The option to extend the terms expires in December 2016. If executed, the Company would have additional fixed price swaps for 30,000 MMBtu per day at a weighted average price of $3.33 per MMBtu and additional short call options for 30,000 MMBtu per day at a weighted average ceiling price of $3.33 per MMBtu. In addition, the Company has entered into natural gas basis swap positions, which settle on the pricing index to basis differential of MichCon or Tetco M2 to the NYMEX Henry Hub natural gas price. As of June 30, 2016 , the Company had the following natural gas basis swap positions for MichCon and Tetco M2, respectively. Location Daily Volume (MMBtu/day) Hedged Differential July 2016 - December 2016 MichCon 40,000 $ 0.02 November 2016 - March 2017 Tetco M2 50,000 $ (0.59 )
Schedule Of Derivative Instruments In Statement Of Financial Position	The following table presents the fair value of the Company's derivative instruments on a gross basis at June 30, 2016 : (In thousands) Short-term derivative instruments - asset $ 44,672 Long-term derivative instruments - asset $ 14,644 Short-term derivative instruments - liability $ 49,906 Long-term derivative instruments - liability $ 29,269
Derivative Instruments, Gain (Loss)	The following table presents the net gain and loss recognized in gas sales, oil and condensate sales and natural gas liquids sales in the accompanying consolidated statements of operations for the three and six months ended June 30, 2016 and 2015 . Net (loss) gain on derivative instruments Three months ended June 30, Six months ended June 30, 2016 2015 2016 2015 (In thousands) Gas sales $ (133,621 ) $ (8,087 ) $ (76,621 ) $ 38,453 Oil and condensate sales (2,628 ) (1,995 ) (1,346 ) 1,569 Natural gas liquids sales (1,143 ) — (1,690 ) — Total net (loss) gain $ (137,392 ) $ (10,082 ) $ (79,657 ) $ 40,022

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2016
Fair Value Disclosures [Abstract]
Fair Value Measurements	The following tables summarize the Company’s financial and non-financial assets and liabilities by FASB ASC 820 valuation level as of June 30, 2016 : June 30, 2016 Level 1 Level 2 Level 3 (In thousands) Assets: Derivative Instruments $ — $ 59,316 $ — Liabilities: Derivative Instruments $ — $ 79,175 $ —

Condensed Consolidating Finan35

Condensed Consolidating Financial Information (Tables)	6 Months Ended
	Jun. 30, 2016
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed Consolidating Balance Sheets	CONDENSED CONSOLIDATING BALANCE SHEETS (Amounts in thousands) June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 395,703 $ 733 $ 1 $ — $ 396,437 Accounts receivable - oil and gas 90,758 7,721 — (7,017 ) 91,462 Accounts receivable - related parties 23 — — — 23 Accounts receivable - intercompany 355,924 1,904 — (357,828 ) — Prepaid expenses and other current assets 7,782 — — — 7,782 Short-term derivative instruments 44,672 — — — 44,672 Deferred tax asset 292 — — — 292 Total current assets 895,154 10,358 1 (364,845 ) 540,668 Property and equipment: Oil and natural gas properties, full-cost accounting 5,334,096 352,821 — (729 ) 5,686,188 Other property and equipment 48,064 43 — — 48,107 Accumulated depletion, depreciation, amortization and impairment (3,339,056 ) (31 ) — — (3,339,087 ) Property and equipment, net 2,043,104 352,833 — (729 ) 2,395,208 Other assets: Equity investments 242,627 25,441 49,557 (64,578 ) 253,047 Long-term derivative instruments 14,644 — — — 14,644 Deferred tax asset 24,284 — — — 24,284 Other assets 11,336 — — — 11,336 Total other assets 292,891 25,441 49,557 (64,578 ) 303,311 Total assets $ 3,231,149 $ 388,632 $ 49,558 $ (430,152 ) $ 3,239,187 Liabilities and Stockholders' Equity Current liabilities: Accounts payable and accrued liabilities $ 281,712 $ 16,768 $ — $ (8,730 ) $ 289,750 Accounts payable - intercompany — 355,991 125 (356,116 ) — Asset retirement obligation - current 75 — — — 75 Short-term derivative instruments 49,906 — — — 49,906 Total current liabilities 331,693 372,759 125 (364,846 ) 339,731 Long-term derivative instrument 29,269 — — — 29,269 Asset retirement obligation - long-term 29,993 — — — 29,993 Long-term debt 956,754 — — — 956,754 Total liabilities 1,347,709 372,759 125 (364,846 ) 1,355,747 Stockholders' equity: Common stock 1,253 — — — 1,253 Paid-in capital 3,242,404 25,822 255,244 (281,066 ) 3,242,404 Accumulated other comprehensive (loss) income (46,803 ) — (45,507 ) 45,507 (46,803 ) Retained (deficit) earnings (1,313,414 ) (9,949 ) (160,304 ) 170,253 (1,313,414 ) Total stockholders' equity 1,883,440 15,873 49,433 (65,306 ) 1,883,440 Total liabilities and stockholders' equity $ 3,231,149 $ 388,632 $ 49,558 $ (430,152 ) $ 3,239,187 CONDENSED CONSOLIDATING BALANCE SHEETS (Amounts in thousands) December 31, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Assets Current assets: Cash and cash equivalents $ 112,494 $ 479 $ 1 $ — $ 112,974 Accounts receivable - oil and gas 72,241 54 — (423 ) 71,872 Accounts receivable - related parties 16 — — — 16 Accounts receivable - intercompany 326,475 60 — (326,535 ) — Prepaid expenses and other current assets 3,905 — — — 3,905 Short-term derivative instruments 142,794 — — — 142,794 Total current assets 657,925 593 1 (326,958 ) 331,561 Property and equipment: Oil and natural gas properties, full-cost accounting, 5,108,258 316,813 — (729 ) 5,424,342 Other property and equipment 33,128 43 — — 33,171 Accumulated depletion, depreciation, amortization and impairment (2,829,081 ) (29 ) — — (2,829,110 ) Property and equipment, net 2,312,305 316,827 — (729 ) 2,628,403 Other assets: Equity investments 231,892 — 50,644 (40,143 ) 242,393 Long-term derivative instruments 51,088 — — — 51,088 Deferred tax assets 74,925 — — — 74,925 Other assets 6,364 — — — 6,364 Total other assets 364,269 — 50,644 (40,143 ) 374,770 Total assets $ 3,334,499 $ 317,420 $ 50,645 $ (367,830 ) $ 3,334,734 Liabilities and Stockholders' Equity Current liabilities: Accounts payable and accrued liabilities $ 264,893 $ 527 $ — $ (292 ) $ 265,128 Accounts payable - intercompany 326,541 124 (326,665 ) — Asset retirement obligation - current 75 — — — — 75 Short-term derivative instruments 437 — — — 437 Deferred tax liability 50,697 — — — 50,697 Current maturities of long-term debt 179 — — — 179 Total current liabilities 316,281 327,068 124 (326,957 ) 316,516 Long-term derivative instrument 6,935 — — — 6,935 Asset retirement obligation - long-term 26,362 — — — 26,362 Long-term debt, net of current maturities 946,084 — — — 946,084 Total liabilities 1,295,662 327,068 124 (326,957 ) 1,295,897 Stockholders' equity: Common stock 1,082 — — — 1,082 Paid-in capital 2,824,303 322 241,553 (241,875 ) 2,824,303 Accumulated other comprehensive (loss) income (55,177 ) — (55,177 ) 55,177 (55,177 ) Retained (deficit) earnings (731,371 ) (9,970 ) (135,855 ) 145,825 (731,371 ) Total stockholders' equity 2,038,837 (9,648 ) 50,521 (40,873 ) 2,038,837 Total liabilities and stockholders' equity $ 3,334,499 $ 317,420 $ 50,645 $ (367,830 ) $ 3,334,734
Condensed Consolidating Statements of Operations	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Three months ended June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ (28,580 ) $ 428 $ — $ — $ (28,152 ) Costs and expenses: Lease operating expenses 14,491 170 — — 14,661 Production taxes 2,828 28 — — 2,856 Midstream gathering and processing 39,242 107 — — 39,349 Depreciation, depletion, and amortization 55,651 1 — — 55,652 Impairment of oil and gas properties 170,621 — — — 170,621 General and administrative 11,846 8 — — 11,854 Accretion expense 261 — — — 261 294,940 314 — — 295,254 (LOSS) INCOME FROM OPERATIONS (323,520 ) 114 — — (323,406 ) OTHER (INCOME) EXPENSE: Interest expense 16,082 — — — 16,082 Interest income (391 ) — — — (391 ) Loss (income) from equity method investments and investments in subsidiaries 722 59 762 (707 ) 836 16,413 59 762 (707 ) 16,527 (LOSS) INCOME BEFORE INCOME TAXES (339,933 ) 55 (762 ) 707 (339,933 ) INCOME TAX BENEFIT (157 ) — — — (157 ) NET (LOSS) INCOME $ (339,776 ) $ 55 $ (762 ) $ 707 $ (339,776 ) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Three months ended June 30, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ 112,027 $ 243 $ — $ — $ 112,270 Costs and expenses: Lease operating expenses 16,685 178 — — 16,863 Production taxes 3,260 25 — — 3,285 Midstream gathering and processing 32,892 12 — — 32,904 Depreciation, depletion, and amortization 71,154 1 — — 71,155 General and administrative 9,488 5 22 — 9,515 Accretion expense 192 — — — 192 133,671 221 22 — 133,914 (LOSS) INCOME FROM OPERATIONS (21,644 ) 22 (22 ) — (21,644 ) OTHER (INCOME) EXPENSE: Interest expense 12,023 — — — 12,023 Interest income (248 ) — — — (248 ) Loss (income) from equity method investments and investments in subsidiaries 15,120 — 8,494 (8,494 ) 15,120 26,895 — 8,494 (8,494 ) 26,895 (LOSS) INCOME BEFORE INCOME TAXES (48,539 ) 22 (8,516 ) 8,494 (48,539 ) INCOME TAX BENEFIT (17,214 ) — — — (17,214 ) NET (LOSS) INCOME $ (31,325 ) $ 22 $ (8,516 ) $ 8,494 $ (31,325 ) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Six months ended June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ 128,171 $ 640 $ — $ — $ 128,811 Costs and expenses: Lease operating expenses 30,963 355 — — 31,318 Production taxes 5,915 52 — — 5,967 Midstream gathering and processing 76,865 136 — — 77,001 Depreciation, depletion, and amortization 121,127 2 121,129 Impairment of oil and gas properties 389,612 — — — 389,612 General and administrative 22,458 14 2 — 22,474 Accretion expense 508 — — — 508 647,448 559 2 — 648,009 (LOSS) INCOME FROM OPERATIONS (519,277 ) 81 (2 ) — (519,198 ) OTHER (INCOME) EXPENSE: Interest expense 32,104 1 — — 32,105 Interest income (485 ) — — — (485 ) Loss (income) from equity method investments and investments in subsidiaries 31,495 59 24,447 (24,428 ) 31,573 63,114 60 24,447 (24,428 ) 63,193 (LOSS) INCOME BEFORE INCOME TAXES (582,391 ) 21 (24,449 ) 24,428 (582,391 ) INCOME TAX BENEFIT (348 ) — — — (348 ) NET (LOSS) INCOME $ (582,043 ) $ 21 $ (24,449 ) $ 24,428 $ (582,043 ) CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS (Amounts in thousands) Six months ended June 30, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Total revenues $ 287,859 $ 728 $ — $ — $ 288,587 Costs and expenses: Lease operating expenses 33,472 371 — — 33,843 Production taxes 7,513 57 — — 7,570 Midstream gathering and processing 58,266 19 — — 58,285 Depreciation, depletion, and amortization 161,062 2 — — 161,064 General and administrative 20,249 41 24 — 20,314 Accretion expense 382 — — — 382 280,944 490 24 — 281,458 INCOME (LOSS) FROM OPERATIONS 6,915 238 (24 ) — 7,129 OTHER (INCOME) EXPENSE: Interest expense 20,782 — — — 20,782 Interest income (257 ) — — — (257 ) (Income) loss from equity method investments and investments in subsidiaries (5,069 ) — 12,636 (12,422 ) (4,855 ) 15,456 — 12,636 (12,422 ) 15,670 (LOSS) INCOME BEFORE INCOME TAXES (8,541 ) 238 (12,660 ) 12,422 (8,541 ) INCOME TAX BENEFIT (2,735 ) — — — (2,735 ) NET (LOSS) INCOME $ (5,806 ) $ 238 $ (12,660 ) $ 12,422 $ (5,806 )
Condensed Consolidating Statements of Comprehensive Income (Loss)	CONDENSED CONSOLIDATING STATEMENTS OF COMPREHENSIVE (LOSS) INCOME (Amounts in thousands) Three months ended June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Net (loss) income $ (339,776 ) $ 55 $ (762 ) $ 707 $ (339,776 ) Foreign currency translation adjustment (684 ) — (604 ) 604 (684 ) Other comprehensive (loss) income (684 ) — (604 ) 604 (684 ) Comprehensive (loss) income $ (340,460 ) $ 55 $ (1,366 ) $ 1,311 $ (340,460 ) Three months ended June 30, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Net (loss) income $ (31,325 ) $ 22 $ (8,516 ) $ 8,494 $ (31,325 ) Foreign currency translation adjustment 3,247 — 3,247 (3,247 ) 3,247 Other comprehensive income (loss) 3,247 — 3,247 (3,247 ) 3,247 Comprehensive (loss) income $ (28,078 ) $ 22 $ (5,269 ) $ 5,247 $ (28,078 ) Six months ended June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Net (loss) income $ (582,043 ) $ 21 $ (24,449 ) $ 24,428 $ (582,043 ) Foreign currency translation adjustment 8,374 — 9,669 (9,669 ) 8,374 Other comprehensive income (loss) 8,374 — 9,669 (9,669 ) 8,374 Comprehensive (loss) income $ (573,669 ) $ 21 $ (14,780 ) $ 14,759 $ (573,669 ) Six months ended June 30, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Net (loss) income $ (5,806 ) $ 238 $ (12,660 ) $ 12,422 $ (5,806 ) Foreign currency translation adjustment (11,737 ) — (11,737 ) 11,737 (11,737 ) Other comprehensive (loss) income (11,737 ) — (11,737 ) 11,737 (11,737 ) Comprehensive (loss) income $ (17,543 ) $ 238 $ (24,397 ) $ 24,159 $ (17,543 )
Condensed Consolidating Statements of Cash Flows	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS (Amounts in thousands) Six months ended June 30, 2016 Parent Guarantors Non-Guarantor Eliminations Consolidated Net cash provided by operating activities $ 142,470 $ 254 $ — $ — $ 142,724 Net cash (used in) provided by investing activities (281,044 ) (25,500 ) (13,690 ) 39,190 (281,044 ) Net cash provided by (used in) financing activities 421,783 25,500 13,690 (39,190 ) 421,783 Net increase in cash and cash equivalents 283,209 254 — — 283,463 Cash and cash equivalents at beginning of period 112,494 479 1 — 112,974 Cash and cash equivalents at end of period $ 395,703 $ 733 $ 1 $ — $ 396,437 Six months ended June 30, 2015 Parent Guarantors Non-Guarantor Eliminations Consolidated Net cash provided by (used in) operating activities $ 135,485 $ 3,389 $ (1 ) $ 1 $ 138,874 Net cash (used in) provided by investing activities (976,820 ) (2,946 ) (8,267 ) 8,267 (979,766 ) Net cash provided by (used in) financing activities 1,224,040 — 8,268 (8,268 ) 1,224,040 Net increase in cash and cash equivalents 382,705 443 — — 383,148 Cash and cash equivalents at beginning of period 141,535 804 1 — 142,340 Cash and cash equivalents at end of period $ 524,240 $ 1,247 $ 1 $ — $ 525,488

Acquisitions (Details)

Acquisitions (Details) $ in Thousands	Aug. 31, 2015USD ($)	Jun. 29, 2015USD ($)a	Jun. 12, 2015USD ($)awellmiMMcf	Jun. 09, 2015USD ($)a	Dec. 31, 2015USD ($)	Jun. 29, 2015USD ($)a	Apr. 30, 2015USD ($)a	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)
Business Acquisition [Line Items]
Increase (decrease) in restricted cash								$ 0	$ (75,005)
Paloma Partners III, LLC
Business Acquisition [Line Items]
Purchase price	$ 302,300						$ 301,900
Gas and oil acreage, net | a							24,000
Amount put in escrow	$ 30,100						$ 75,000
American Energy - Utica, LLC
Business Acquisition [Line Items]
Purchase price						$ 405,400
Amount put in escrow				$ 67,100
Increase (decrease) in restricted cash					$ 2,400
Cash, net of purchase price adjustments		$ 405,000	$ 405,029
Fair value of net identifiable assets acquired			405,029
American Energy - Utica, LLC | Proved
Business Acquisition [Line Items]
Fair value of net identifiable assets acquired			70,804
American Energy - Utica, LLC | Unevaluated
Business Acquisition [Line Items]
Fair value of net identifiable assets acquired			334,225
Belmont And Jefferson Counties, Ohio | American Energy - Utica, LLC
Business Acquisition [Line Items]
Purchase price				$ 68,200
Gross and net acres acquired | a				6,198
Monroe County, Ohio | American Energy - Utica, LLC
Business Acquisition [Line Items]
Purchase price		$ 18,200	$ 319,000
Gas and oil acreage, net | a		1,900	27,228			1,900
Gas and oil acreage, gross | a		4,950	38,965			4,950
Daily production of well acquired | MMcf			14.6
Gross wells acquired | well			18
Net wells acquired | well			11.3
Gas gathering system (in miles) | mi			11
Number of well pad locations acquired | well			4

Property And Equipment (Schedul

Property And Equipment (Schedule Of Property And Equipment) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Property, Plant and Equipment [Abstract]
Oil and natural gas properties	$ 5,686,188	$ 5,424,342
Office furniture and fixtures	13,139	12,589
Building	31,301	16,915
Land	3,667	3,667
Total property and equipment	5,734,295	5,457,513
Accumulated depletion, depreciation, amortization and impairment	(3,339,087)	(2,829,110)
Property and equipment, net	$ 2,395,208	$ 2,628,403

Property And Equipment (Narrati

Property And Equipment (Narrative) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Property, Plant and Equipment [Line Items]
Impairment of oil and gas properties	$ 170,621,000	$ 0	$ 389,612,000	$ 0
Cumulative capitalization of general and administrative costs incurred and capitalized to the full cost pool	115,600,000		115,600,000
Capitalized general and administrative costs	7,900,000	$ 6,300,000	15,000,000	$ 13,500,000
Capitalized costs of oil and natural gas properties excluded from amortization	$ 1,762,439,000		$ 1,762,439,000		$ 1,817,701,000
Minimum
Property, Plant and Equipment [Line Items]
Expected number of years amortization will commence			3 years
Maximum
Property, Plant and Equipment [Line Items]
Expected number of years amortization will commence			5 years

Property And Equipment (Summary

Property And Equipment (Summary Of Oil And Gas Properties Not Subject To Amortization) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Total oil and gas properties not subject to amortization, total	$ 1,762,439	$ 1,817,701
Utica
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Total oil and gas properties not subject to amortization, total	1,757,014
Niobrara
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Total oil and gas properties not subject to amortization, total	4,853
Southern Louisiana
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Total oil and gas properties not subject to amortization, total	431
Bakken
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Total oil and gas properties not subject to amortization, total	96
Other
Capitalized Costs of Unproved Properties Excluded from Amortization [Line Items]
Total oil and gas properties not subject to amortization, total	$ 45

Property And Equipment (Sched40

Property And Equipment (Schedule Of Asset Retirement Obligation) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation, beginning of period			$ 26,437	$ 17,938
Liabilities incurred			3,195	4,077
Liabilities settled			(72)	(1,120)
Accretion expense	$ 261	$ 192	508	382
Asset retirement obligation as of end of period	30,068	21,277	30,068	21,277
Less current portion	75	75	75	75	$ 75
Asset retirement obligation, long-term	$ 29,993	$ 21,202	$ 29,993	$ 21,202	$ 26,362

Equity Investments (Investments

Equity Investments (Investments Accounted For By The Equity Method) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity investments	$ 253,047		$ 253,047		$ 242,393
Loss (income) from equity method investments	$ 836	$ 15,120	$ 31,573	$ (4,855)
Investment in Tatex Thailand II, LLC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	23.50%		23.50%
Loss (income) from equity method investments	$ 0	0	$ (159)	0
Investment in Tatex Thailand III, LLC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	17.90%		17.90%
Equity investments	$ 0		$ 0
Loss (income) from equity method investments	$ 0	189	$ 0	189
Investment in Grizzly Oil Sands ULC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	24.9999%		24.9999%
Equity investments	$ 49,556		$ 49,556		50,645
Loss (income) from equity method investments	$ 763	8,494	$ 24,448	12,636
Investment in Timber Wolf Terminals LLC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	50.00%		50.00%
Equity investments	$ 996		$ 996		999
Loss (income) from equity method investments	$ 1	7	$ 4	13
Investment in Windsor Midstream LLC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	22.50%		22.50%
Equity investments	$ 26,147		$ 26,147		27,955
Loss (income) from equity method investments	$ (2,881)	881	$ (3,048)	(17,906)
Investment in Stingray Cementing LLC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	50.00%		50.00%
Equity investments	$ 2,359		$ 2,359		2,487
Loss (income) from equity method investments	$ 78	105	$ 108	172
Investment in Blackhawk Midstream LLC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	48.50%		48.50%
Equity investments	$ 0		$ 0		0
Loss (income) from equity method investments	$ 0	0	$ 0	(7,217)
Investment in Stingray Energy Services LLC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	50.00%		50.00%
Equity investments	$ 4,981		$ 4,981		5,908
Loss (income) from equity method investments	$ 139	311	$ 641	321
Investment in Sturgeon Acquisitions LLC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	25.00%		25.00%
Equity investments	$ 22,258		$ 22,258		22,769
Loss (income) from equity method investments	$ 134	(491)	$ 511	(1,059)
Investment in Mammoth Energy Partners LP
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	30.50%		30.50%
Equity investments	$ 121,309		$ 121,309		131,630
Loss (income) from equity method investments	$ 2,543	5,624	$ 9,009	7,996
Investment in Strike Force Midstream LLC
Schedule of Equity Method Investments [Line Items]
Approximate ownership %	25.00%		25.00%
Equity investments	$ 25,441		$ 25,441		$ 0
Loss (income) from equity method investments	$ 59	$ 0	$ 59	$ 0

Equity Investments (Equity Inve

Equity Investments (Equity Investments Balance Sheet Disclosure) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Equity Method Investments and Joint Ventures [Abstract]
Current assets	$ 105,614	$ 105,537
Noncurrent assets	1,330,877	1,293,925
Current liabilities	41,238	56,559
Noncurrent liabilities	$ 146,642	$ 155,995

Equity Investments (Equity In43

Equity Investments (Equity Investment Income Statement Disclosure) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Equity Method Investments and Joint Ventures [Abstract]
Gross revenue	$ 86,732	$ 130,134	$ 130,039	$ 263,690
Net (loss) income	$ (560)	$ (45,246)	$ (25,868)	$ 45,422

Equity Investments (Narrative)

Equity Investments (Narrative) (Details) a in Thousands	Jan. 28, 2014USD ($)	Mar. 31, 2015USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Jun. 30, 2016USD ($)ashares	Jun. 30, 2015USD ($)	Dec. 31, 2014USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2012	Oct. 05, 2012USD ($)
Schedule of Equity Method Investments [Line Items]
Impairment of oil and gas properties			$ 170,621,000	$ 0		$ 389,612,000	$ 0
Income (loss) from equity method investments			(836,000)	(15,120,000)		(31,573,000)	4,855,000
Distributions from equity method investments						4,658,000	4,612,000
Payments for equity method investments						$ 16,690,000	8,267,000
Investment in Tatex Thailand II, LLC
Schedule of Equity Method Investments [Line Items]
Equity shares owned by affiliate (shares) | shares						85,122
Total shares owned of subaffiliate (shares) | shares						1,000,000
Gas and oil area, reserve (acres) | a						243
Income (loss) from equity method investments			$ 0	0		$ 159,000	0
Ownership interest, percent			23.50%			23.50%
Investment in Tatex Thailand III, LLC
Schedule of Equity Method Investments [Line Items]
Gas and oil area, reserve (acres) | a						245
Income (loss) from equity method investments			$ 0	(189,000)		$ 0	(189,000)
Ownership interest, percent			17.90%			17.90%
Investment in Grizzly Oil Sands ULC
Schedule of Equity Method Investments [Line Items]
Gas and oil area, reserve (acres) | a						830
Impairment of oil and gas properties						$ 23,100,000
Income (loss) from equity method investments			$ (763,000)	(8,494,000)		(24,448,000)	(12,636,000)
Equity method investment, amount of cash calls, based on proportionate ownership interest						13,700,000
Equity Method Investments, Increase (Decrease) Due To Foreign Currency Translation Adjustment			$ (600,000)	3,200,000		$ 9,700,000	11,700,000
Ownership interest, percent			24.9999%			24.9999%
Investment in Windsor Midstream LLC
Schedule of Equity Method Investments [Line Items]
Income (loss) from equity method investments			$ 2,881,000	(881,000)		$ 3,048,000	17,906,000
Distributions from equity method investments						$ 4,900,000
Ownership interest, percent			22.50%			22.50%
Investment in Windsor Midstream LLC | MidMar Gas LLC
Schedule of Equity Method Investments [Line Items]
Ownership interest, percent										28.40%
Coronado Midstream | Investment in Windsor Midstream LLC
Schedule of Equity Method Investments [Line Items]
Proceeds from sale of interest in partnership unit		$ 600,000,000
Gain on sale on investment		$ 81,600,000
Investment in Blackhawk Midstream LLC
Schedule of Equity Method Investments [Line Items]
Income (loss) from equity method investments			$ 0	0		$ 0	7,217,000
Ownership interest, percent			48.50%			48.50%
Investment in Blackhawk Midstream LLC | Ohio Gathering Company, LLC and Ohio Condensate Company, LLC
Schedule of Equity Method Investments [Line Items]
Purchase price of sold equity interests	$ 190,000,000
Amount put in escrow	$ 14,300,000
Proceeds from release of escrow deposits					$ 7,200,000
Investment in Sturgeon Acquisitions LLC
Schedule of Equity Method Investments [Line Items]
Income (loss) from equity method investments			$ (134,000)	491,000		$ (511,000)	1,059,000
Ownership interest, percent			25.00%			25.00%
Payments for equity method investments								$ 20,700,000
Investment in Mammoth Energy Partners LP
Schedule of Equity Method Investments [Line Items]
Income (loss) from equity method investments			$ (2,543,000)	(5,624,000)		$ (9,009,000)	(7,996,000)
Equity Method Investments, Increase (Decrease) Due To Foreign Currency Translation Adjustment						$ (1,300,000)
Ownership interest, percent			30.50%			30.50%
Investment in Strike Force Midstream LLC
Schedule of Equity Method Investments [Line Items]
Income (loss) from equity method investments			$ (59,000)	$ 0		$ (59,000)	$ 0
Equity method investment, amount of cash calls, based on proportionate ownership interest						$ 3,000,000
Ownership interest, percent			25.00%			25.00%
Investment in Strike Force Midstream LLC | Rice Energy Inc
Schedule of Equity Method Investments [Line Items]
Ownership interest, percent			75.00%			75.00%
Revolving Credit Facility | Subsidiaries
Schedule of Equity Method Investments [Line Items]
Revolving credit facility											$ 125,000,000
Credit facility outstanding			$ 57,200,000			$ 57,200,000
Level 3 | Investment in Grizzly Oil Sands ULC
Schedule of Equity Method Investments [Line Items]
Equity investment at fair value									$ 39,100,000

Other Assets (Schedule Of Other

Other Assets (Schedule Of Other Assets) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
Other Assets, Noncurrent Disclosure [Abstract]
Plugging and abandonment escrow account on the WCBB properties (Note 10)	$ 3,081	$ 3,089
Certificates of Deposit securing letter of credit	276	276
Prepaid drilling costs	5,404	58
Loan commitment fees	2,496	2,870
Deposits	34	34
Other	45	37
Other assets	$ 11,336	$ 6,364

Long-Term Debt (Break-Down Of L

Long-Term Debt (Break-Down Of Long-Term Debt) (Details) - USD ($)		Jun. 30, 2016	Dec. 31, 2015		Apr. 21, 2015	Aug. 18, 2014	Mar. 31, 2011
Debt Instrument [Line Items]
Net unamortized original issue (discount) premium, net	[1]	$ 11,359,000	$ 12,493,000
Net unamortized debt issuance costs		(16,567,000)	(17,883,000)
Less: current maturities of long term debt		0	(179,000)
Long-term debt, net of current maturities		956,754,000	946,084,000
Line of Credit
Debt Instrument [Line Items]
Long-term debt	[2]	$ 0	0
Building loan
Debt Instrument [Line Items]
Long-term debt			$ 1,653,000	[3]			$ 2,400,000
7.75% Senior Notes
Debt Instrument [Line Items]
Stated interest rate, percent		7.75%	7.75%
Long-term debt	[4]	$ 600,000,000	$ 600,000,000
6.625% Senior Notes
Debt Instrument [Line Items]
Long-term debt	[5]	350,000,000	350,000,000
Construction Loans
Debt Instrument [Line Items]
Long-term debt	[6]	11,962,000	0
Senior Notes
Debt Instrument [Line Items]
Stated interest rate, percent						7.75%
Long-term debt						$ 600,000,000
Accounting Standards Update 2015-03 | Other Assets
Debt Instrument [Line Items]
Net unamortized debt issuance costs	[7]	$ 16,600,000	$ 17,900,000
Notes Due 2023 | Senior Notes
Debt Instrument [Line Items]
Stated interest rate, percent		6.625%	6.625%		6.625%
[1]	The October Notes were issued at a price of 98.534% resulting in a gross discount of $3.7 million and an effective rate of 8.000%. The December Notes were issued at a price of 101.000% resulting in a gross premium of $0.5 million and an effective rate of 7.531%. The August Notes were issued at a price of 106.000% resulting in a gross premium of $18.0 million and an effective rate of 6.561%. The April Notes were issued at par. The premium and discount are being amortized using the effective interest method.
[2]	The Company has entered into a senior secured revolving credit facility, as amended, with The Bank of Nova Scotia, as the lead arranger and administrative agent and certain lenders from time to time party thereto. The credit agreement provides for a maximum facility amount of $1.5 billion and matures on June 6, 2018. On February 19, 2016, the Company further amended its revolving credit facility to, among other things, (a) increase the basket for unsecured debt issuances to $1.4 billion from $1.2 billion (of which $950 million was then outstanding), (b) reaffirm the Company’s borrowing base of $700.0 million, and (c) increase the percentage of projected oil and gas production that may be hedged by the Company during 2016. As of June 30, 2016, no balance was outstanding under this revolving credit facility and total funds available for borrowing, after giving effect to an aggregate of $205.8 million of letters of credit, were $494.2 million. This facility is secured by substantially all of the Company's assets. The wholly-owned subsidiaries of the Company guarantee the obligations under the revolving credit facility.Advances under this revolving credit facility may be in the form of either base rate loans or eurodollar loans. The interest rate for base rate loans is equal to (1) the applicable rate, which ranges from 0.50% to 1.50%, plus (2) the highest of: (a) the federal funds rate plus 0.50%, (b) the rate of interest in effect for such day as publicly announced from time to time by agent as its “prime rate,” and (c) the eurodollar rate for an interest period of one month plus 1.00%. The interest rate for eurodollar loans is equal to (1) the applicable rate, which ranges from 1.50% to 2.50%, plus (2) the London interbank offered rate that appears on pages LIBOR01 or LIBOR02 of the Reuters screen that displays such rate for deposits in U.S. dollars, or, if such rate is not available, the rate as administered by ICE Benchmark Administration (or any other person that takes over administration of such rate) per annum equal to the offered rate on such other page or other service that displays an average London interbank offered rate as administered by ICE Benchmark Administration (or any other person that takes over the administration of such rate) for deposits in U.S. dollars, or, if such rate is not available, the average quotations for three major New York money center banks of whom the agent shall inquire as the “London Interbank Offered Rate” for deposits in U.S. dollars. The Company's revolving credit facility contains customary negative covenants including, but not limited to, restrictions on the Company's and its subsidiaries' ability to: incur indebtedness; grant liens; pay dividends and make other restricted payments; make investments; make fundamental changes; enter into swap contracts and forward sales contracts; dispose of assets; change the nature of their business; and enter into transactions with their affiliates. The negative covenants are subject to certain exceptions as specified in this revolving credit facility. The Company's revolving credit facility also contains certain affirmative covenants, including, but not limited to the following financial covenants: (1) the ratio of net funded debt to EBITDAX (net income, excluding (i) any non-cash revenue or expense associated with swap contracts resulting from ASC 815 and (ii) any cash or non-cash revenue or expense attributable to minority investment plus without duplication and, in the case of expenses, to the extent deducted from revenues in determining net income, the sum of (a) the aggregate amount of consolidated interest expense for such period, (b) the aggregate amount of income, franchise, capital or similar tax expense (other than ad valorem taxes) for such period, (c) all amounts attributable to depletion, depreciation, amortization and asset or goodwill impairment or writedown for such period, (d) all other non-cash charges, (e) exploration costs deducted in determining net income under successful efforts accounting, (f) actual cash distributions received from minority investments, (g) to the extent actually reimbursed by insurance, expenses with respect to liability on casualty events or business interruption, and (h) all reasonable transaction expenses related to dispositions and acquisitions of assets, investments and debt and equity offerings (provided that expenses related to any unsuccessful dispositions will be limited to $3.0 million in the aggregate) for a twelve-month period may not be greater than 4.00 to 1.00; and (2) the ratio of EBITDAX to interest expense for a twelve-month period may not be less than 3.00 to 1.00. The Company was in compliance with these financial covenants at June 30, 2016.
[3]	In March 2011, the Company refinanced the $2.4 million then outstanding under its previous building loan for the office building it occupies in Oklahoma City, Oklahoma. This loan agreement, as subsequently amended, bore interest at the rate of 4.00% per annum, required monthly interest and principal payments of approximately $20,000, was collateralized by the Oklahoma City office building and associated land and had a maturity date of December 2018. The Company paid the balance of the loan in full in February 2016.
[4]	On October 17, 2012, the Company issued $250.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "October Notes") under an indenture among the Company, its subsidiary guarantors and Wells Fargo Bank, National Association, as the trustee (the "senior note indenture"). On December 21, 2012, the Company issued an additional $50.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "December Notes") as additional securities under the senior note indenture. The Company used a portion of the net proceeds from the October Notes to repay all amounts outstanding at such time under its revolving credit facility. The Company used the remaining net proceeds of the October Notes and the net proceeds of the December Notes for general corporate purposes, which included funding a portion of its 2013 capital development plan. The October Notes and the December Notes were exchanged for substantially identical notes in the same aggregate principal amount that were registered under the Securities Act in October 2013 (the "Exchange Notes").On August 18, 2014, the Company issued an additional $300.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "August Notes"). The August Notes were issued as additional securities under the senior note indenture. The Company used a portion of the net proceeds from the August Notes to repay all amounts outstanding at such time under its revolving credit facility. The Company used the remaining net proceeds of the August Notes Offering for general corporate purposes, including funding a portion of its 2014 and 2015 capital development plans. The October Notes, December Notes and the August Notes are collectively referred to as the "2020 Notes".In connection with the issuance of the 2020 Notes, the Company and the subsidiary guarantors entered into a registration rights agreement with the initial purchasers, pursuant to which the Company and the subsidiary guarantors agreed to file a registration statement with respect to an offering to exchange the 2020 Notes for a new issue of substantially identical debt securities registered under the Securities Act. The exchange offer for the October Notes and the December Notes was completed in October 2013 and the exchange offer for the August Note was completed in March 2015. Under the senior note indenture relating to the 2020 Notes, interest on the 2020 Notes accrues at a rate of 7.75% per annum on the outstanding principal amount from October 17, 2012, payable semi-annually on May 1 and November 1 of each year, commencing on May 1, 2013. The 2020 Notes are the Company's senior unsecured obligations and rank equally in the right of payment with all of the Company's other senior indebtedness and senior in right of payment to any future subordinated indebtedness. All of the Company's existing and future restricted subsidiaries that guarantee the Company's secured revolving credit facility or certain other debt guarantee the 2020 Notes; provided, however, that the 2020 Notes are not guaranteed by Grizzly Holdings, Inc. and will not be guaranteed by any of the Company's future unrestricted subsidiaries. The Company may redeem some or all of the 2020 Notes at any time on or after November 1, 2016, at the redemption prices listed in the senior note indenture. Prior to November 1, 2016, the Company may redeem the 2020 Notes at a price equal to 100% of the principal amount plus a “make-whole” premium. In addition, prior to November 1, 2015, the Company may redeem up to 35% of the aggregate principal amount of the 2020 Notes with the net proceeds of certain equity offerings, provided that at least 65% of the aggregate principal amount of the 2020 Notes initially issued remains outstanding immediately after such redemption.
[5]	On April 21, 2015, the Company issued $350.0 million in aggregate principal amount of 6.625% Senior Notes due 2023 (the "2023 Notes" and, together with the "2020 Notes," the "Notes") to qualified institutional buyers pursuant to Rule 144A under the Securities Act and to certain non-U.S. persons in accordance with Regulation S under the Securities Act (the "2023 Notes Offering"). The Company received net proceeds of approximately $343.6 million after initial purchaser discounts and commissions and estimated offering expenses.The 2023 notes were issued under an indenture, dated as of April 21, 2015, among the Company, the subsidiary guarantors party thereto and Wells Fargo Bank, National Association, as trustee. Pursuant to the indenture relating to the 2023 Notes, interest on the 2023 Notes will accrue at a rate of 6.625% per annum on the outstanding principal amount thereof from April 21, 2015, payable semi-annually on May 1 and November 1 of each year, commencing on November 1, 2015. The 2023 Notes are not guaranteed by Grizzly Holdings, Inc. and will not be guaranteed by any of the Company's future unrestricted subsidiaries.In connection with the 2023 Notes Offering, the Company and its subsidiary guarantors entered into a registration rights agreement, dated as of April 21, 2015, pursuant to which the Company agreed to file a registration statement with respect to an offer to exchange the 2023 Notes for a new issue of substantially identical debt securities registered under the Securities Act. The exchange offer for the 2023 Notes was completed on October 13, 2015.
[6]	On June 4, 2015, the Company entered into a construction loan agreement (the "Construction Loan") with InterBank for the construction of a new corporate headquarters in Oklahoma City. The Construction Loan allows for a maximum principal amount of $24.5 million and requires the Company to fund 30% of the estimated cost of the construction before any funds can be drawn, which occurred in January 2016. Interest accrues daily on the outstanding principal balance at a fixed rate of 4.50% per annum and is payable on the last day of the month through May 31, 2017. Monthly interest and principal payments are due beginning June 30, 2017, with the final payment due June 4, 2025. At June 30, 2016, the total borrowings under the Construction Loan were approximately $12.0 million.
[7]	In accordance with Accounting Standards Update ("ASU") 2015-03, loan issuance costs related to the Notes have been presented as a reduction to the Notes. At June 30, 2016, total unamortized debt issuance costs were $4.6 million for the October Notes, $1.0 million for the December Notes, $4.5 million for the August Notes and $6.4 million for the April Notes.

Long-Term Debt (Narrative) (Det

Long-Term Debt (Narrative) (Details)		Dec. 27, 2013USD ($)	Jan. 31, 2016	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2015USD ($)	Feb. 19, 2016USD ($)	Feb. 18, 2016USD ($)	Dec. 31, 2015USD ($)		Jun. 04, 2015USD ($)	Apr. 21, 2015USD ($)	Aug. 18, 2014USD ($)	Dec. 21, 2012USD ($)	Oct. 17, 2012USD ($)	Mar. 31, 2011USD ($)
Debt Instrument [Line Items]
Interest cost capitalized, undeveloped properties				$ 1,400,000	$ 4,700,000	$ 3,000,000	$ 8,400,000
Interest capitalized						$ 3,707,000	$ 8,399,000
Debt covenant ratio for EBITDAX				3		3
Net unamortized debt issuance costs				$ (16,567,000)		$ (16,567,000)				$ (17,883,000)
Net unamortized original issue (discount) premium, net (5)	[1]			$ (11,359,000)		$ (11,359,000)				(12,493,000)
Maximum
Debt Instrument [Line Items]
Debt covenant ratio for future EBITDAX				4		4
Building loan
Debt Instrument [Line Items]
Interest capitalized				$ 400,000		$ 700,000
Building loan outstanding amount of building loan refinanced										1,653,000	[2]						$ 2,400,000
Loan, periodic payment						20,000
Senior Notes
Debt Instrument [Line Items]
Building loan outstanding amount of building loan refinanced														$ 600,000,000
Stated interest rate, percent														7.75%
Effective interest rate, percent														6.561%	7.531%	8.00%
Discount issue price, price, percent																98.534%
Unamortized discount																$ 3,700,000
Premium issue price, percent														106.00%	101.00%
Unamortized premium														$ 18,000,000	$ 500,000
Construction Loans
Debt Instrument [Line Items]
Building loan outstanding amount of building loan refinanced	[3]			11,962,000		11,962,000				0
Line of credit facility, required minimum down payment, percent			30.00%
7.75% Senior Notes
Debt Instrument [Line Items]
Building loan outstanding amount of building loan refinanced	[4]			$ 600,000,000		$ 600,000,000				$ 600,000,000
Stated interest rate, percent				7.75%		7.75%				7.75%
Debt issued														$ 300,000,000	$ 50,000,000	$ 250,000,000
Redemption of principal amount plus aggregate net proceeds, percent				100.00%		100.00%
7.75% Senior Notes | Minimum
Debt Instrument [Line Items]
Percentage of notes required to be outstanding for redemption, percent				65.00%		65.00%
7.75% Senior Notes | Maximum
Debt Instrument [Line Items]
Redemption of principal amount plus aggregate net proceeds, percent				35.00%		35.00%
Fifth Amended And Restated Credit Agreement
Debt Instrument [Line Items]
Borrowing capacity								$ 700,000,000
Refinanced Building Loan | Building loan
Debt Instrument [Line Items]
Stated interest rate, percent				4.00%		4.00%
Notes Due 2023 | Senior Notes
Debt Instrument [Line Items]
Stated interest rate, percent				6.625%		6.625%				6.625%			6.625%
Debt instrument, amount													$ 350,000,000
6.625% Senior Notes | Senior Notes
Debt Instrument [Line Items]
Building loan outstanding amount of building loan refinanced													$ 343,600,000
Stated interest rate, percent													6.625%
October Notes
Debt Instrument [Line Items]
Net unamortized debt issuance costs				$ (4,600,000)		$ (4,600,000)
Unamortized discount				2,300,000		2,300,000
December Notes
Debt Instrument [Line Items]
Net unamortized debt issuance costs				(1,000,000)		(1,000,000)
Unamortized premium				300,000		300,000
August Notes
Debt Instrument [Line Items]
Net unamortized debt issuance costs				(4,500,000)		(4,500,000)
Unamortized premium				13,300,000		13,300,000
April Notes
Debt Instrument [Line Items]
Net unamortized debt issuance costs				(6,400,000)		(6,400,000)
Letter of Credit | Fifth Amended And Restated Credit Agreement
Debt Instrument [Line Items]
Credit facility outstanding				205,800,000		205,800,000
Remaining borrowing capacity				$ 494,200,000		$ 494,200,000
Nova Scotia, Amegy, KeyBank
Debt Instrument [Line Items]
Revolving credit facility		$ 1,500,000,000						$ 1,350,000,000	$ 1,200,000,000
Credit facility outstanding									$ 950,000,000
Debt Instrument, description of variable rate basis						LIBOR01
Nova Scotia, Amegy, KeyBank | Base Rate Loans
Debt Instrument [Line Items]
Applicable rate, minimum, percent		0.50%
Applicable rate, maximum, percent		1.50%
Nova Scotia, Amegy, KeyBank | Base Rate Loans | Federal Funds Rate
Debt Instrument [Line Items]
Basis spread, percent		0.50%
Nova Scotia, Amegy, KeyBank | Base Rate Loans | Eurodollar
Debt Instrument [Line Items]
Basis spread, percent		1.00%
Nova Scotia, Amegy, KeyBank | Euro Dollar Loans
Debt Instrument [Line Items]
Applicable rate, minimum, percent		1.50%
Applicable rate, maximum, percent		2.50%
Nova Scotia, Amegy, KeyBank | Letter of Credit | Second Amendment of Restated Credit Agreement
Debt Instrument [Line Items]
Disposition costs, maximum expenses allowed						$ 3,000,000
InterBank | Line of Credit | Construction Loans
Debt Instrument [Line Items]
Revolving credit facility												$ 24,500,000
Stated interest rate, percent												4.50%
[1]	The October Notes were issued at a price of 98.534% resulting in a gross discount of $3.7 million and an effective rate of 8.000%. The December Notes were issued at a price of 101.000% resulting in a gross premium of $0.5 million and an effective rate of 7.531%. The August Notes were issued at a price of 106.000% resulting in a gross premium of $18.0 million and an effective rate of 6.561%. The April Notes were issued at par. The premium and discount are being amortized using the effective interest method.
[2]	In March 2011, the Company refinanced the $2.4 million then outstanding under its previous building loan for the office building it occupies in Oklahoma City, Oklahoma. This loan agreement, as subsequently amended, bore interest at the rate of 4.00% per annum, required monthly interest and principal payments of approximately $20,000, was collateralized by the Oklahoma City office building and associated land and had a maturity date of December 2018. The Company paid the balance of the loan in full in February 2016.
[3]	On June 4, 2015, the Company entered into a construction loan agreement (the "Construction Loan") with InterBank for the construction of a new corporate headquarters in Oklahoma City. The Construction Loan allows for a maximum principal amount of $24.5 million and requires the Company to fund 30% of the estimated cost of the construction before any funds can be drawn, which occurred in January 2016. Interest accrues daily on the outstanding principal balance at a fixed rate of 4.50% per annum and is payable on the last day of the month through May 31, 2017. Monthly interest and principal payments are due beginning June 30, 2017, with the final payment due June 4, 2025. At June 30, 2016, the total borrowings under the Construction Loan were approximately $12.0 million.
[4]	On October 17, 2012, the Company issued $250.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "October Notes") under an indenture among the Company, its subsidiary guarantors and Wells Fargo Bank, National Association, as the trustee (the "senior note indenture"). On December 21, 2012, the Company issued an additional $50.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "December Notes") as additional securities under the senior note indenture. The Company used a portion of the net proceeds from the October Notes to repay all amounts outstanding at such time under its revolving credit facility. The Company used the remaining net proceeds of the October Notes and the net proceeds of the December Notes for general corporate purposes, which included funding a portion of its 2013 capital development plan. The October Notes and the December Notes were exchanged for substantially identical notes in the same aggregate principal amount that were registered under the Securities Act in October 2013 (the "Exchange Notes").On August 18, 2014, the Company issued an additional $300.0 million in aggregate principal amount of senior unsecured notes due 2020 (the "August Notes"). The August Notes were issued as additional securities under the senior note indenture. The Company used a portion of the net proceeds from the August Notes to repay all amounts outstanding at such time under its revolving credit facility. The Company used the remaining net proceeds of the August Notes Offering for general corporate purposes, including funding a portion of its 2014 and 2015 capital development plans. The October Notes, December Notes and the August Notes are collectively referred to as the "2020 Notes".In connection with the issuance of the 2020 Notes, the Company and the subsidiary guarantors entered into a registration rights agreement with the initial purchasers, pursuant to which the Company and the subsidiary guarantors agreed to file a registration statement with respect to an offering to exchange the 2020 Notes for a new issue of substantially identical debt securities registered under the Securities Act. The exchange offer for the October Notes and the December Notes was completed in October 2013 and the exchange offer for the August Note was completed in March 2015. Under the senior note indenture relating to the 2020 Notes, interest on the 2020 Notes accrues at a rate of 7.75% per annum on the outstanding principal amount from October 17, 2012, payable semi-annually on May 1 and November 1 of each year, commencing on May 1, 2013. The 2020 Notes are the Company's senior unsecured obligations and rank equally in the right of payment with all of the Company's other senior indebtedness and senior in right of payment to any future subordinated indebtedness. All of the Company's existing and future restricted subsidiaries that guarantee the Company's secured revolving credit facility or certain other debt guarantee the 2020 Notes; provided, however, that the 2020 Notes are not guaranteed by Grizzly Holdings, Inc. and will not be guaranteed by any of the Company's future unrestricted subsidiaries. The Company may redeem some or all of the 2020 Notes at any time on or after November 1, 2016, at the redemption prices listed in the senior note indenture. Prior to November 1, 2016, the Company may redeem the 2020 Notes at a price equal to 100% of the principal amount plus a “make-whole” premium. In addition, prior to November 1, 2015, the Company may redeem up to 35% of the aggregate principal amount of the 2020 Notes with the net proceeds of certain equity offerings, provided that at least 65% of the aggregate principal amount of the 2020 Notes initially issued remains outstanding immediately after such redemption.

Common Stock And Changes In C48

Common Stock And Changes In Capitalization (Details) - USD ($) $ in Thousands	Mar. 15, 2016	Jun. 30, 2016	Jun. 30, 2015
Class of Stock [Line Items]
Proceeds from issuance of common stock, net of offering costs		$ 411,711	$ 981,866
Common Stock | Public Offering
Class of Stock [Line Items]
Stock issued in underwritten public offering (in shares)	16,905,000
Proceeds from issuance of common stock, net of offering costs	$ 411,700
Common Stock | Over-Allotment Option
Class of Stock [Line Items]
Stock issued in underwritten public offering (in shares)	2,205,000

Stock-Based Compensation (Narra

Stock-Based Compensation (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Share-based Compensation [Abstract]
Stock-based compensation expense	$ 3,300	$ 3,200	$ 6,600	$ 6,700
Capitalized stock-based compensation	1,300	$ 1,300	2,625	$ 2,694
Unrecognized compensation expense	$ 16,000		$ 16,000
Weighted average period of expense recognition (in years)			1 year 8 months 7 days

Stock-Based Compensation (Summa

Stock-Based Compensation (Summary Of Restricted Stock Award And Unit Activity) (Details) - Restricted Stock	6 Months Ended
	Jun. 30, 2016$ / sharesshares
Number of Unvested Restricted Shares
Unvested shares as of January 1, 2016 | shares	484,239
Granted | shares	255,204
Vested | shares	(137,916)
Forfeited | shares	(8,042)
Unvested shares as of June 30, 2016 | shares	593,485
Weighted Average Grant Date Fair Value
Unvested shares as of January 1, 2016 | $ / shares	$ 43.51
Granted | $ / shares	27.71
Vested | $ / shares	47.31
Forfeited | $ / shares	34.76
Unvested shares as of June 30, 2016 | $ / shares	$ 35.95

Earnings Per Share (Schedule Of

Earnings Per Share (Schedule Of Earnings Per Share Reconciliation) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Basic:
Net loss	$ (339,776)	$ (31,325)	$ (582,043)	$ (5,806)
Net loss (in shares)	125,343,723	96,663,358	118,426,654	91,201,824
Net loss (in USD per share)	$ (2.71)	$ (0.32)	$ (4.91)	$ (0.06)
Effect of dilutive securities:
Stock options and awards	$ 0	$ 0	$ 0	$ 0
Weighted Average Number Diluted Shares Outstanding Adjustment	0	0	0	0
Diluted:
Net loss	$ (339,776)	$ (31,325)	$ (582,043)	$ (5,806)
Net loss (in share)	125,343,723	96,663,358	118,426,654	91,201,824
Net loss (in USD per share)	$ (2.71)	$ (0.32)	$ (4.91)	$ (0.06)
Common stock considered anti-dilutive (in shares)	573,187	378,550	558,894	382,494

Commitments and Contingencies52

Commitments and Contingencies (Details) $ in Thousands	Feb. 09, 2016complaintcompany	Mar. 11, 1997	Jun. 30, 2016USD ($)well	Jun. 30, 2016USD ($)well	Dec. 31, 1997USD ($)well	Dec. 31, 2015USD ($)
Commitments [Line Items]
Loss Contingency, New Claims Filed, Number | complaint	2
Plugging and abandonment escrow account on the WCBB properties (Note 10)			$ 3,081	$ 3,081		$ 3,089
WCBB
Commitments [Line Items]
Purchasing remaining percent interest In oil and gas property, percent					50.00%
Payments held for restricted cash					$ 18
Significant plugging commitment minimum number of wells to be plugged | well					20
Tenure of minimum wells to be plugged		20 years
Number of wells plugged | well			463	463
Muskie Proppant LLC
Commitments [Line Items]
Long-term purchase commitment, accrued damages , amount			$ 700	$ 2,000
Cameron Parish
Commitments [Line Items]
Loss Contingency, Number of Defendant Companies in a Complaint | company	26
Vermillion Parish
Commitments [Line Items]
Loss Contingency, Number of Defendant Companies in a Complaint | company	9

Commitments and Contingencies53

Commitments and Contingencies (Future Minimum Lease Commitments) (Details) $ in Thousands	Jun. 30, 2016USD ($)
Commitments and Contingencies Disclosure [Abstract]
Remaining 2,016	$ 386
2,017	583
2,018	54
Total	$ 1,023

Commitments and Contingencies54

Commitments and Contingencies (Other Commitment Payments) (Details) $ in Thousands	Jun. 30, 2016USD ($)
Commitments and Contingencies Disclosure [Abstract]
Remaining 2,016	$ 26,220
2,017	52,440
2,018	39,330
Total	$ 117,990

Derivative Instruments (Narrati

Derivative Instruments (Narrative) (Details)	6 Months Ended
	Jun. 30, 2016MMBTU / d$ / MMBTU
Derivative [Line Items]
Derivative, Extension Option Term	12 months
January 2017 - December 2017
Derivative [Line Items]
Daily Volume | MMBTU / d	30,000
Weighted Average Price (in usd per MMBtu) | $ / MMBTU	3.33
January 2017 - December 2017 | Short
Derivative [Line Items]
Daily Volume | MMBTU / d	30,000
Weighted Average Price (in usd per MMBtu) | $ / MMBTU	3.33

Derivative Instruments (Schedul

Derivative Instruments (Schedule Of Derivative Instruments) (Details)	Jun. 30, 2016bbl / dMMBTU / d$ / bbl$ / MMBTU
July 2016 - June 2017 | ARGUS LLS
Derivative [Line Items]
Daily Volume | bbl / d	2,000
Weighted Average Price | $ / bbl	(51.10)
July 2016 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	550,000
Weighted Average Price | $ / MMBTU	(3.06)
August 2016 - September 2016 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	560,000
Weighted Average Price | $ / MMBTU	(3.04)
October 2016 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	570,000
Weighted Average Price | $ / MMBTU	(3.05)
November 2016 - December 2016 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	525,000
Weighted Average Price | $ / MMBTU	(3.18)
January 2017 - February 2017 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	442,500
Weighted Average Price | $ / MMBTU	(3.14)
March 2017 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	422,500
Weighted Average Price | $ / MMBTU	(3.13)
April 2017 - June 2017 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	367,500
Weighted Average Price | $ / MMBTU	(3.15)
July 2017 - October 2017 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	305,000
Weighted Average Price | $ / MMBTU	(2.99)
November 2017 - December 2017 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	385,000
Weighted Average Price | $ / MMBTU	(3.03)
January 2018 - March 2018 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	240,000
Weighted Average Price | $ / MMBTU	(3.07)
April 2018 - December 2018 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	160,000
Weighted Average Price | $ / MMBTU	(3.01)
January 2019 - March 2019 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	20,000
Weighted Average Price | $ / MMBTU	(3.37)
July 2016 - December 2016 | Mont Belvieu
Derivative [Line Items]
Daily Volume | bbl / d	1,500
Weighted Average Price | $ / bbl	(19.95)
Short | Call Option | January 2018 - March 2018 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	20,000
Weighted Average Price | $ / MMBTU	(2.91)
Short | Call Option | January 2017 - March 2017 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	105,000
Weighted Average Price | $ / MMBTU	(3.27)
Short | Call Option | April 2017 - December 2017 | NYMEX Henry Hub
Derivative [Line Items]
Daily Volume | MMBTU / d	125,000
Weighted Average Price | $ / MMBTU	(3.21)
Swap | July 2016 - December 2016 | MichCon
Derivative [Line Items]
Daily Volume | MMBTU / d	40,000
Weighted Average Price | $ / MMBTU	(0.02)
Swap | November 2016 - March 2017 | Tetco M2
Derivative [Line Items]
Daily Volume | MMBTU / d	50,000
Weighted Average Price | $ / MMBTU	(0.59)

Derivative Instruments (Sched57

Derivative Instruments (Schedule Of Derivative Instruments In Statement Of Financial Position) (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015
General Discussion of Derivative Instruments and Hedging Activities [Abstract]
Short-term derivative instruments - asset	$ 44,672	$ 142,794
Long-term derivative instruments - asset	14,644	51,088
Short-term derivative instruments - liability	49,906	437
Long-term derivative instruments - liability	$ 29,269	$ 6,935

Derivative Instruments - Gain (

Derivative Instruments - Gain (Los) On Derivative Instruments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Derivative [Line Items]
Net (loss) gain on derivative instruments	$ (137,392)	$ (10,082)	$ (79,657)	$ 40,022
Gas sales
Derivative [Line Items]
Net (loss) gain on derivative instruments	(133,621)	(8,087)	(76,621)	38,453
Oil and condensate sales
Derivative [Line Items]
Net (loss) gain on derivative instruments	(2,628)	(1,995)	(1,346)	1,569
Natural gas liquids sales
Derivative [Line Items]
Net (loss) gain on derivative instruments	$ (1,143)	$ 0	$ (1,690)	$ 0

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Mar. 31, 2016
Liabilities:
Asset retirement obligation capitalized	$ 3,195	$ 4,077
Level 1
Assets:
Derivative Instruments	0
Liabilities:
Derivative Instruments	0
Level 2
Assets:
Derivative Instruments	59,316
Liabilities:
Derivative Instruments	79,175
Level 3
Assets:
Derivative Instruments	0
Liabilities:
Derivative Instruments	0
Asset retirement obligation capitalized	$ 3,200
Level 3 | Investment in Grizzly Oil Sands ULC
Liabilities:
Equity investment			$ 39,100

Fair Value of Financial Instr60

Fair Value of Financial Instruments (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015	Aug. 18, 2014	Dec. 21, 2012	Oct. 17, 2012
Debt Instrument [Line Items]
Net unamortized debt issuance costs	$ 16,567	$ 17,883
Fair value of notes	960,400
October Notes
Debt Instrument [Line Items]
Unamortized discount	2,300
Net unamortized debt issuance costs	4,600
December Notes
Debt Instrument [Line Items]
Unamortized premium	300
Net unamortized debt issuance costs	1,000
August Notes
Debt Instrument [Line Items]
Unamortized premium	13,300
Net unamortized debt issuance costs	4,500
April Notes
Debt Instrument [Line Items]
Net unamortized debt issuance costs	6,400
Senior Notes
Debt Instrument [Line Items]
Carrying value of debt	$ 944,800
Unamortized discount					$ 3,700
Unamortized premium			$ 18,000	$ 500

Condensed Consolidating Finan61

Condensed Consolidating Financial Information - (Details) - USD ($)	Jun. 30, 2016	Dec. 31, 2015	Apr. 21, 2015	Aug. 18, 2014
Senior Notes
Condensed Financial Statements, Captions [Line Items]
Long-term debt				$ 600,000,000
Stated interest rate, percent				7.75%
Guarantors
Condensed Financial Statements, Captions [Line Items]
Ownership percentage by parent	100.00%
Notes Due 2023 | Senior Notes
Condensed Financial Statements, Captions [Line Items]
Stated interest rate, percent	6.625%	6.625%	6.625%
Debt instrument, amount			$ 350,000,000

Condensed Consolidating Finan62

Condensed Consolidating Financial Information - Condensed Consolidating Balance Sheets (Details) - USD ($) $ in Thousands	Jun. 30, 2016	Dec. 31, 2015	Jun. 30, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 396,437	$ 112,974	$ 525,488	$ 142,340
Accounts receivable—oil and gas	91,462	71,872
Accounts receivable - related parties	23	16
Accounts receivable - intercompany		0
Prepaid expenses and other current assets	7,782	3,905
Short-term derivative instruments	44,672	142,794
Deferred Tax Assets, Net, Current	292	0
Total current assets	540,668	331,561
Property and equipment:
Oil and natural gas properties	5,686,188	5,424,342
Other property and equipment	48,107	33,171
Accumulated depletion, depreciation, amortization and impairment	(3,339,087)	(2,829,110)
Property and equipment, net	2,395,208	2,628,403
Other assets:
Equity investments	253,047	242,393
Long-term derivative instruments	14,644	51,088
Deferred tax asset	24,284	74,925
Other assets	11,336	6,364
Total other assets	303,311	374,770
Total assets	3,239,187	3,334,734
Current liabilities:
Accounts payable and accrued liabilities	289,750	265,128
Accounts payable - intercompany	0	0
Asset retirement obligation—current	75	75	75
Short-term derivative instruments	49,906	437
Deferred tax liability	0	50,697
Current maturities of long-term debt	0	179
Total current liabilities	339,731	316,516
Long-term derivative instrument	29,269	6,935
Asset retirement obligation—long-term	29,993	26,362	21,202
Asset retirement obligation - long-term		26,362
Long-term debt	956,754	946,084
Total liabilities	1,355,747	1,295,897
Stockholders’ equity:
Common stock	1,253	1,082
Paid-in capital	3,242,404	2,824,303
Accumulated other comprehensive (loss) income	(46,803)	(55,177)
Retained (deficit) earnings	(1,313,414)	(731,371)
Total stockholders’ equity	1,883,440	2,038,837	3,267,306	2,296,296
Total liabilities and stockholders’ equity	3,239,187	3,334,734
Parent
Current assets:
Cash and cash equivalents	395,703	112,494	524,240	141,535
Accounts receivable—oil and gas	90,758	72,241
Accounts receivable - related parties	23	16
Accounts receivable - intercompany	355,924	326,475
Prepaid expenses and other current assets	7,782	3,905
Short-term derivative instruments	44,672	142,794
Deferred Tax Assets, Net, Current	292
Total current assets	895,154	657,925
Property and equipment:
Oil and natural gas properties	5,334,096	5,108,258
Other property and equipment	48,064	33,128
Accumulated depletion, depreciation, amortization and impairment	(3,339,056)	(2,829,081)
Property and equipment, net	2,043,104	2,312,305
Other assets:
Equity investments	242,627	231,892
Long-term derivative instruments	14,644	51,088
Deferred tax asset	24,284	74,925
Other assets	11,336	6,364
Total other assets	292,891	364,269
Total assets	3,231,149	3,334,499
Current liabilities:
Accounts payable and accrued liabilities	281,712	264,893
Accounts payable - intercompany	0
Asset retirement obligation—current	75	75
Short-term derivative instruments	49,906	437
Deferred tax liability		50,697
Current maturities of long-term debt		179
Total current liabilities	331,693	316,281
Long-term derivative instrument	29,269	6,935
Asset retirement obligation—long-term	29,993
Asset retirement obligation - long-term		26,362
Long-term debt	956,754	946,084
Total liabilities	1,347,709	1,295,662
Stockholders’ equity:
Common stock	1,253	1,082
Paid-in capital	3,242,404	2,824,303
Accumulated other comprehensive (loss) income	(46,803)	(55,177)
Retained (deficit) earnings	(1,313,414)	(731,371)
Total stockholders’ equity	1,883,440	2,038,837
Total liabilities and stockholders’ equity	3,231,149	3,334,499
Guarantors
Current assets:
Cash and cash equivalents	733	479	1,247	804
Accounts receivable—oil and gas	7,721	54
Accounts receivable - related parties	0	0
Accounts receivable - intercompany	1,904	60
Prepaid expenses and other current assets		0
Short-term derivative instruments	0	0
Deferred Tax Assets, Net, Current	0
Total current assets	10,358	593
Property and equipment:
Oil and natural gas properties	352,821	316,813
Other property and equipment	43	43
Accumulated depletion, depreciation, amortization and impairment	(31)	(29)
Property and equipment, net	352,833	316,827
Other assets:
Equity investments	25,441	0
Long-term derivative instruments	0	0
Deferred tax asset	0	0
Other assets		0
Total other assets	25,441
Total assets	388,632	317,420
Current liabilities:
Accounts payable and accrued liabilities	16,768	527
Accounts payable - intercompany	355,991	326,541
Asset retirement obligation—current		0
Short-term derivative instruments		0
Deferred tax liability		0
Current maturities of long-term debt		0
Total current liabilities	372,759	327,068
Long-term derivative instrument	0	0
Asset retirement obligation—long-term	0
Asset retirement obligation - long-term		0
Long-term debt	0	0
Total liabilities	372,759	327,068
Stockholders’ equity:
Common stock		0
Paid-in capital	25,822	322
Accumulated other comprehensive (loss) income		0
Retained (deficit) earnings	(9,949)	(9,970)
Total stockholders’ equity	15,873	(9,648)
Total liabilities and stockholders’ equity	388,632	317,420
Non-Guarantor
Current assets:
Cash and cash equivalents	1	1	1	1
Accounts receivable—oil and gas	0	0
Accounts receivable - related parties	0	0
Accounts receivable - intercompany	0	0
Prepaid expenses and other current assets	0	0
Short-term derivative instruments	0	0
Deferred Tax Assets, Net, Current	0
Total current assets	1	1
Property and equipment:
Oil and natural gas properties		0
Other property and equipment		0
Accumulated depletion, depreciation, amortization and impairment		0
Property and equipment, net		0
Other assets:
Equity investments	49,557	50,644
Long-term derivative instruments	0	0
Deferred tax asset	0	0
Other assets		0
Total other assets	49,557	50,644
Total assets	49,558	50,645
Current liabilities:
Accounts payable and accrued liabilities		0
Accounts payable - intercompany	125	124
Asset retirement obligation—current		0
Short-term derivative instruments		0
Deferred tax liability		0
Current maturities of long-term debt		0
Total current liabilities	125	124
Long-term derivative instrument	0	0
Asset retirement obligation—long-term	0
Asset retirement obligation - long-term		0
Long-term debt	0	0
Total liabilities	125	124
Stockholders’ equity:
Common stock		0
Paid-in capital	255,244	241,553
Accumulated other comprehensive (loss) income	(45,507)	(55,177)
Retained (deficit) earnings	(160,304)	(135,855)
Total stockholders’ equity	49,433	50,521
Total liabilities and stockholders’ equity	49,558	50,645
Eliminations
Current assets:
Cash and cash equivalents	0	0	$ 0	$ 0
Accounts receivable—oil and gas	(7,017)	(423)
Accounts receivable - related parties	0	0
Accounts receivable - intercompany	(357,828)	(326,535)
Prepaid expenses and other current assets		0
Short-term derivative instruments	0	0
Deferred Tax Assets, Net, Current	0
Total current assets	(364,845)	(326,958)
Property and equipment:
Oil and natural gas properties	(729)	(729)
Other property and equipment		0
Accumulated depletion, depreciation, amortization and impairment		0
Property and equipment, net	(729)	(729)
Other assets:
Equity investments	(64,578)	(40,143)
Long-term derivative instruments	0	0
Deferred tax asset	0	0
Other assets		0
Total other assets	(64,578)	(40,143)
Total assets	(430,152)	(367,830)
Current liabilities:
Accounts payable and accrued liabilities	(8,730)	(292)
Accounts payable - intercompany	(356,116)	(326,665)
Asset retirement obligation—current		0
Short-term derivative instruments		0
Deferred tax liability		0
Current maturities of long-term debt		0
Total current liabilities	(364,846)	(326,957)
Long-term derivative instrument	0	0
Asset retirement obligation—long-term	0
Asset retirement obligation - long-term		0
Long-term debt	0	0
Total liabilities	(364,846)	(326,957)
Stockholders’ equity:
Common stock		0
Paid-in capital	(281,066)	(241,875)
Accumulated other comprehensive (loss) income	45,507	55,177
Retained (deficit) earnings	170,253	145,825
Total stockholders’ equity	(65,306)	(40,873)
Total liabilities and stockholders’ equity	$ (430,152)	$ (367,830)

Condensed Consolidating Finan63

Condensed Consolidating Financial Information - Condensed Consolidating Statement of Operations (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Revenues:
Total revenues	$ (28,152,000)	$ 112,270,000	$ 128,811,000	$ 288,587,000
Costs and expenses:
Lease operating expenses	14,661,000	16,863,000	31,318,000	33,843,000
Production taxes	2,856,000	3,285,000	5,967,000	7,570,000
Midstream gathering and processing	39,349,000	32,904,000	77,001,000	58,285,000
Depreciation, depletion and amortization	55,652,000	71,155,000	121,129,000	161,064,000
Impairment of oil and gas properties	170,621,000	0	389,612,000	0
General and administrative	11,854,000	9,515,000	22,474,000	20,314,000
Accretion expense	261,000	192,000	508,000	382,000
Total costs and expenses	295,254,000	133,914,000	648,009,000	281,458,000
(LOSS) INCOME FROM OPERATIONS	(323,406,000)	(21,644,000)	(519,198,000)	7,129,000
OTHER (INCOME) EXPENSE:
Interest expense	16,082,000	12,023,000	32,105,000	20,782,000
Interest income	(391,000)	(248,000)	(485,000)	(257,000)
Loss (income) from equity method investments and investments in subsidiaries	836,000	15,120,000	31,573,000	(4,855,000)
Nonoperating Income (Expense)	16,527,000	26,895,000	63,193,000	15,670,000
LOSS BEFORE INCOME TAXES	(339,933,000)	(48,539,000)	(582,391,000)	(8,541,000)
INCOME TAX BENEFIT	(157,000)	(17,214,000)	(348,000)	(2,735,000)
NET LOSS	(339,776,000)	(31,325,000)	(582,043,000)	(5,806,000)
Parent
Revenues:
Total revenues	(28,580,000)	112,027,000	128,171,000	287,859,000
Costs and expenses:
Lease operating expenses	14,491,000	16,685,000	30,963,000	33,472,000
Production taxes	2,828,000	3,260,000	5,915,000	7,513,000
Midstream gathering and processing	39,242,000	32,892,000	76,865,000	58,266,000
Depreciation, depletion and amortization	55,651,000	71,154,000	121,127,000	161,062,000
Impairment of oil and gas properties	170,621,000		389,612,000
General and administrative	11,846,000	9,488,000	22,458,000	20,249,000
Accretion expense	261,000	192,000	508,000	382,000
Total costs and expenses	294,940,000	133,671,000	647,448,000	280,944,000
(LOSS) INCOME FROM OPERATIONS	(323,520,000)	(21,644,000)	(519,277,000)	6,915,000
OTHER (INCOME) EXPENSE:
Interest expense	16,082,000	12,023,000	32,104,000	20,782,000
Interest income	(391,000)	(248,000)	(485,000)	(257,000)
Loss (income) from equity method investments and investments in subsidiaries	722,000	15,120,000	31,495,000	(5,069,000)
Nonoperating Income (Expense)	16,413,000	26,895,000	63,114,000	15,456,000
LOSS BEFORE INCOME TAXES	(339,933,000)	(48,539,000)	(582,391,000)	(8,541,000)
INCOME TAX BENEFIT	(157,000)	(17,214,000)	(348,000)	(2,735,000)
NET LOSS	(339,776,000)	(31,325,000)	(582,043,000)	(5,806,000)
Guarantors
Revenues:
Total revenues	428,000	243,000	640,000	728,000
Costs and expenses:
Lease operating expenses	170,000	178,000	355,000	371,000
Production taxes	28,000	25,000	52,000	57,000
Midstream gathering and processing	107,000	12,000	136,000	19,000
Depreciation, depletion and amortization	1,000	1,000	2,000	2,000
Impairment of oil and gas properties	0		0
General and administrative	8,000	5,000	14,000	41,000
Accretion expense	0	0	0	0
Total costs and expenses	314,000	221,000	559,000	490,000
(LOSS) INCOME FROM OPERATIONS	114,000	22,000	81,000	238,000
OTHER (INCOME) EXPENSE:
Interest expense	0	0	1,000	0
Interest income	0	0	0	0
Loss (income) from equity method investments and investments in subsidiaries	59,000	0	59,000	0
Nonoperating Income (Expense)	59,000	0	60,000	0
LOSS BEFORE INCOME TAXES	55,000	22,000	21,000	238,000
INCOME TAX BENEFIT	0	0	0	0
NET LOSS	55,000	22,000	21,000	238,000
Non-Guarantor
Revenues:
Total revenues	0	0	0	0
Costs and expenses:
Lease operating expenses	0	0	0	0
Production taxes	0	0	0	0
Midstream gathering and processing	0	0	0	0
Depreciation, depletion and amortization	0	0		0
Impairment of oil and gas properties	0		0
General and administrative	0	22,000	2,000	24,000
Accretion expense	0	0	0	0
Total costs and expenses	0	22,000	2,000	24,000
(LOSS) INCOME FROM OPERATIONS	0	(22,000)	(2,000)	(24,000)
OTHER (INCOME) EXPENSE:
Interest expense	0	0	0	0
Interest income	0	0	0	0
Loss (income) from equity method investments and investments in subsidiaries	762,000	8,494,000	24,447,000	12,636,000
Nonoperating Income (Expense)	762,000	8,494,000	24,447,000	12,636,000
LOSS BEFORE INCOME TAXES	(762,000)	(8,516,000)	(24,449,000)	(12,660,000)
INCOME TAX BENEFIT	0	0	0	0
NET LOSS	(762,000)	(8,516,000)	(24,449,000)	(12,660,000)
Eliminations
Revenues:
Total revenues	0	0	0	0
Costs and expenses:
Lease operating expenses	0	0	0	0
Production taxes	0	0	0	0
Midstream gathering and processing	0	0	0	0
Depreciation, depletion and amortization	0	0		0
Impairment of oil and gas properties	0		0
General and administrative	0	0	0	0
Accretion expense	0	0	0	0
Total costs and expenses	0	0	0	0
(LOSS) INCOME FROM OPERATIONS	0	0	0	0
OTHER (INCOME) EXPENSE:
Interest expense	0	0	0	0
Interest income	0	0	0	0
Loss (income) from equity method investments and investments in subsidiaries	(707,000)	(8,494,000)	(24,428,000)	(12,422,000)
Nonoperating Income (Expense)	(707,000)	(8,494,000)	(24,428,000)	(12,422,000)
LOSS BEFORE INCOME TAXES	707,000	8,494,000	24,428,000	12,422,000
INCOME TAX BENEFIT	0	0	0	0
NET LOSS	$ 707,000	$ 8,494,000	$ 24,428,000	$ 12,422,000

Condensed Consolidating Finan64

Condensed Consolidating Financial Information - Condensed Consolidating Statements of Comprehensive Income (Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Condensed Financial Statements, Captions [Line Items]
Net loss	$ (339,776)	$ (31,325)	$ (582,043)	$ (5,806)
Foreign currency translation adjustment	(684)	3,247	8,374	(11,737)
Other comprehensive (loss) income	(684)	3,247	8,374	(11,737)
Comprehensive loss	(340,460)	(28,078)	(573,669)	(17,543)
Parent
Condensed Financial Statements, Captions [Line Items]
Net loss	(339,776)	(31,325)	(582,043)	(5,806)
Foreign currency translation adjustment	(684)	3,247	8,374	(11,737)
Other comprehensive (loss) income	(684)	3,247	8,374	(11,737)
Comprehensive loss	(340,460)	(28,078)	(573,669)	(17,543)
Guarantors
Condensed Financial Statements, Captions [Line Items]
Net loss	55	22	21	238
Foreign currency translation adjustment	0	0	0	0
Other comprehensive (loss) income	0	0	0	0
Comprehensive loss	55	22	21	238
Non-Guarantor
Condensed Financial Statements, Captions [Line Items]
Net loss	(762)	(8,516)	(24,449)	(12,660)
Foreign currency translation adjustment	(604)	3,247	9,669	(11,737)
Other comprehensive (loss) income	(604)	3,247	9,669	(11,737)
Comprehensive loss	(1,366)	(5,269)	(14,780)	(24,397)
Eliminations
Condensed Financial Statements, Captions [Line Items]
Net loss	707	8,494	24,428	12,422
Foreign currency translation adjustment	604	(3,247)	(9,669)	11,737
Other comprehensive (loss) income	604	(3,247)	(9,669)	11,737
Comprehensive loss	$ 1,311	$ 5,247	$ 14,759	$ 24,159

Condensed Consolidating Finan65

Condensed Consolidating Financial Information - Condensed Consolidating Statement of Cash Flows (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2016	Jun. 30, 2015	Jun. 30, 2016	Jun. 30, 2015
Condensed Financial Statements, Captions [Line Items]
Net Income (Loss) Attributable to Parent	$ (339,776)	$ (31,325)	$ (582,043)	$ (5,806)
Net cash provided by operating activities			142,724	138,874
Net cash (used in) provided by investing activities			(281,044)	(979,766)
Net cash provided by (used in) financing activities			421,783	1,224,040
Net increase in cash and cash equivalents			283,463	383,148
Cash and cash equivalents at beginning of period			112,974	142,340
Cash and cash equivalents at end of period	396,437	525,488	396,437	525,488
Parent
Condensed Financial Statements, Captions [Line Items]
Net Income (Loss) Attributable to Parent	(339,776)	(31,325)	(582,043)	(5,806)
Net cash provided by operating activities			142,470	135,485
Net cash (used in) provided by investing activities			(281,044)	(976,820)
Net cash provided by (used in) financing activities			421,783	1,224,040
Net increase in cash and cash equivalents			283,209	382,705
Cash and cash equivalents at beginning of period			112,494	141,535
Cash and cash equivalents at end of period	395,703	524,240	395,703	524,240
Guarantors
Condensed Financial Statements, Captions [Line Items]
Net Income (Loss) Attributable to Parent	55	22	21	238
Net cash provided by operating activities			254	3,389
Net cash (used in) provided by investing activities			(25,500)	(2,946)
Net cash provided by (used in) financing activities			25,500	0
Net increase in cash and cash equivalents			254	443
Cash and cash equivalents at beginning of period			479	804
Cash and cash equivalents at end of period	733	1,247	733	1,247
Non-Guarantor
Condensed Financial Statements, Captions [Line Items]
Net Income (Loss) Attributable to Parent	(762)	(8,516)	(24,449)	(12,660)
Net cash provided by operating activities			0	(1)
Net cash (used in) provided by investing activities			(13,690)	(8,267)
Net cash provided by (used in) financing activities			13,690	8,268
Net increase in cash and cash equivalents			0	0
Cash and cash equivalents at beginning of period			1	1
Cash and cash equivalents at end of period	1	1	1	1
Eliminations
Condensed Financial Statements, Captions [Line Items]
Net Income (Loss) Attributable to Parent	707	8,494	24,428	12,422
Net cash provided by operating activities			0	1
Net cash (used in) provided by investing activities			39,190	8,267
Net cash provided by (used in) financing activities			(39,190)	(8,268)
Net increase in cash and cash equivalents			0	0
Cash and cash equivalents at beginning of period			0	0
Cash and cash equivalents at end of period	$ 0	$ 0	$ 0	$ 0

Recent Accounting Pronounceme66

Recent Accounting Pronouncements (Details) - USD ($) $ in Thousands		Jun. 30, 2016	Dec. 31, 2015
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Unamortized Debt Issuance Expense		$ 16,567	$ 17,883
Other Assets | Accounting Standards Update 2015-03
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Unamortized Debt Issuance Expense	[1]	(16,600)	(17,900)
Long-term Debt | Accounting Standards Update 2015-03
Error Corrections and Prior Period Adjustments Restatement [Line Items]
Unamortized Debt Issuance Expense	[1]	$ 16,600	$ 17,900
[1]	In accordance with Accounting Standards Update ("ASU") 2015-03, loan issuance costs related to the Notes have been presented as a reduction to the Notes. At June 30, 2016, total unamortized debt issuance costs were $4.6 million for the October Notes, $1.0 million for the December Notes, $4.5 million for the August Notes and $6.4 million for the April Notes.