Magnum Hunter Resources 10-Q 9 Nov 15 2015 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2015	Nov. 06, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	MAGNUM HUNTER RESOURCES CORP
Entity Central Index Key	1,335,190
Document Type	10-Q
Document Period End Date	Sep. 30, 2015
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		260,743,281
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q3

CONSOLIDATED BALANCE SHEETS (Un

CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
CURRENT ASSETS
Cash and cash equivalents	$ 6,463	$ 53,180
Oil and natural gas sales	16,041	21,514
Joint interests and other, net of allowance for doubtful accounts of $567 at September 30, 2015 and $308 at December 31, 2014	8,524	23,888
Derivative assets	1,054	16,586
Inventory	2,554	2,268
Investments	968	3,864
Prepaid expenses and other assets	4,056	4,091
Total current assets	39,660	125,391
PROPERTY, PLANT AND EQUIPMENT
Oil and natural gas properties, successful efforts method of accounting, net	979,147	1,098,235
Gas transportation, gathering and processing equipment and other, net	74,417	77,423
Total property, plant and equipment, net	1,053,564	1,175,658
OTHER ASSETS
Deferred financing costs, net of amortization of $17,568 at September 30, 2015 and $15,099 at December 31, 2014	19,765	22,856
Other assets	419	3,928
Assets of discontinued operations	343,307	347,191
Total assets	1,456,715	1,675,024
CURRENT LIABILITIES
Current portion of long-term debt	939,679	10,770
Accounts payable	83,603	135,697
Accounts payable to related parties	11,234	90
Accrued liabilities	35,004	20,277
Revenue payable	4,357	5,450
Derivative liabilities	569	0
Other liabilities	2,413	1,356
Total current liabilities	1,076,859	173,640
Long-term debt, net of current portion	8,300	937,963
Asset retirement obligations, net of current portion	26,451	26,229
Other long-term liabilities	5,415	5,337
Total liabilities	$ 1,117,025	$ 1,143,169
COMMITMENTS AND CONTINGENCIES (Note 15)
SHAREHOLDERS' EQUITY
Common stock, $0.01 par value per share, 350,000,000 shares authorized, and 261,269,008 and 201,420,701 issued, and 260,354,056 and 200,505,749 outstanding as of September 30, 2015 and December 31, 2014, respectively	$ 2,613	$ 2,014
Additional paid in capital	975,534	909,783
Accumulated deficit	(1,051,865)	(784,546)
Accumulated other comprehensive income (loss)	1,039	(7,765)
Treasury stock, at cost	(1,914)	(1,914)
Total shareholders' equity	239,690	431,855
Total liabilities and shareholders' equity	1,456,715	1,675,024
Series C Cumulative Perpetual Preferred Stock
REDEEMABLE PREFERRED STOCK
Redeemable preferred stock	100,000	100,000
Series D Cumulative Perpetual Preferred Stock
SHAREHOLDERS' EQUITY
Preferred Stock	221,244	221,244
Series E Cumulative Convertible Preferred Stock
SHAREHOLDERS' EQUITY
Preferred Stock	95,069	95,069
Treasury stock, at cost	$ (2,030)	$ (2,030)

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Accounts receivable, allowance for doubtful accounts	$ 567	$ 308
Amortization of deferred financing costs	$ 17,568	$ 15,099
Preferred stock, shares authorized	10,000,000	10,000,000
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares authorized	350,000,000	350,000,000
Common stock, shares issued	261,269,008	201,420,701
Common stock, shares outstanding	260,354,056	200,505,749
Treasury stock, shares	914,952	914,952
Series C Cumulative Perpetual Preferred Stock
Cumulative dividend rate (as a percent)	10.25%	10.25%
Preferred stock, shares authorized	4,000,000	4,000,000
Preferred stock, shares issued	4,000,000	4,000,000
Preferred stock, shares outstanding	4,000,000	4,000,000
Preferred stock, liquidation preference (in dollars per share)	$ 25	$ 25
Series D Cumulative Perpetual Preferred Stock
Preferred stock, shares authorized	5,750,000	5,750,000
Cumulative dividend rate for cumulative preferred stock (as a percent)	8.00%	8.00%
Preferred stock, shares issued	4,424,889	4,424,889
Preferred Stock, Shares Outstanding	4,424,889	4,424,889
Preferred stock, liquidation preference (in dollars per share)	$ 50	$ 50
Series E Cumulative Convertible Preferred Stock
Preferred stock, shares authorized	12,000	12,000
Cumulative dividend rate for cumulative preferred stock (as a percent)	8.00%	8.00%
Preferred stock, shares issued	3,803	3,803
Preferred Stock, Shares Outstanding	3,722	3,722
Preferred stock, liquidation preference (in dollars per share)	$ 25,000	$ 25,000
Treasury stock, shares	81	81

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
REVENUES AND OTHER
Oil and natural gas sales	$ 27,852	$ 62,510	$ 110,661	$ 222,247
Midstream natural gas gathering, processing, and marketing	161	1,180	1,091	66,937
Oilfield services	5,294	5,986	15,552	17,561
Other revenue	357	881	1,282	1,330
Total revenue	33,664	70,557	128,586	308,075
OPERATING EXPENSES
Production costs	11,130	10,994	34,286	34,236
Severance taxes and marketing	1,588	5,396	6,170	16,100
Transportation, processing, and other related costs	17,536	14,255	48,498	33,123
Exploration	4,358	27,284	14,327	52,394
Impairment of proved oil and gas properties	49,842	22,886	63,791	39,798
Midstream natural gas gathering, processing, and marketing	52	941	730	66,373
Oilfield services	3,264	3,856	12,153	11,892
Depletion, depreciation, amortization and accretion	23,378	32,147	103,441	89,903
Gain on sale of assets, net	(2,892)	(7,988)	(31,288)	(4,600)
General and administrative	10,060	16,851	34,089	49,621
Total operating expenses	118,316	126,622	286,197	388,840
OPERATING LOSS	(84,652)	(56,065)	(157,611)	(80,765)
OTHER INCOME (EXPENSE)
Interest income	34	40	132	126
Interest expense	(25,031)	(17,936)	(72,598)	(55,827)
Gain (loss) on derivative contracts, net	568	8,262	3,345	(333)
Loss from equity method investments	(176)	(79)	(494)	(436)
Other income (expense)	(1,913)	2,179	(9,666)	2,606
Total other expense, net	(26,518)	(7,534)	(79,281)	(53,864)
LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX	(111,170)	(63,599)	(236,892)	(134,629)
Income tax benefit	0	0	0	0
LOSS FROM CONTINUING OPERATIONS, NET OF TAX	(111,170)	(63,599)	(236,892)	(134,629)
Gain on dilution of interest in Eureka Hunter Holdings, LLC, net of tax	2,211	0	4,601	0
Loss from discontinued operations, net of tax	(4,222)	(59,590)	(8,485)	(101,963)
Loss on disposal of discontinued operations, net of tax	0	(258)	0	(13,983)
NET LOSS	(113,181)	(123,447)	(240,776)	(250,575)
Net loss attributed to non-controlling interests	0	2,764	0	3,653
LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	(113,181)	(120,683)	(240,776)	(246,922)
Dividends on preferred stock	(8,848)	(8,848)	(26,543)	(26,516)
Dividends on preferred stock of discontinued operations	0	(6,644)	0	(19,202)
NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS	$ (122,029)	$ (136,175)	$ (267,319)	$ (292,640)
Weighted average number of common shares outstanding, basic and diluted	231,742,785	199,448,453	213,692,427	185,440,763
Loss from continuing operations per share, basic and diluted	$ (0.52)	$ (0.35)	$ (1.23)	$ (0.85)
Income (loss) from discontinued operations per share, basic and diluted	(0.01)	(0.33)	(0.02)	(0.73)
NET LOSS PER COMMON SHARE, BASIC AND DILUTED	$ (0.53)	$ (0.68)	$ (1.25)	$ (1.58)
Loss from continuing operations, net of tax	$ (111,170)	$ (60,835)	$ (236,892)	$ (130,976)
Income (loss) from discontinued operations, net of tax	(2,011)	(59,848)	(3,884)	(115,946)
Net loss	$ (113,181)	$ (120,683)	$ (240,776)	$ (246,922)

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Statement of Comprehensive Income [Abstract]
Net loss	$ (113,181)	$ (123,447)	$ (240,776)	$ (250,575)
OTHER COMPREHENSIVE INCOME (LOSS)
Foreign currency translation gain (loss)	(2)	0	100	(1,218)
Unrealized loss on available for sale securities	(1,304)	(2,583)	(2,403)	(3,188)
Amounts reclassified for other than temporary impairment of available for sale securities	2,115	0	11,107	0
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	0	0	20,741
Total other comprehensive income	809	(2,583)	8,804	16,335
COMPREHENSIVE LOSS	(112,372)	(126,030)	(231,972)	(234,240)
Comprehensive loss attributable to non-controlling interests	0	2,764	0	3,653
COMPREHENSIVE LOSS ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	$ (112,372)	$ (123,266)	$ (231,972)	$ (230,587)

CONSOLIDATED STATEMENT OF SHARE

CONSOLIDATED STATEMENT OF SHAREHOLDERS' EQUITY (Unaudited) - 9 months ended Sep. 30, 2015 - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock	Additional Paid in Capital	Accumulated Deficit	Accumulated Other Comprehensive Income (loss)	Treasury Stock	Series D Preferred StockPreferred Stock	Series E Preferred StockPreferred Stock
BALANCE (in shares) at Dec. 31, 2014		201,421					4,425	4
BALANCE at Dec. 31, 2014	$ 431,855	$ 2,014	$ 909,783	$ (784,546)	$ (7,765)	$ (3,944)	$ 221,244	$ 95,069
Increase (Decrease) in Shareholders' Equity
Share based compensation (in shares)		1,360
Share based compensation	6,492	$ 14	6,478
Shares withheld for taxes (in shares)		(105)
Shares withheld for taxes	(311)	$ (1)	(310)
Shares of common stock issued for payment of 401k plan matching contribution (shares)		2,291
Shares of common stock issued for payment of 401k plan matching contribution	1,878	$ 23	1,855
Sale of common stock (shares)		56,202
Sale of common stock	58,240	$ 562	57,678
Dividends on preferred stock	(26,543)			(26,543)
Shares of common stock issued upon exercise of common stock options (in shares)		100
Shares of common stock issued upon exercise of common stock options	51	$ 1	50
Net loss	(240,776)			(240,776)
Foreign currency translation gain (loss)	100				100
Unrealized gain on available for sale securities	(2,403)				(2,403)
Amounts reclassified for other than temporary impairment of available for sale securities	11,107				11,107
BALANCE (in shares) at Sep. 30, 2015		261,269					4,425	4
BALANCE at Sep. 30, 2015	$ 239,690	$ 2,613	$ 975,534	$ (1,051,865)	$ 1,039	$ (3,944)	$ 221,244	$ 95,069

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Statement of Cash Flows [Abstract]
Net loss	$ (240,776)	$ (250,575)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion, depreciation, amortization and accretion	103,441	101,733
Exploration	12,579	51,306
Impairment of proved oil and gas properties	63,791	39,798
Impairment of other assets	11,107	666
Share-based compensation	8,059	7,267
Cash paid for plugging wells	(136)	(26)
Loss (gain) on sale of assets	(31,288)	9,371
Loss (gain) on derivative contracts	(3,457)	92,125
Cash proceeds (payment) on settlement of derivative contracts	19,558	(4,074)
Gain on dilution of interest in Eureka Hunter Holdings, LLC	(4,601)	0
Loss from equity method investments	8,979	504
Amortization and write-off of deferred financing costs and discount on Senior Notes included in interest expense	4,587	8,809
Changes in operating assets and liabilities:
Accounts receivable, net	21,305	20,742
Inventory	(276)	4,681
Prepaid expenses and other current assets	35	(2,766)
Accounts payable	60,082	(50,851)
Revenue payable	(1,021)	(2,336)
Accrued liabilities	14,843	(12,819)
Net cash provided by operating activities	46,811	13,555
CASH FLOWS FROM INVESTING ACTIVITIES
Capital expenditures and advances	(164,874)	(363,304)
Change in restricted cash	0	5,000
Change in deposits and other long-term assets	3,389	310
Proceeds from sales of assets	38,384	110,690
Net cash used in investing activities	(123,101)	(247,304)
CASH FLOWS FROM FINANCING ACTIVITIES
Net proceeds from sales of common shares	58,239	178,432
Proceeds from sale of Eureka Hunter Holdings Series A Preferred Units	0	11,956
Proceeds from sale of Eureka Hunter Holdings Series A Common Units	0	8,180
Repurchase of non-controlling interest	0	(2,875)
Proceeds from exercise of warrants and options	51	9,622
Preferred stock dividends	(26,543)	(36,754)
Repayments of debt	(8,684)	(208,298)
Proceeds from borrowings on debt	6,886	279,592
Deferred financing costs	(451)	(6,228)
Change in other long-term liabilities	79	1,032
Net cash provided by financing activities	29,577	234,659
Effect of changes in exchange rate on cash	(4)	44
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	(46,717)	954
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	53,180	41,713
CASH AND CASH EQUIVALENTS, END OF PERIOD	$ 6,463	$ 42,667

GENERAL

GENERAL	9 Months Ended
	Sep. 30, 2015
Accounting Policies [Abstract]
GENERAL	NOTE 1 - GENERAL Organization and Nature of Operations Magnum Hunter Resources Corporation, a Delaware corporation, operating directly and indirectly through its subsidiaries ("Magnum Hunter" or the "Company"), is an Irving, Texas based independent oil and gas company engaged primarily in the exploration for and the exploitation, acquisition, development and production of natural gas and natural gas liquids resources predominantly in shale plays in the United States, along with certain oil field service activities. In addition, the Company has a substantial equity method investment in midstream operations, which is classified as discontinued operations. Presentation of Consolidated Financial Statements The accompanying unaudited interim consolidated financial statements of Magnum Hunter have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). The preparation of these consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during reporting periods. Actual results could differ materially from those estimates. In the opinion of management, all adjustments (consisting of normal recurring adjustments unless otherwise indicated) necessary for the fair statement of the financial position and the results of operations for the interim periods presented have been reflected herein. The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year. The year-end balance sheet data were derived from audited financial statements, but do not include all disclosures required by GAAP. Certain information and disclosures normally included in the consolidated financial statements prepared in accordance with GAAP that would substantially duplicate the disclosures contained in the audited consolidated financial statements as reported in the Company's Annual Report on Form 10-K have been condensed or omitted. These consolidated financial statements should be read in conjunction with the audited consolidated financial statements and notes thereto included in the Company's Annual Report on Form 10-K for the year ended December 31, 2014 , as amended. The consolidated financial statements also reflect the interests of the Company's wholly owned subsidiary, Magnum Hunter Production, Inc. ("MHP"), in various managed drilling partnerships. The Company accounts for the interests in these managed drilling partnerships using the proportionate consolidation method. Reclassification of Prior-Period Balances Certain prior period balances have been reclassified to correspond with current-period presentation. Effective January 1, 2015, the Company adopted ASU 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity, issued by the Financial Accounting Standards Board ("FASB"). ASU 2014-08 updated the requirements for reporting discontinued operations in ASC Subtopic 205-20, Presentation of Financial Statements - Discontinued Operations , by requiring classification as discontinued operations of a component of an entity, a group of components of an entity, or a business (including equity method investments) if the disposal represents a strategic shift that has (or will have) a major effect on an entity's operations and financial results when either 1) the component, group of components of an entity, or a business meet the criteria to be classified as held for sale, 2) are disposed of by sale, or 3) are disposed of other than by sale (e.g. abandonment or a distribution to owners in a spinoff). This ASU was effective prospectively for all disposals (or classification as held for sale) of components of an entity that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years. As a result of the Company's decision in June 2015 to pursue the sale of all of its equity ownership interest in Eureka Hunter Holdings, LLC ("Eureka Hunter Holdings") and the adoption of ASU 2014-08, the Company was required to reclassify the operations of Eureka Hunter Holdings to discontinued operations for all periods presented. See "Note 3 - Acquisitions, Divestitures, and Discontinued Operations" . The Company has separately classified transportation and processing expenses incurred to deliver gas to processing plants and/or to selling points, which were previously included as components of lease operating expenses and severance taxes and marketing, in the accompanying consolidated statements of operations for all periods presented. The Company has also renamed lease operating expenses as "Production costs" and presented transportation and processing expenses as "Transportation, processing, and other related costs" in order to provide more meaningful information on costs associated with production and development. The Company has reclassified approximately $5.2 million of oil and gas transportation, processing and production taxes payables from accounts receivable - oil and natural gas sales to accounts payable as of December 31, 2014. Non-Controlling Interest in Consolidated Subsidiaries Prior to July 24, 2014, the Company owned 87.5% of the equity interests in PRC Williston, LLC ("PRC Williston"), which sold substantially all of its assets on December 30, 2013. On July 24, 2014, the Company executed a settlement and release agreement with Drawbridge Special Opportunities Fund LP and Fortress Value Recovery Fund I LLC f/k/a D.B. Zwirn Special Opportunities Fund, L.P. As a result of this settlement agreement, the Company owns 100% of the equity interests in PRC Williston and has all rights and claims to its remaining assets and liabilities, which are not significant. The net loss attributable to non-controlling interest for PRC Williston is recorded through July 24, 2014. Regulated Activities Sentra Corporation, a wholly owned subsidiary of the Company, owns and operates distribution systems for retail sales of natural gas in south central Kentucky. Sentra Corporation's gas distribution billing rates are regulated by the Kentucky Public Service Commission based on recovery of purchased gas costs. The Company accounts for its operations based on the provisions of the FASB Accounting Standards Codification ("ASC") Subtopic 980-605, Regulated Operations-Revenue Recognition , which requires covered entities to record regulatory assets and liabilities resulting from actions of regulators. During the three and nine months ended September 30, 2015 , gas utility sales from Sentra Corporation's regulated operations aggregated $42,845 and $504,075 , respectively. During the three and nine months ended September 30, 2014 , the Company had revenues of $27,656 and $473,555 , respectively, related to Sentra Corporation's regulated operations. Recently Issued Accounting Standards Accounting standards-setting organizations frequently issue new or revised accounting rules. The Company regularly reviews all new pronouncements to determine their impact, if any, on its financial statements. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) . ASU 2014-09 supersedes the revenue recognition requirements in ASC Topic 605, Revenue Recognition , and most industry-specific guidance throughout the Industry Topics of the ASC. The core principle of the revised standard is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. To achieve that core principle, an entity should apply the following steps: (i) identify the contract(s) with a customer; (ii) identify the performance obligations in the contract; (iii) determine the transaction price; (iv) allocate the transaction price to the performance obligations in the contract; and (v) recognize revenue when (or as) the entity satisfies a performance obligation. ASU 2014-09 requires entities to disclose both quantitative and qualitative information that enables users of financial statements to understand the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. In August 2015, the FASB issued ASU 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date , which defers the effective date of ASU 2014-09 for all entities by one year. As such, this amendment is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those reporting periods. The guidance allows for either a "full retrospective" adoption or a "modified retrospective" adoption, and earlier application is permitted as of annual reporting periods beginning after December 14, 2016, including interim reporting periods within that reporting period. The Company is currently evaluating the adoption methods and the impact of this ASU on its consolidated financial statements and financial statement disclosures. In April 2015, the FASB issued ASU 2015-03, Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs . This update requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by this update. This amendment is effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. Early adoption is permitted for financial statements that have not been previously issued. As of September 30, 2015 , the Company had $19.8 million of debt issuance costs, which under this standard would be reclassified from an asset to a direct deduction from the related debt liability. In April 2015, the FASB issued ASU 2015-04, Intangibles - Goodwill and Other - Internal-Use Software: Customer's Accounting for Fees Paid in a Cloud Computing Agreement . This update provides guidance to customers about whether a cloud computing arrangement includes a software license. If a cloud computing arrangement includes a software license, then the customer should account for the software license element of the arrangement consistent with the acquisition of other software licenses. If a cloud computing arrangement does not include a software license, the customer should account for the arrangement as a service contract. This update does not change GAAP for a customer's accounting for service contracts. This amendment is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Early adoption is permitted for all entities, either prospectively to all arrangements entered into or materially modified after the effective date, or retrospectively. The Company has several cloud computing arrangements and is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.

GOING CONCERN AND LIQUIDITY; FO

GOING CONCERN AND LIQUIDITY; FORBEARANCE AGREEMENTS	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
GOING CONCERN AND LIQUIDITY; FORBEARANCE AGREEMENTS	NOTE 2 - GOING CONCERN AND LIQUIDITY; FORBEARANCE AGREEMENTS As of September 30, 2015, the Company had $6.5 million in cash and a working capital deficit of $1,037.2 million , and the Company continues to incur significant losses from continuing operations. Additionally, as of September 30, 2015, the Company was in default under its senior revolving credit facility (as amended, the "Credit Facility") and Second Lien Credit Agreement (as defined below), as further described below. In addition, the Company has an interest payment due on November 15, 2015 on its Senior Notes (as defined below) of approximately $29.3 million , of which $22.1 million was accrued as of September 30, 2015, which the Company does not expect to be able to pay (but which is the subject of forbearance agreements described below and in "Note 9 - Debt" ). Although the Company has taken proactive measures to address these issues, including entering into such forbearance agreements, these factors raise substantial doubt about the Company's ability to continue as a going concern. The consolidated financial statements do not include any adjustments relating to the recoverability or classification of recorded asset amounts or the amount and classification of liabilities that might be necessary as a result of this uncertainty. As further described in "Note 9 - Debt" , on September 30, 2015, the Company was in default under its Credit Facility and its Second Lien Term Loan Agreement relating to past due accounts payable. Pursuant to covenants contained in the Credit Facility and the Second Lien Term Loan Agreement, the Company is not permitted to have accounts payable outstanding in excess of 180 days from the invoice date (subject to certain permissible amounts). As of September 8, 2015, the Company had approximately $1.4 million in accounts payable outstanding (other than such permissible amounts) in excess of 180 days from the invoice date. Under the terms of the Company's Credit Facility and Second Lien Term Loan Agreement, this default would result in an event of default (as defined in the agreements) if not cured within 30 days. As of October 8, 2015, the Company continued to have accounts payable outstanding (other than such permissible amounts) in excess of 180 days from the invoice date, resulting in an event of default. Due to the event of default, the lenders under the Company's Credit Facility and Second Lien Term Loan Agreement may declare the outstanding loan amounts immediately due and payable. In addition, $3.1 million of certain of the Company's equipment notes payable and certain of the Company's derivatives contracts became callable subsequent to September 30, 2015 as a result of certain cross-default provisions. Accordingly, the Company's debt balances under the Credit Facility, Second Lien Term Loan Agreement, and certain equipment notes payable and derivatives are reflected as current liabilities in the accompanying consolidated balance sheet as of September 30, 2015. Our unsecured 9.750% Senior Notes due 2020 ("Senior Notes") and certain remaining derivatives contracts also contain cross-default or cross-acceleration provisions that may result in the Senior Notes and the remaining derivatives contracts becoming callable if any material obligation is called by a lender due to an event of the default. Specifically, a cross-default under the indenture governing the Senior Notes (the "Indenture") will occur if the lenders under the Company's Credit Facility or Second Lien Term Loan Agreement choose to accelerate the indebtedness under such agreement as a result of the event of default. The Company has not received any notice of acceleration with respect to any of the obligations described above. The Company has an interest payment due on November 15, 2015 on its Senior Notes. Interest on the Senior Notes accrues at an annual rate of 9.75% and is payable semi-annually on May 15 and November 15. The total interest payment due on November 15, 2015 is expected to be approximately $29.3 million , of which $22.1 million was accrued as of September 30, 2015. The failure by the Company to make an interest payment on the Senior Notes within 30 days following the due date would constitute an event of default under the Senior Notes, and the Senior Notes could be declared immediately due and payable. The Company does not expect to make the interest payment by December 15, 2015; however, payments under the Senior Notes are the subject of forbearance agreements described below and in "Note 9 - Debt" . Therefore, the Company's outstanding obligations on its Senior Notes are reflected as current liabilities in the accompanying consolidated balance sheet as of September 30, 2015. On October 9, 2015, the Company announced that it had suspended monthly cash dividends on all of its outstanding series of preferred stock. The suspension commenced with the monthly cash dividend that would otherwise have been declared and paid for the month ending October 31, 2015 and will continue indefinitely. The outstanding shares of Series E Preferred Stock are represented by depositary shares, each representing a 1/1,000th interest of a share of Series E Preferred Stock. Under the terms of the Company's Series C, Series D and Series E Preferred Stock, any unpaid dividends, including the unpaid dividends for the month ending October 31, 2015 and any future unpaid dividends, will continue to accumulate. Additionally, if the Company does not pay dividends on its Series C, Series D and Series E Preferred Stock for any month within a quarter for a total of four quarterly periods (whether consecutive or non-consecutive), (i) the holders of each series of preferred stock will have the right to elect two directors to serve on the Company's Board of Directors (the "Board") until all accumulated and unpaid dividends have been paid in full, (ii) the annual dividend rates on the Series C, Series D and Series E Preferred Stock will be increased to 12.5% , 10.0% and 10.0% , respectively (the "Penalty Rates"), until all accumulated and unpaid dividends have been paid in full and the Company has paid cash dividends at the respective Penalty Rates in full for an additional two consecutive quarters, and (iii) if not paid in cash, dividends must be paid in shares of common stock or (if the common stock is not publicly traded) in shares of the series of preferred stock (until the dividend default has been cured). The Company had previously suspended dividends on its Series C, Series D and Series E Preferred Stock affecting two quarterly periods during 2013. As a result of the suspension of monthly cash dividends on its preferred stock, the Company became ineligible to issue securities, including issuances of common stock in At-the-Market ("ATM") offerings, under its universal shelf Registration Statement on Form S-3, which was declared effective on April 22, 2015. On October 9, 2015, the Company also announced that it has engaged a financial advisor and a special legal advisor to advise management and the Board regarding potential strategic alternatives to enhance liquidity and address the Company's current capital structure, which may include liquidity-enhancing transactions that the Company has commenced previously, as well as restructuring some or all of the Company's debt and preferred equity to preserve cash flow, which may include seeking private restructuring or reorganization under Chapter 11 of the U.S. Bankruptcy Code (the "Bankruptcy Code"). On November 3, 2015, the Company entered into the Sixth Amendment (the "Sixth Amendment") to the Credit Facility by and among the Company, as borrower, the guarantors party thereto, certain holders of the Company's Senior Notes (the "New Senior Notes Lenders"), certain holders of the loans outstanding pursuant to the Company's Second Lien Term Loan Agreement (the "New Second Lien Lenders" and collectively with the New Senior Notes Lenders, the "New First Lien Lenders"), as lenders, Bank of Montreal, as administrative agent and Cantor Fitzgerald Securities, as loan administrator. (as so amended, the "Refinancing Facility") in order to, among other things: i. assign amounts outstanding of approximately $5.0 million under the Credit Facility in the form of a single tranche of term loans to the New First Lien Lenders; ii. cash collateralize certain outstanding letters of credit issued under the Credit Facility in an aggregate amount of approximately $39.0 million ; and iii. provide the Company with an additional new term loan in the aggregate principal amount of approximately $16.0 million , which was funded in full by the New First Lien Lenders on the closing date of the Sixth Amendment. As a result of the Sixth Amendment, the New First Lien Lenders became the lenders under the Refinancing Facility, the Credit Facility was restructured from a senior secured revolving credit facility to a senior secured term loan facility represented by the Refinancing Facility and the aggregate amounts outstanding under the Refinancing Facility as of the closing date of the Sixth Amendment totaled approximately $60.0 million . In addition, the Refinancing Facility includes an uncommitted incremental credit facility for up to an additional $10.0 million aggregate principal amount of term loans to be provided to the Company, if and to the extent requested by the Company and agreed to by a specified percentage of the New First Lien Lenders. The Refinancing Facility contains the same covenants as the Credit Facility prior to execution of the Sixth Amendment, subject to customary adjustments consistent with financings of this type and duration and subject to the following additional changes: i. removal of all financial covenants in effect prior to the Sixth Amendment (including the current ratio, total secured net debt to EBITDAX, proved reserves coverage ratio and proved developed producing reserves coverage ratio covenants). ii. removal of restrictions against trade payables being outstanding for more than 180 days from the date of invoice, and iii. inclusion of budgetary and reporting requirements consistent with financings of this type and duration, including a cumulative budget variance covenant tested every other week, in accordance with the terms of the Refinancing Facility. The Company believes that the Refinancing Facility will provide the Company with liquidity for approximately 30 to 45 days, during which time the Company and the New First Lien Lenders will continue to discuss various options and alternatives regarding the Company's balance sheet. See "Note 9 - Debt" . On November 3, 2015, the Company and the New Senior Notes Lenders entered into a Forbearance Agreement (the "Forbearance Agreement") whereby the New Senior Notes Lenders agreed to forbear during a certain period from exercising any remedies as a result of any default, Default or Event of Default under (as such terms are defined in) the Indenture that is present as a result of (i) the failure of the Company to make any interest payment otherwise due under the Senior Notes, (ii) a breach of the debt incurrence covenant under the Indenture, or (iii) the failure of the Company to make any interest payment otherwise due pursuant to the Second Lien Term Loan Agreement. Additionally, the New Senior Notes Lenders consented to an amendment to the Indenture, pursuant to a supplemental indenture, which such amendment amends the incurrence of indebtedness covenant in the Indenture to permit the incurrence of the $70.0 million aggregate principal amount of borrowings under the Refinancing Facility. See "Note 9 - Debt" . On November 3, 2015, the Company entered into a Forbearance Agreement and Second Amendment (the "Second Amendment") to the Second Lien Credit Agreement, by and among the Company, as borrower, Credit Suisse AG, Cayman Islands Branch, as administrative agent and collateral agent, the lenders party thereto and the agents party thereto (the "Second Lien Term Loan Agreement"). The Second Amendment provides for a forbearance by the lenders under the Second Lien Term Loan Agreement that entered into the Refinancing Facility with respect to exercising remedies regarding any default or event of default that results from the failure of the Company to make any interest payment under the Second Lien Term Loan Agreement, the failure to meet certain financial covenants, and certain other matters (including the default that arose on account of trade payables being outstanding for more than 180 days). The Second Amendment also amends certain other terms of the Second Lien Term Loan Agreement as necessary to permit the Refinancing Facility and to make certain covenants in the Second Lien Term Loan Agreement consistent with the revised covenants in the Refinancing Facility. See "Note 9 - Debt" . Triad Hunter, LLC ("Triad Hunter"), a wholly owned subsidiary of the Company, and Eureka Hunter Pipeline, LLC ("Eureka Hunter Pipeline") are parties to an Amended and Restated Gas Gathering Services Agreement (the "Gas Gathering Services Agreement"). Under the terms of the Gas Gathering Services Agreement, Triad Hunter reserved throughput capacity in the gas gathering pipeline system of Eureka Hunter Pipeline for which Triad Hunter has committed to minimum reservation fees of approximately $0.75 per MMBtu. As of October 31, 2015, Triad Hunter owed Eureka Hunter Pipeline approximately $10.7 million in past due gathering fees under the Gas Gathering Services Agreement. On November 5, 2015, the Company received a demand notice from MSI (as defined under "Discontinued Operations - Eureka Hunter Holdings" in Note 3 below), on behalf of Eureka Hunter Pipeline, demanding, in connection with past due amounts, adequate assurance of performance of security in the amount of approximately $20.8 million on or before November 10, 2015. Additionally, Eureka Hunter Pipeline can also demand adequate assurance of performance for any payments if it determines that Triad Hunter’s credit is unsatisfactory. MSI advised the Company that its failure to provide such adequate assurance of performance by the specified deadline will result in a suspension of services under the Gas Gathering Services Agreement until such time as the Company provides such adequate assurance of performance. MSI further advised the Company that if the Company has not provided the adequate assurance of performance and/or paid in full all amounts past due by November 20, 2015, then Eureka Hunter Pipeline will terminate the Gas Gathering Services Agreement. The Company does not expect that it will be able to provide such adequate assurance of performance by the specified deadline. The Company has initiated discussions with MSI regarding a forbearance by Eureka Hunter Pipeline and MSI of their rights and remedies with respect to past due amounts under the Gas Gathering Services Agreement, including the provision of adequate assurance of performance. The Company can provide no assurance regarding whether a forbearance will be obtained. If such forbearance is not obtained, and Eureka Hunter Pipeline suspends performance under or terminates the Gas Gathering Services Agreement, such suspension in service or termination would force a temporary shut-in of certain of our wells (until the suspension is lifted or new gas gathering services are arranged) and could materially impact our business, financial condition and results of operations. We cannot predict at this time whether we would be able to secure any alternate gas gathering services or the timing thereof, especially in view of the limited amount of gas gathering service capacity in these areas of operation. Even if such services became available to us, such services may not be on terms we find suitable or attractive. See "Item 1A. Risk Factors - We are and may continue to become subject to claims by vendor creditors.”

ACQUISITIONS, DIVESTITURES, AND

ACQUISITIONS, DIVESTITURES, AND DISCONTINUED OPERATIONS	9 Months Ended
	Sep. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
ACQUISITIONS AND DISCONTINUED OPERATIONS	NOTE 3 - ACQUISITIONS, DIVESTITURES, AND DISCONTINUED OPERATIONS Acquisitions Agreement to Purchase Utica Shale Acreage On August 12, 2013, Triad Hunter entered into an asset purchase agreement ("the MNW Purchase Agreement") with MNW Energy, LLC ("MNW"). MNW is an Ohio limited liability company that represents an informal association of various land owners, lessees and sub-lessees of mineral acreage who own or have rights in mineral acreage located in Monroe, Noble and/or Washington Counties, Ohio. Pursuant to the purchase agreement, Triad Hunter agreed to acquire from MNW up to 32,000 net mineral acres, including currently leased and subleased acreage, located in such counties, over a period of time, in staggered closings, subject to certain conditions. The maximum purchase price, if MNW delivers 32,000 acres with acceptable title, would be $142.1 million , excluding title costs. During the nine months ended September 30, 2015 and 2014 , Triad Hunter purchased 2,665 and 11,296 net leasehold acres, respectively, from MNW for an aggregate purchase price of $12.0 million and $46.7 million , respectively. As of September 30, 2015 , Triad Hunter had purchased a total of 25,044 net leasehold acres from MNW for an aggregate purchase price of $103.9 million . The Company believes that MNW will not be able to provide Triad Hunter with satisfactory title to any of the remaining net leasehold acres subject to purchase under the MNW Purchase Agreement, and therefore the Company anticipates that none of the remaining net leasehold acres will be acquired by Triad Hunter. Divestitures Sale of Certain West Virginia Assets On May 22, 2015, Triad Hunter entered into a Purchase and Sale Agreement with Antero Resources Corporation ("Antero") pursuant to which Triad Hunter agreed to sell to Antero all of Triad Hunter's right, title and interest in certain undeveloped and unproven leasehold acreage located in Tyler County, West Virginia. The sale transaction closed on June 18, 2015 and Triad Hunter received cash consideration of $33.6 million , subject to post-closing adjustments for any title defects and for remediation of asserted title defects. During the third quarter of 2015, the Company received $4.2 million of additional consideration for title defects cured or removed. The properties sold consisted of ownership interests in approximately 5,210 net leasehold acres. The Company recognized a gain on the sale of $5.5 million and $31.7 million during the three and nine month periods ended September 30, 2015. Discontinued Operations Williston Hunter Canada, Inc. In September 2013, the Company adopted a plan to divest all of its interests in the Canadian operations of Williston Hunter Canada, Inc. ("WHI Canada"), which was a wholly owned subsidiary of the Company. The Company closed on the sale of its interests in WHI Canada on May 12, 2014. The loss from operations and loss on disposal attributable to WHI Canada are included in discontinued operations. Eureka Hunter Holdings In June 2015, the Company announced its decision to pursue the sale of all of its equity ownership interest in Eureka Hunter Holdings in order to improve the Company's liquidity position. The Company has reclassified its equity method investment in Eureka Hunter Holdings to assets of discontinued operations as of September 30, 2015 and December 31, 2014 . All operations related to periods prior to December 18, 2014, and all subsequent equity method losses through September 30, 2015, are reflected as discontinued operations. Prior to December 18, 2014, Eureka Hunter Holdings was a consolidated subsidiary of the Company and its operations were included in the Midstream and Marketing operating segment. Following a series of transactions and capital contributions that occurred up to and including December 18, 2014, the Company determined it no longer held a controlling financial interest in Eureka Hunter Holdings. However, the Company exercises significant influence through its retained equity interest and through representation on Eureka Hunter Holdings' board of managers and owned 44.53% of the outstanding membership interest of Eureka Hunter Holdings as of September 30, 2015 . As a result, the Company uses the equity method to account for its retained interest in Eureka Hunter Holdings. On November 18, 2014, the Company entered into a letter agreement (the "November 2014 Letter Agreement") with Eureka Hunter Holdings and MSIP II Buffalo Holdings, LLC ("MSI"), an affiliate of Morgan Stanley Infrastructure II Inc. Pursuant to the November 2014 Letter Agreement, the parties agreed that, among other things, the Company would make a $13.3 million capital contribution (the "MHR 2015 Contribution") in cash to Eureka Hunter Holdings on or before March 31, 2015, in exchange for additional Series A-1 Units in Eureka Hunter Holdings. On March 30, 2015, the Company, Eureka Hunter Holdings and MSI entered into an additional letter agreement (the "March 2015 Letter Agreement"), pursuant to which the parties agreed that, among other things, (i) the Company is no longer required to make the MHR 2015 Contribution and (ii) MSI would make certain additional capital contributions to Eureka Hunter Holdings in exchange for additional Series A-2 Units. Pursuant to the March 2015 Letter Agreement, MSI purchased additional Series A-2 Units of Eureka Hunter Holdings as follows: i. On March 31, 2015, MSI made a capital contribution in cash to Eureka Hunter Holdings of approximately $27.2 million (the "2015 Growth CapEx Projects Contribution") in exchange for additional Series A-2 Units in Eureka Hunter Holdings with the proceeds of such capital contribution to be used to fund certain of Eureka Hunter Pipeline's 2015 capital expenditures. The 2015 Growth CapEx Projects Contribution is subject to the Company's right to make an MHR Catch-Up Contribution (as defined in the Second Amended and Restated Limited Liability Company Agreement of Eureka Hunter Holdings (the "LLC Agreement")). ii. On March 31, 2015, MSI made an additional capital contribution in cash to Eureka Hunter Holdings of approximately $37.8 million (the "Additional Contribution") in exchange for additional Series A-2 Units in Eureka Hunter Holdings with the proceeds of such Additional Contribution to be used to fund certain of Eureka Hunter Pipeline's additional capital expenditures and for certain other uses. Immediately after giving effect to these transactions, the Company and MSI owned 45.53% and 53.00% , respectively, of the equity interests of Eureka Hunter Holdings, with the Company's equity ownership consisting of Series A-1 Units and MSI's equity ownership consisting of Series A-2 Units. Pursuant to the March 2015 Letter Agreement, the parties further agreed that the Company had the right, in its discretion, to fund as a capital contribution to Eureka Hunter Holdings, all or a portion (in specified minimum amounts) of its pro-rata share of the Additional Contribution, which pro-rata share equaled approximately $18.7 million (the "MHR Additional Contribution Component"), before June 30, 2015 (as extended, the "MHR Contribution Deadline"), in exchange for additional Series A-1 Units in Eureka Hunter Holdings (the "MHR 2015 Make-up Contribution"). On July 27, 2015, the Company entered into an additional letter agreement (the "July 2015 Letter Agreement") with Eureka Hunter Holdings and MSI pursuant to which the parties memorialized an agreement in principle which had been reached prior to June 30, 2015, to extend the MHR Contribution Deadline to the earlier of (i) September 30, 2015 or (ii) the day immediately preceding the date on which the Company disposes, in a sale transaction or otherwise, its equity ownership interest in Eureka Hunter Holdings. As of September 30, 2015, the Company had not funded the MHR Additional Contribution Component, and as such, the Company's Series A-1 Units in Eureka Hunter Holdings were adjusted downward by 529,190 units, which was an amount equivalent to the unfunded portion of the MHR Additional Contribution Component divided by the purchase price per unit paid by MSI in connection with the 2015 Growth CapEx Projects Contribution and the Additional Contribution. As a result of the downward adjustment to its Series A-1 Units, the Company recognized a loss of $7.7 million reported net of tax in "Loss from discontinued operations, net of tax" on the consolidated statements of operations during the three and nine months ended September 30, 2015 . The loss included the Company's proportionate decrease in its equity method basis difference which was reduced by $4.0 million during the three and nine months ended September 30, 2015, based on the change in the Company's ownership in the net assets of Eureka Hunter Holdings related to the downward adjustment in its Series A-1 Units. The Company continues to have the right to make MHR Catch-Up Contributions (as defined in the LLC Agreement) in accordance with the LLC Agreement (as modified by the November 2014 Letter Agreement as to the applicable time and amount limitations) in respect of any MHR Shortfall Amounts (as defined in the LLC Agreement) that are eligible to be funded by the Company under the LLC Agreement. The Company accounted for the March 31, 2015 MSI capital contributions, the issuance of additional Series A-2 Units by Eureka Hunter Holdings, and the September 30, 2015 expiration of the MHR Contribution Deadline in accordance with the subsequent measurement provision of ASC Topic 323, Investments - Equity Method and Joint Ventures , which requires the Company to recognize a gain or loss on the dilution of its equity interest as if the Company had sold a proportionate interest in Eureka Hunter Holdings. During the three and nine months ended September 30, 2015 , the Company recognized a gain of $2.2 million and $4.6 million , respectively, reported net of tax in "Gain on dilution of interest in Eureka Hunter Holdings, LLC, net of tax" in the consolidated statements of operations based on the difference between the carrying value of the Company's Series A-1 Units and the proceeds received by Eureka Hunter Holdings for the issuance of additional Series A-2 Units to MSI which resulted in permanent dilution of the Company's equity interest in Eureka Hunter Holdings. The gain included the Company's proportionate decrease in its equity method basis difference which was reduced by $3.6 million and $7.5 million , during the three and nine months ended September 30, 2015 , respectively, based on the change in the Company's ownership in the net assets of Eureka Hunter Holdings after giving effect to the dilution of the Company's interest as a result of the unit issuance. As of September 30, 2015 , the Company and MSI owned 44.53% and 53.98% , respectively, of the Class A Common Units of Eureka Hunter Holdings. As of December 31, 2014, the Company and MSI owned 48.60% and 49.84% , respectively of the equity interests of Eureka Hunter Holdings. The Company recorded its retained interest in Eureka Hunter Holdings initially at a fair value of $347.3 million as of December 18, 2014. The carrying value of the Company's equity interest in Eureka Hunter Holdings was $343.3 million and $347.2 million at September 30, 2015 and December 31, 2014 , respectively. The recognition of the Company's retained interest in Eureka Hunter Holdings at fair value upon deconsolidation resulted in a basis difference between the carrying value of the Company's investment in Eureka Hunter Holdings and its proportionate share in net assets of Eureka Hunter Holdings. The basis difference was accounted for using the acquisition method of accounting, which requires that the basis difference be allocated to the identifiable assets of Eureka Hunter Holdings at fair value and based upon the Company's proportionate ownership. Determining the fair value of assets and liabilities is judgmental in nature and involves the use of significant estimates and assumptions. The Company recognized a basis difference of $201.9 million upon deconsolidation related to its investment in Eureka Hunter Holdings which has been allocated to the following identifiable assets of Eureka Hunter Holdings: Identifiable Assets Ending Basis December 31, 2014 Basis Amortization Basis Reduction Ending Basis September 30, 2015 (in thousands) Fixed assets $ 5,088 $ (187 ) $ (289 ) $ 4,612 Intangible assets 155,189 (5,471 ) (8,727 ) 140,991 Goodwill 41,597 — (2,518 ) 39,079 Total basis difference $ 201,874 $ (5,658 ) $ (11,534 ) $ 184,682 The components of the Company's basis difference, excluding goodwill, are being amortized over their estimated useful lives ranging from 3 to 39 years. During the second quarter of 2015, the Company completed its valuation of the identifiable assets to which the basis difference is attributable and has recorded amortization based on this valuation for the period ended September 30, 2015 . Summarized income information for Eureka Hunter Holdings for the three and nine months ended September 30, 2015 is as follows: Three Months Ended Nine Months Ended (in thousands) Operating revenues $ 22,457 $ 53,581 Operating income $ 12,231 $ 13,549 Net income $ 11,469 $ 10,623 Magnum Hunter's interest in Eureka Hunter Holdings net income (loss) $ 5,222 $ 4,837 Basis difference amortization $ (1,780 ) $ (5,658 ) Loss on downward adjustment of units $ (7,664 ) $ (7,664 ) Magnum Hunter's equity in earnings (loss), net $ (4,222 ) $ (8,485 ) As of September 30, 2015 and December 31, 2014 , the Company had assets of discontinued operations of $343.3 million and $347.2 million , respectively, consisting of its equity method investment in Eureka Hunter Holdings. The Company included the results of operations related to Eureka Hunter Holdings for all periods presented, and the results of operations of WHI Canada through May 12, 2014, the date of sale, in discontinued operations. The following presents the results of the Company's discontinued operations for the three and nine months ended September 30, 2015 and 2014 . Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in thousands) Revenues $ — $ 9,113 $ — $ 32,073 Depreciation, depletion, amortization and accretion — (4,224 ) — (11,831 ) Other operating expenses — (6,401 ) — (23,703 ) Interest expense — (159 ) — (6,646 ) Loss on derivative contracts, net — (57,898 ) — (91,792 ) Loss from equity method investments (4,222 ) — (8,485 ) — Other expense — (21 ) — (64 ) Loss from discontinued operations, net of tax (4,222 ) (59,590 ) (8,485 ) (101,963 ) Gain on dilution of interest in Eureka Hunter Holdings, net of tax 2,211 — 4,601 — Loss on disposal of discontinued operations, net of taxes of $0 — (258 ) — (13,983 ) Loss from discontinued operations, net of taxes $ (2,011 ) $ (59,848 ) $ (3,884 ) $ (115,946 ) Total operating cash inflows related to Eureka Hunter Holdings for the three and nine month periods ended September 30, 2014 were $28.9 million and $67.3 million , respectively, and total investing cash outflows related to Eureka Hunter Holdings for the three and nine month periods ended September 30, 2014 were $46.7 million and $111.1 million , respectively.

OIL & NATURAL GAS SALES

OIL & NATURAL GAS SALES	9 Months Ended
	Sep. 30, 2015
Other Income and Expenses [Abstract]
Oil & Natural Gas Sales	NOTE 4 - OIL & NATURAL GAS SALES During the three and nine months ended September 30, 2015 and 2014 , the Company recognized sales from oil, natural gas, and natural gas liquids ("NGLs") as follows: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in thousands) Oil $ 9,962 $ 34,495 $ 34,593 $ 111,354 Natural gas 14,532 18,247 59,415 74,031 NGLs 3,358 9,768 16,653 36,862 Total oil and natural gas sales $ 27,852 $ 62,510 $ 110,661 $ 222,247

PROPERTY, PLANT, & EQUIPMENT

PROPERTY, PLANT, & EQUIPMENT	9 Months Ended
	Sep. 30, 2015
Property, Plant and Equipment [Abstract]
Property, Plant, & Equipment	NOTE 5 - PROPERTY, PLANT, & EQUIPMENT Oil and Natural Gas Properties The following sets forth the net capitalized costs under the successful efforts method for oil and natural gas properties as of: September 30, December 31, (in thousands) Mineral interests in properties Unproved leasehold costs $ 442,799 $ 481,643 Proved leasehold costs 276,818 257,185 Wells and related equipment and facilities 602,258 606,406 Advances to operators for wells in progress 1,278 1,411 Total costs 1,323,153 1,346,645 Less accumulated depletion, depreciation, and amortization (344,006 ) (248,410 ) Net capitalized costs $ 979,147 $ 1,098,235 Proved oil and natural gas properties are reviewed for impairment on a field-by-field basis bi-annually or when events and circumstances indicate a possible decline in the recoverability of the carrying amount of such property. Impairments of proved properties of $49.8 million and $63.8 million were recorded during the three and nine months ended September 30, 2015 , respectively, primarily related to Appalachian Basin and Williston Basin properties. Impairments of proved properties of $22.9 million and $39.8 million were recorded for the three and nine months ended September 30, 2014 , respectively, which were comprised primarily of impairments recorded on MHP's proved oil and natural gas properties. Depletion, depreciation, and amortization expense for proved oil and natural gas properties was $20.8 million and $95.7 million for the three and nine months ended September 30, 2015 , respectively, and $28.0 million and $81.9 million for the three and nine months ended September 30, 2014 , respectively. Exploration Exploration expense consists primarily of abandonment charges, exploratory dry holes, geological and geophysical costs, and impairment expense for capitalized leasehold costs associated with unproved properties for which the Company has no further exploration or development plans. During the three and nine months ended September 30, 2015 and 2014 , the Company recognized exploration expense as follows: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in thousands) Leasehold impairments Williston Basin $ 1,898 $ 17,846 $ 9,504 $ 37,765 Appalachian Basin 1,789 7,150 2,952 9,720 Western Kentucky — 1,925 — 3,820 South Texas 124 — 124 — Total leasehold impairments 3,811 26,921 12,580 51,305 Geological and geophysical 547 363 1,747 1,089 Total exploration expense $ 4,358 $ 27,284 $ 14,327 $ 52,394 Impairments of leases in the Williston and Appalachian Basins for all periods presented are related to leases that expired and had no exploration activities during the period or are expected to expire and that the Company does not plan to develop or extend. The Company also recognized $1.9 million and $3.8 million in leasehold impairment expense related to fair value write-downs of MHP for the three and nine months ended September 30, 2014 , respectively. Gas Transportation, Gathering, and Processing Equipment and Other The historical cost of gas transportation, gathering, and processing equipment and other property, presented on a gross basis with accumulated depreciation, as of September 30, 2015 and December 31, 2014 is summarized as follows: September 30, December 31, (in thousands) Gas transportation, gathering and processing equipment and other $ 102,959 $ 100,436 Less accumulated depreciation (28,542 ) (23,013 ) Net capitalized costs $ 74,417 $ 77,423 Depreciation expense for gas transportation, gathering, and processing equipment and other property was $1.9 million and $5.8 million for the three and nine months ended September 30, 2015 , respectively, and $2.7 million and $5.8 million for the three and nine months ended September 30, 2014 , respectively.

ASSET RETIREMENT OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS	9 Months Ended
	Sep. 30, 2015
Asset Retirement Obligation Disclosure [Abstract]
ASSET RETIREMENT OBLIGATIONS	NOTE 6 - ASSET RETIREMENT OBLIGATIONS The following table summarizes the Company's asset retirement obligation ("ARO") activities during the nine -month period ended September 30, 2015 and for the year ended December 31, 2014 : September 30, 2015 December 31, 2014 (in thousands) Asset retirement obligations at beginning of period $ 26,524 $ 16,216 Liabilities incurred 40 218 Liabilities settled (136 ) (107 ) Liabilities sold (74 ) (2,598 ) Accretion expense 1,928 1,478 Revisions in estimated liabilities (1) (596 ) 3,208 Reclassified from liabilities associated with assets of MHP — 8,109 Asset retirement obligation at end of period 27,686 26,524 Less: current portion (included in other liabilities) (1,235 ) (295 ) Asset retirement obligations, net of current portion $ 26,451 $ 26,229 ________________________________ (1) Revisions in estimated liabilities during 2014 relate to a change in assumptions used with respect to certain wells in the Appalachian Basin in Ohio and West Virginia.

FAIR VALUE OF FINANCIAL INSTRUM

FAIR VALUE OF FINANCIAL INSTRUMENTS	9 Months Ended
	Sep. 30, 2015
Fair Value Disclosures [Abstract]
FAIR VALUE OF FINANCIAL INSTRUMENTS	NOTE 7 - FAIR VALUE OF FINANCIAL INSTRUMENTS GAAP defines fair value as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. GAAP also establishes a framework for measuring fair value and a valuation hierarchy based upon the transparency of inputs used in the valuation of an asset or liability. Classification within the hierarchy is based upon the lowest level of input that is significant to the fair value measurement. The valuation hierarchy contains three levels: • Level 1 — Quoted prices (unadjusted) for identical assets or liabilities in active markets • Level 2 — Quoted prices for similar assets or liabilities in active markets; quoted prices for identical or similar assets or liabilities in markets that are not active; and model-derived valuations whose inputs or significant value drivers are observable • Level 3 — Significant inputs to the valuation model are unobservable Transfers between levels of the fair value hierarchy occur at the end of the reporting period in which it is determined that the observability of significant inputs has increased or decreased. There were no transfers between levels of the fair value hierarchy during the nine month periods ended September 30, 2015 and 2014 . The Company used the following fair value measurements for certain of the Company's assets and liabilities at September 30, 2015 and December 31, 2014 : Level 1 Classification: Available for Sale Securities At September 30, 2015 and December 31, 2014 , the Company held common and preferred stock of publicly traded companies with quoted prices in an active market. Accordingly, the fair market value measurements of these securities have been classified as Level 1. Level 2 Classification: Commodity Derivative Instruments At September 30, 2015 and December 31, 2014 , the Company had commodity derivative financial instruments in place. The Company does not designate its derivative instruments as hedges and therefore does not apply hedge accounting. Changes in fair value of derivative instruments subsequent to the initial measurement are recorded as gain (loss) on derivative contracts, in other income (expense). The estimated fair value amounts of the Company's commodity derivative instruments have been determined at discrete points in time based on relevant market information which resulted in the Company classifying such derivatives as Level 2. Although the Company's commodity derivative instruments are valued using public indices, the instruments themselves are traded with unrelated counterparties and are not openly traded on an exchange. As of September 30, 2015 and December 31, 2014 , the Company's derivative contracts were with financial institutions, many of which were either senior lenders to the Company or affiliates of such senior lenders, and some of which had investment grade credit ratings. Certain counterparties to the Company's commodity derivatives positions are no longer participants in the Company's credit facilities following the execution of new credit agreements on October 22, 2014 and an amendment on July 10, 2015. See "Note 9 - Debt" . All of the counterparties are believed to have minimal credit risk. Although the Company is exposed to credit risk to the extent of nonperformance by the counterparties to these derivative contracts, the Company does not anticipate such nonperformance and monitors the credit worthiness of its counterparties on an ongoing basis. Level 3 Classification: Convertible Security Embedded Derivative The Company recognized an embedded derivative asset resulting from the fair value of the bifurcated conversion feature associated with the convertible note it received in February 2012 as partial consideration upon the sale of Hunter Disposal, LLC ("Hunter Disposal") to GreenHunter Resources, Inc. ("GreenHunter"), a related party. The embedded derivative was valued using a Black-Scholes model valuation of the conversion option. The key inputs used in the Black-Scholes option pricing model were as follows: September 30, 2015 Life (in years) 1.4 Risk-free interest rate 0.60% Estimated volatility 92% Dividend — GreenHunter stock price at end of period $0.30 The sensitivity of the estimate of volatility used in determining the fair value of the convertible security embedded derivative would not have a significant impact to the Company's financial statements based on the value of its assets as compared to the financial statements as a whole. The following tables present the fair value hierarchy levels of the Company's financial assets and liabilities which are measured and carried at fair value on a recurring basis: Fair Value Measurements on a Recurring Basis September 30, 2015 (in thousands) Assets Level 1 Level 2 Level 3 Available for sale securities $ 968 $ — $ — Commodity derivative assets — 1,051 — Convertible security derivative assets — — 3 Total assets at fair value $ 968 $ 1,051 $ 3 Liabilities Commodity derivative liabilities $ — $ 569 $ — Total liabilities at fair value $ — $ 569 $ — Fair Value Measurements on a Recurring Basis December 31, 2014 (in thousands) Assets Level 1 Level 2 Level 3 Available for sale securities $ 3,864 $ — $ — Commodity derivative assets — 16,511 — Convertible security derivative assets — — 75 Total assets at fair value $ 3,864 $ 16,511 $ 75 The following table presents the changes in fair value of the derivative assets and liabilities measured at fair value using significant unobservable inputs (Level 3 inputs) for the nine -month period ended September 30, 2015 : Convertible Security Embedded Derivative Asset (in thousands) Fair value as of December 31, 2014 $ 75 Decrease in fair value recognized in gain (loss) on derivative contracts, net (72 ) Fair value as of September 30, 2015 $ 3 Other Fair Value Measurements The following table presents the carrying amounts and fair values categorized by fair value hierarchy level of the Company's financial instruments not carried at fair value: September 30, 2015 December 31, 2014 Fair Value Hierarchy Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value (in thousands) Senior Notes Level 2 $ 597,521 $ 275,700 $ 597,355 $ 498,000 MHR Senior Revolving Credit Facility Level 3 $ 5,000 $ 5,000 $ — $ — MHR Second Lien Term Loan Level 3 $ 327,469 $ 319,873 $ 329,140 $ 329,140 Equipment Notes Payable Level 3 $ 17,990 $ 17,990 $ 22,238 $ 22,150 The fair value of the Company's Senior Notes is based on quoted market prices available for Magnum Hunter's Senior Notes. The fair value hierarchy for the Company's Senior Notes is Level 2 (quoted prices for identical or similar assets in markets that are not active). The carrying value of the Company's Credit Facility approximates fair value as the facility is subject to short-term floating interest rates that approximate the rates available to the Company at these dates. The fair value hierarchy for the Credit Facility is Level 3. The fair value of all fixed-rate notes and the credit facility is based on interest rates currently available to the Company. Fair Value on a Non-Recurring Basis The Company follows the provisions of ASC Topic 820, Fair Value Measurement , for non-financial assets and liabilities measured at fair value on a non-recurring basis. As it relates to the Company, ASC Topic 820 applies to certain non-financial assets and liabilities as may be acquired in a business combination and thereby measured at fair value, measurements of impairments, and the initial recognition of asset retirement obligations, for which fair value is used. ARO estimates are derived from historical costs as well as management's expectation of future cost environments. As there is no corroborating market activity to support the assumptions used, the Company has designated these measurements as Level 3. A reconciliation of the beginning and ending balances of the Company's ARO is presented in "Note 6 - Asset Retirement Obligations" . The Company recorded impairment charges of $63.8 million during the nine months ended September 30, 2015 as a result of writing down the carrying value of certain proved properties to estimated fair value. The fair value of the properties impaired was $511.2 million as of September 30, 2015 . In order to determine the amounts of the impairment charges, Magnum Hunter compares net capitalized costs of proved oil and natural gas properties to estimated undiscounted future net cash flows using management's expectations of economically recoverable proved, probable, and possible reserves. If the net capitalized cost exceeds the undiscounted future net cash flows, Magnum Hunter impairs the net cost basis down to the discounted future net cash flows, which is management's estimate of fair value. Significant inputs used to determine the fair value include estimates of: (i) reserves; (ii) future operating and development costs; (iii) future commodity prices; and (iv) a discounted cash flow model utilizing a 10% discount rate. The underlying commodity prices embedded in the Company's estimated cash flows are the product of a process that begins with forward curve pricing, adjusted for estimated location and quality differentials, as well as other factors that Magnum Hunter's management believes will impact realizable prices. The inputs used by management for the fair value measurements utilized in this review include significant unobservable inputs, and therefore, the fair value measurements employed are classified as Level 3 for these types of assets. The Company recorded impairment charges of $16.8 million during the first quarter of 2014 in order to record MHP at the estimated selling price less costs to sell, based on additional information on estimated selling prices obtained through active marketing of the assets. The fair value of these net assets was $60.0 million as of March 31, 2014. The Company had designated this valuation as Level 3. Effective September 2014, the Company withdrew its plan to divest MHP. As of September 2014, the Company remeasured the carrying value of certain long-lived assets of MHP previously classified as held for sale at their fair value in connection with their reclassification to asset held and used and recorded impairment charges of $1.9 million in exploration expense and $17.0 million in impairment of proved oil and gas properties. The fair value of these assets was $52.6 million as of September 30, 2014, and was derived using a variety of assumptions including market precedent transactions for similar assets, analyst pricing, and risk-adjusted discount rates for similar transactions. The Company has designated these valuations as Level 3. Effective September 2014, the assets and liabilities of MHP are presented as held for use and the results of MHP's operations are presented in continuing operations for all periods presented in these interim consolidated financial statements.

INVESTMENTS AND DERIVATIVES

INVESTMENTS AND DERIVATIVES	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
INVESTMENTS AND DERIVATIVES	NOTE 8 - INVESTMENTS AND DERIVATIVES Investment Holdings - Available for Sale Securities The Company's investment holdings in available for sale securities are concentrated in three issuers whose business activities are related to the oil and natural gas or minerals mining industries. These investments are ancillary to the Company's overall operating strategy and such concentrations of risk related to investment holdings do not pose a substantial risk to the Company's operational performance. The Company evaluates factors that it believes could influence the fair value of the issuers' securities such as management, assets, earnings, cash generation, and capital needs. The fair values of equity securities fluctuate based upon changes in market prices. Gross unrealized losses on investments are considered for other-than-temporary impairment when such losses have continued for more than a 12-month period. However, security-specific circumstances may arise where an investment is considered impaired when gross unrealized losses have been observed for less than twelve months. At December 31, 2014 , the Company did not hold any equity securities which were in a gross unrealized loss position for greater than a year, and no impairments were recognized for the period then ended. As of March 31, 2015, the Company's investment in New Standard Energy Limited ("NSE"), an Australian Securities Exchange-listed Australian company, had been in a gross unrealized loss position for greater than a year. The Company reviewed its investment for impairment and considered such factors as NSE's future business outlook, the prevailing economic environment and the overall market condition for the Company's investment. As a result of its review, the Company recorded an other-than-temporary impairment of $9.0 million which was reclassified from accumulated other comprehensive income into "Other expense" on the consolidated statements of operations during the first quarter of 2015, related to the decline in value of its investment in NSE. Effective October 20, 2015, the Company sold its entire investment in NSE for cash consideration of approximately AUD $0.7 million (approximately $0.5 million USD). The Company recognized a gain on the sale of approximately $0.1 million . At September 30, 2015, the Company's investments in common shares of Redstar Gold Corp. and Series C Preferred shares of GreenHunter were in gross unrealized loss positions for greater than a year. The Company reviewed the business outlook and market conditions for these investments and recorded other-than-temporary impairment of $0.4 million and $1.8 million related to the decline in value of its investments in common shares of Redstar Gold Corp. and its Series C Preferred shares of GreenHunter, respectively, which were reclassified from accumulated other comprehensive income into "Other expense" on the consolidated statements of operations during the third quarter of 2015. Investment Holdings - GreenHunter The Company holds an equity method investment in common shares of GreenHunter received as partial consideration for the sale by Triad Hunter of its equity ownership interest in Hunter Disposal to GreenHunter in 2012. The GreenHunter common stock investment had no carrying value at September 30, 2015 or December 31, 2014 . The GreenHunter common shares are publicly traded and had a fair value of $0.5 million and $1.3 million at September 30, 2015 and December 31, 2014 , respectively, which is not reflected in the carrying value since the Company's investment is accounted for using the equity method. Below is a summary of changes in investments for the nine months ended September 30, 2015 : Available for Sale Securities (in thousands) Carrying value as of December 31, 2014 $ 3,864 Loss from equity method investment (1) (494 ) Change in fair value recognized in other comprehensive loss (2,402 ) Carrying value as of September 30, 2015 $ 968 (1) As a result of the carrying value of the Company's investment in common stock of GreenHunter being reduced to zero from equity method losses, the Company is required to allocate any additional losses to its investment in the Series C preferred stock of GreenHunter. The Company recorded additional equity method loss against the carrying value of its investment in the Series C preferred stock of GreenHunter before recording any mark-to-market adjustments. The Company's investments in available for sale securities have been presented in current assets as "Investments" in the consolidated balance sheet as of September 30, 2015 and December 31, 2014 . The cost for equity securities and their respective fair values as of September 30, 2015 and December 31, 2014 are as follows: September 30, 2015 (in thousands) Cost Gross Unrealized Losses Fair Value Securities available for sale, carried at fair value: Equity securities $ 532 $ — $ 532 Equity securities - related party (see "Note 14 - Related Party Transactions") 436 — 436 Total Securities available for sale $ 968 $ — $ 968 December 31, 2014 (in thousands) Cost Gross Unrealized Losses Fair Value Securities available for sale, carried at fair value: Equity securities $ 9,876 $ (7,323 ) $ 2,553 Equity securities - related party (see "Note 14 - Related Party Transactions") 2,200 (889 ) 1,311 Total Securities available for sale $ 12,076 $ (8,212 ) $ 3,864 The methods of determining the fair values of Magnum Hunter's investments in equity securities are described in "Note 7 - Fair Value of Financial Instruments" . Commodity and Financial Derivative Instruments The Company periodically enters into certain commodity derivative instruments such as futures contracts, swaps, collars, and basis swap contracts. As a producer of oil and natural gas, the Company holds these commodity derivatives to protect the operating revenues and cash flows related to a portion of its future natural gas and crude oil sales from the risk of significant declines in commodity prices, which is intended to help reduce exposure to price risk and improve the likelihood of funding its capital budget. The Company has not designated any commodity derivative instruments as hedges. As of September 30, 2015 , the Company had the following commodity derivative instruments: Weighted Average Natural Gas Period MMBtu/day Price per MMBtu Collars Aug 2015 - Dec 2015 80,000 $2.66 - $3.15 Weighted Average Crude Oil Period Bbl/day Price per Bbl Collars Aug 2015 - Dec 2015 1,500 $45.00 - $48.00 Ceilings sold (call) Jan 2015 - Dec 2015 1,570 $120.00 Floors sold (put) Jan 2015 - Dec 2015 259 $70.00 On May 7, 2015, the Company obtained consent under the Credit Facility to terminate the Company's open commodity derivative positions, so long as all such terminations occur prior to the November 1, 2015 borrowing base redetermination. See "Note 9 - Debt" . The Company received approximately $11.8 million in cash proceeds from the termination of the majority of its open commodity derivative positions that were terminated on May 7, 2015. As of September 30, 2015 , Citibank, N.A. and Bank of Montreal are the counterparties to the Company's commodity derivatives positions. Collateral securing the Credit Facility is used as collateral for the Company's commodity derivatives with those counterparties participating, currently or at the time the commodity derivative position was entered into, in the Credit Facility, under which the Company had outstanding borrowings of $5.0 million as of September 30, 2015 . Effective as of July 10, 2015, Citibank, N.A. is no longer a participant in the Company's credit facilities. The Company is exposed to credit losses in the event of nonperformance by the counterparties where the Company's open commodity derivative contracts are in a gain position. The Company does not anticipate nonperformance by the counterparties over the term of the commodity derivatives positions. As further discussed in "Note 9 - Debt" , as of October 8, 2015, the Company had an event of default under its Credit Facility and Second Lien Term Loan Agreement which resulted in a cross-default under the Company's derivative contracts with Bank of Montreal, and which may result in a cross-default under the Company's derivative contracts with Citibank, N.A. if the outstanding loan obligations under the related credit agreements are accelerated. Under the Company's derivative contracts, upon a cross-default the non-defaulting party may designate an early termination date for all outstanding transactions. The counterparties to the Company's derivative contracts have not designated early termination dates for any of the Company's outstanding commodities derivatives as of the date of this report. On November 2, 2015, the Company terminated its open commodity derivative positions with Bank of Montreal and received approximately $0.9 million in cash proceeds. At September 30, 2015 , the Company also had a convertible security embedded derivative asset primarily due to the conversion feature of the promissory note received as partial consideration for the sale of Hunter Disposal. See " Note 7 - Fair Value of Financial Instruments " and " Note 14 - Related Party Transactions ". The following table summarizes the fair value of the Company's commodity and financial derivative contracts as of the dates indicated: Derivatives not designated as hedging instruments Derivative Assets Derivative Liabilities September 30, December 31, September 30, December 31, (in thousands) Commodity Derivative assets $ 1,051 $ 16,511 $ — $ — Derivative liabilities — — 569 — Total commodity $ 1,051 $ 16,511 $ 569 $ — Financial Derivative assets $ 3 $ 75 $ — $ — Total financial $ 3 $ 75 $ — $ — Total derivatives $ 1,054 $ 16,586 $ 569 $ — Certain of the Company's derivative instruments are subject to enforceable master netting arrangements that provide for the net settlement of all derivative contracts between the Company and a counterparty in the event of default or upon the occurrence of certain termination events. The tables below summarize the Company's commodity derivatives and the effect of master netting arrangements on the presentation of those derivatives in the Company's consolidated balance sheets as of: September 30, 2015 Gross Amounts of Recognized Assets and Liabilities Gross Amounts Offset on the Consolidated Balance Sheet Net Amount (in thousands) Current assets: Fair value of derivative contracts $ 1,051 $ — $ 1,051 Current liabilities: Fair value of derivative contracts (569 ) — (569 ) $ 482 $ — $ 482 December 31, 2014 Gross Amounts of Assets and Liabilities Gross Amounts Offset on the Consolidated Balance Sheet Net Amount (in thousands) Current assets: Fair value of derivative contracts $ 18,146 $ (1,635 ) $ 16,511 Current liabilities: Fair value of derivative contracts (1,635 ) 1,635 — $ 16,511 $ — $ 16,511 The following table summarizes the net gain (loss) on all derivative contracts included in gain (loss) on derivative contracts, net on the consolidated statements of operations for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended September 30, Nine Months Ended 2015 2014 2015 2014 (in thousands) Gain (loss) on settled transactions $ (380 ) $ 477 $ 2,814 $ (4,074 ) Gain (loss) on open contracts 948 7,785 531 3,741 Total gain (loss), net $ 568 $ 8,262 $ 3,345 $ (333 )

DEBT

DEBT	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
DEBT	NOTE 9 - DEBT Long-term debt at September 30, 2015 and December 31, 2014 consisted of the following: September 30, December 31, (in thousands) Senior Notes payable due May 15, 2020, interest rate of 9.75%, net of unamortized net discount of $2.5 million and $2.6 million at September 30, 2015 and December 31, 2014, respectively $ 597,521 $ 597,355 Various equipment and real estate notes payable with maturity dates February 2015 - November 2017, interest rates of 4.25% - 7.94% 17,990 22,238 MHR Senior Revolving Credit Facility due on demand as of October 8, 2015, original maturity of October 22, 2018, interest rate of 4.21% at September 30, 2015 and 2.92% at December 31, 2014 5,000 — MHR second lien term loan due on demand as of October 8, 2015, original maturity of October 22, 2019, interest rate of 8.5%, net of unamortized discount of $9.1 million and $10.0 million at September 30, 2015 and December 31, 2014, respectively 327,469 329,140 947,980 948,733 Less: current portion (939,680 ) (10,770 ) Total long-term debt obligations, net of current portion $ 8,300 $ 937,963 The following table presents the scheduled or expected approximate annual maturities of debt, gross of unamortized discount of $11.6 million as of September 30, 2015 : (in thousands) 2015 $ 946,533 2016 8,226 2017 1,240 2018 558 2019 207 Thereafter 2,826 Total $ 959,590 MHR Senior Revolving Credit Facility and Second Lien Term Loan Senior Revolving Credit Facility On October 22, 2014, the Company entered into the Fourth Amended and Restated Credit Agreement by and among the Company, as borrower, Bank of Montreal, as administrative agent, the lenders party thereto and the agents party thereto (as amended, the "Credit Agreement"). First Amendment to Credit Agreement and Limited Waiver On February 24, 2015, the Company entered into a First Amendment to Credit Agreement and Limited Waiver (the "First Amendment") that, among other things, (i) waived the then existing current ratio covenant requirement for the December 31, 2014 compliance period and (ii) lowered the current ratio requirement to 0.75 from 1.0 for the fiscal quarter ending March 31, 2015. Pursuant to the First Amendment, the current ratio requirement would have increased to 1.0 to 1.0 for the fiscal quarter ending June 30, 2015 and each fiscal quarter ending thereafter. The First Amendment also modified the leverage ratio requirement to remain at not more than 2.5 x beginning with the December 31, 2014 compliance period through the December 31, 2015 compliance period. In addition, the First Amendment provided that, until such time as the Company can demonstrate a (i) current ratio of 1.0 to 1.0 as of the last day of a fiscal quarter or, if there is a proposed Liquidity Event (described below) or other arms-length liquidity event with a non-affiliate or unrestricted subsidiary, demonstrate a current ratio of 1.0 to 1.0 on a pro forma basis as of the last day of a calendar month assuming that the Liquidity Event (or other liquidity event) had occurred during such calendar month and (ii) in the case of a decrease of the Rates for ABR Loans and Eurodollar Loans, pro forma compliance with the other applicable financial covenants as of the last day of the fiscal quarter most recently ended, (such period, the "Adjusted Period"), then: i. neither the Company nor any of its restricted subsidiaries were permitted to make additional investments in excess of $2 million in the aggregate in oil and gas properties (other than acreage swaps and associated assets) and other applicable assets; ii. neither the Company nor any of its restricted subsidiaries were permitted to make additional capital contributions to or other investments in unrestricted subsidiaries in amounts in excess of $2 million in the aggregate; and iii. the Company could not make any additional capital contributions to or other investments in Eureka Hunter Holdings. For purposes of the First Amendment, a "Liquidity Event" meant any event or events resulting in (i) an increase in Liquidity (as defined in the Credit Agreement, as amended by the First Amendment) of at least $36.0 million as a result of an arm's length transaction with a person or entity that is not an affiliate of the Company or (ii) the receipt by the Company or any restricted subsidiary of aggregate net cash proceeds of at least $73.0 million as a result of one or more arm's length transactions with either (a) persons or entities who are not affiliates of the Company or (b) the Company's unrestricted subsidiaries. The First Amendment also provided that effective March 31, 2015, if a Liquidity Event (described in clause (i) of the preceding paragraph) had not occurred prior to such date, or April 30, 2015 if a proposed Liquidity Event described in clause (ii) of the preceding paragraph for which a pro forma current ratio calculation was used had not occurred prior to such date, the rates for ABR Loans and Eurodollar Loans would automatically increase by 1.00% and the commitment fee would automatically increase by 0.25% and such elevated rates would continue until the day immediately preceding the date on which the Adjusted Period ended. No Liquidity Event or proposed Liquidity Event for which a pro forma current ratio calculation was used had occurred as of April 30, 2015. Accordingly the rates for ABR Loans and Eurodollar Loans and the commitment fee were increased as described in the second preceding sentence. Second Amendment to Credit Agreement and Limited Waiver The Company entered into the Second Amendment to Credit Agreement and Limited Waiver (the "Second Amendment") on and effective as of April 17, 2015 by and among the Company, as borrower, Bank of Montreal, as administrative agent, and the several lenders and guarantors party thereto. The waiver required that certain events and conditions be satisfied by May 29, 2015 as further described below. The Second Amendment amended the Credit Agreement to: i. Extend the amount of time the Company and its Restricted Subsidiaries (as defined in the Credit Agreement) may have accounts payable outstanding after the invoice date from 90 days to 180 days for any day on or prior to May 29, 2015, after which the date the restriction would have reverted back to 90 days. ii. Condition the Company's ability to pay cash dividends on its three outstanding series of preferred stock as follows: 1. Payment of the preferred stock dividends for the month of April 2015 was permitted provided the Company's previously filed shelf registration statement (the "Shelf Registration Statement"), providing for, among other things, ATM offerings of equity securities of the Company, had been declared effective by the Securities and Exchange Commission (the "SEC") and the Company had executed an agreement (a "Sales Agreement") with an underwriter or sales agent to proceed with any such ATM offerings. The Shelf Registration Statement was declared effective on April 22, 2015 and the Company entered into a Sales Agreement on April 23, 2015. 2. Payment of the preferred stock dividends for the month of May 2015 was permitted provided the Company had received, by May 29, 2015, at least $65.0 million of aggregate net cash proceeds from the issuance by the Company of equity securities, permitted asset sales by the Company or any Restricted Subsidiary or the entry into a joint venture by the Company or any Restricted Subsidiary (including the receipt of any contemplated upfront payments therefrom). iii. Increase the applicable interest rate margins under the First Lien Credit Agreement by a nominal amount of 25 basis points. The applicable interest rate margins will automatically revert back to the lower levels in effect immediately prior to the effective date of the First Amendment when the Company demonstrates full compliance with its financial covenants under the Credit Agreement or compliance with such covenants on a pro forma basis giving effect to one or more Liquidity Events. In addition, pursuant to the Second Amendment, the lenders agreed to waive (i) effective as of March 31, 2015, compliance with the current ratio and leverage ratio covenants under the Credit Agreement for the fiscal quarter ended March 31, 2015 (which covenants, prior to the waiver, required a current ratio of not less than 0.75 to 1.0 , and leverage ratio of not more than 2.5 to 1.0 , for such fiscal quarter) and (ii) any default or event of default that may have occurred as a result of non-compliance with the accounts payable aging limitation in effect prior to the effective date of the Second Amendment, as described above. These waivers were subject to the Company having received, by May 29, 2015, at least $65.0 million of aggregate net cash proceeds from one or more of the issuance by the Company of equity securities, permitted asset sales by the Company or any Restricted Subsidiary or the entry into a joint venture by the Company or any Restricted Subsidiary (including the receipt of upfront payments therefrom) (the "Waiver Condition"). On May 7, 2015, the Company obtained consent under the Credit Facility to terminate the Company's open commodity derivative positions, so long as all such terminations occurred prior to the November 1, 2015 borrowing base redetermination. Such terminations had been contemplated and were reflected in the May 1, 2015 borrowing base redetermination. Following the May 1, 2015 borrowing base redetermination, the Company's borrowing base under the Credit Facility was maintained at $50 million . The Company terminated the majority of its open commodity derivative positions on May 7, 2015. See "Note 8 - Investments and Derivatives" . Third Amendment to Credit Agreement and Limited Consent On and effective as of May 28, 2015, the Company entered into the Third Amendment to Credit Agreement and Limited Consent (the "Third Amendment") by and among the Company, as borrower, Bank of Montreal, as administrative agent, and the several lenders and guarantors party thereto. The Third Amendment amended the Credit Agreement to: i. Extend the amount of time the Company and its Restricted Subsidiaries may have accounts payable outstanding after the invoice date from 90 days to 180 days for any day on or prior to June 19, 2015 (rather than May 29, 2015, as provided in the Second Amendment), after which June 19, 2015 date the restriction would have reverted back to 90 days; and ii. Remove the condition, previously added by the Second Amendment, on the Company's ability to pay cash dividends on its three outstanding series of preferred stock for the month of May 2015, so that the Company may pay such dividends as scheduled on June 1, 2015 without regard to such condition. In addition, pursuant to the Third Amendment, the lenders agreed to extend the deadline for the Company to satisfy the Waiver Condition from May 29, 2015 to June 19, 2015. Fourth Amendment to Credit Agreement and Limited Consent On and effective as of June 19, 2015, the Company entered into the Fourth Amendment to Credit Agreement and Limited Consent (the "Fourth Amendment") by and among the Company, as borrower, Bank of Montreal, as administrative agent, and the several lenders and guarantors party thereto. The Fourth Amendment amended the Credit Agreement to extend the amount of time the Company and its Restricted Subsidiaries may have accounts payable outstanding after the invoice date from 90 days to 180 days for any day on or prior to July 10, 2015, after such date the restriction would have reverted back to 90 days. In addition, pursuant to the Fourth Amendment, the lenders agreed to extend the deadline for Magnum Hunter to satisfy the Waiver Condition from June 19, 2015 to July 10, 2015. Fifth Amendment to Credit Agreement and Limited Waiver On and effective as of July 10, 2015, the Company entered into the Fifth Amendment to Credit Agreement and Limited Waiver (the "Fifth Amendment") by and among the Company, as borrower, Bank of Montreal, as administrative agent, and the several lenders and guarantors party thereto. The Fifth Amendment amended the Credit Agreement to, among other things: i. Permanently eliminate the Company's obligation to raise $65.0 million in net cash proceeds from one or more of the issuance by the Company of equity securities, permitted asset sales by the Company or any Restricted Subsidiary or the entry into a joint venture by the Company or any Restricted Subsidiary (including the receipt of upfront payments therefrom); ii. Extend the amount of time the Company and its Restricted Subsidiaries may have accounts payable outstanding after the invoice date from 90 days to 180 days for any day on or prior to the earlier of (a) December 31, 2015 or (b) the date that is ten business days following the date on which the Company consummates the sale of all or substantially all of the Company's equity ownership interest in Eureka Hunter Holdings (the date of such sale, the "Trigger Date"), after which earlier date the restriction will revert back to 90 days; and iii. Permit certain lenders to sell and assign their rights and obligations under the Credit Agreement to the Bank of Montreal. In addition, the Fifth Amendment includes a waiver of compliance by the Company with the current ratio and leverage ratio covenants for the fiscal quarter ended June 30, 2015 (which covenants, prior to the waiver, required a current ratio of not less than 1.0 to 1.0 and a leverage ratio of not more than 2.5 to 1.0 ) and for each fiscal quarter ending thereafter until the earlier of (i) the fiscal quarter ending December 31, 2015 or (ii) the fiscal quarter in which the Trigger Date occurs, at which time the waiver of these financial covenants will no longer be in effect commencing with the earlier of the fiscal quarters referred to in clauses (i) and (ii) of this sentence. Upon expiration of the waiver of these financial covenants, the Company will be required to maintain (i) a current ratio of not less than 1.0 to 1.0 for the fiscal quarter during which the waiver expired and each quarter ending thereafter and (ii) a leverage ratio of not more than (a) 2.5 to 1.0 for the fiscal quarters ending September 30, 2015 (if the Trigger Date occurs during such fiscal quarter) and December 31, 2015 and (b) 2.0 to 1.0 for the fiscal quarter ending March 31, 2016 and for each fiscal quarter ending thereafter. Sixth Amendment to the Credit Agreement On and effective as of November 3, 2015, the Company entered into the Sixth Amendment, which amended the Credit Agreement to, among other things: i. assign amounts outstanding of approximately $5.0 million under the Credit Facility in the form of a single tranche of term loans to the New First Lien Lenders; ii. cash collateralize certain outstanding letters of credit issued under the Credit Facility in an aggregate amount of approximately $39.0 million ; and iii. provide the Company with an additional new term loan in the aggregate principal amount of $16.0 million , which was funded in full by the New First Lien Lenders on the closing date of the Sixth Amendment. As a result of the Sixth Amendment, the New First Lien Lenders became the lenders under the Refinancing Facility, the Credit Facility was restructured from a senior secured revolving credit facility to a senior secured term loan facility represented by the Refinancing Facility and the aggregate amounts outstanding under the Refinancing Facility as of the closing date of the Sixth Amendment totaled approximately $60 million . In addition, the Refinancing Facility includes an uncommitted incremental credit facility for up to an additional $10.0 million aggregate principal amount of term loans to be provided to the Company, if and to the extent requested by the Company and agreed to by a specified percentage of the New First Lien Lenders. The Refinancing Facility is due and payable on the earlier of: (a) December 30, 2015, (b) in the case of an event of default under the Refinancing Facility, the acceleration of the payment of the term loans under the Refinancing Facility, as determined by the requisite percentage of the New First Lien Lenders, or (c) the filing of a Chapter 11 case (or cases) by the Company or any of its subsidiaries. The term loans under the Refinancing Facility bear interest at the Company's option at either the London Interbank Offered Rate, plus an applicable margin of 4.0% , or a specified prime rate of interest, plus an applicable margin of 3.0% . The Refinancing Facility contains the same covenants as the Credit Agreement prior to execution of the Sixth Amendment, subject to customary adjustments consistent with financings of this type and duration and subject to the following additional changes: i. removal of all financial covenants in effect prior to the Sixth Amendment (including the current ratio, total secured net debt to EBITDAX, proved reserves coverage ratio and proved developed producing reserves coverage ratio covenants). ii. removal of restrictions against trade payables being outstanding for more than 180 days from the date of invoice, and iii. inclusion of budgetary and reporting requirements consistent with financings of this type and duration, including a cumulative budget variance covenant tested every other week, in accordance with the terms of the Refinancing Facility. The Refinancing Facility also contains restrictions on the sale of assets by the Company and its restricted subsidiaries, which restrictions, among other things, prohibit (i) the Company from selling its equity ownership interests in Eureka Hunter Holdings, LLC (the "EHH Interests") and (ii) the Company and its restricted subsidiaries from engaging in certain farm-outs of undeveloped acreage, without, in each case, first obtaining the requisite consent of the New First Lien Lenders. Additionally, the Refinancing Facility contains a standstill on any marketing by the Company of the sale of the EHH Interests, other than with bidders that contact the Company without prior solicitation and other than any bidders that have already been engaged in such marketing efforts with the Company as of the closing date of the Refinancing Facility. Defaults under the Credit Agreement On July 27, 2015, the Company became aware of a default under the Credit Agreement relating to accounts payable. In accordance with the terms of the Credit Agreement, the Company may not have accounts payable outstanding (subject to certain permissible amounts) in excess of 180 days from the invoice date for any day on or prior to the earlier of (a) December 31, 2015 or (b) the Trigger Date, after which earlier date the restriction will revert back to 90 days. The Company cured the default in accordance with the Credit Agreement on August 26, 2015. On September 8, 2015, the Company became aware of an additional default under the Credit Agreement because the Company had approximately $1.4 million in accounts payable outstanding (other than such permissible amounts) in excess of 180 days from the invoice date. Under the Credit Agreement, the Company had 30 days to cure this default. As of October 8, 2015, the Company continued to have accounts payable outstanding (other than such permissible amounts) in excess of 180 days from the invoice date, resulting in an event of default. Due to the event of default, the lenders under the Credit Agreement may declare the outstanding loan amounts immediately due and payable. As such, the Company's outstanding balance under the Credit Agreement is reflected as a current liability in the accompanying consolidated balance sheet as of September 30, 2015. However, defaults and events of default under the Company's credit facilities are currently subject to certain forbearance agreements. Our unsecured Senior Notes and certain remaining derivatives contracts also contain cross-default or cross-acceleration provisions that may result in the Senior Notes and the remaining derivatives contracts becoming callable if any material obligation is called by a lender due to an event of the default. Specifically, a cross-default under the indenture governing the Senior Notes will occur if the lenders under the Company's Credit Agreement or Second Lien Term Loan Agreement choose to accelerate the indebtedness under such agreement as a result of the event of default. The Company has not received any notice of acceleration with respect to any of the obligations described above. The event of default described above under the Credit Agreement resulted in an event of default under the Second Lien Term Loan Agreement and the Note Payable (as defined below). Furthermore, the event of default regarding accounts payable under the Second Lien Term Loan Agreement, as described below, resulted in a cross-default under the Credit Agreement. For additional information regarding cross-defaults, potential cross-defaults, and forbearances, please see the remaining discussion below regarding each debt instrument. The event of default under the Credit Agreement also resulted in a cross-default under the Company's derivatives contracts with Bank of Montreal, and may result in a cross-default under the Company's derivatives contracts with Citibank, N.A. As of September 30, 2015 , the Company had outstanding commodities derivatives contracts representing $1.1 million of current assets and $0.6 million of current liabilities. Under the Company's derivative contracts with Bank of Montreal, an event of default under the Credit Agreement which results in the obligations under the Credit Facility becoming, or becoming capable at such time of being declared, due and payable before such obligations would otherwise have been due or payable creates a cross-default. As such, a cross-default arose under the Company's derivative contracts with Bank of Montreal on October 8, 2015 when the obligations under the Credit Agreement became callable. However, the Company did not receive any notice of cross-default from Bank of Montreal with respect to such derivatives contracts. In addition, on November 2, 2015, the Company chose to terminate all of its open commodity derivative positions with Bank of Montreal and received approximately $0.9 million in cash proceeds. See " Note 8 - Investments and Derivatives - Commodity and Financial Derivative Instruments". Under the Company's derivatives contracts with Citibank, N.A., an event of default under the Credit Agreement which results in the obligations under the Credit Agreement becoming due and payable before such obligations would otherwise have been due and payable creates a cross-default. Therefore, if the obligations under the Credit Agreement are accelerated, a cross-default under the Company's derivatives contracts with Citibank, N.A. would be created. Under each Citibank, N.A. derivatives contract, upon a cross-default the non-defaulting party may then designate an early termination date for all outstanding transactions. Citibank, N.A. has not designated early termination dates for any of the Company's outstanding commodities derivatives as of the date of this report. See "Note 8 - Investments and Derivatives" . As of September 30, 2015 , the borrowing base under the Credit Agreement was $50.0 million and outstanding borrowings were $5.0 million . The Company also posted letters of credit for $39.0 million using availability under the Credit Agreement. As of September 30, 2015 , the borrowing capacity under the Credit Agreement was $6.0 million . As described above, on November 3, 2015, the Company entered into the Sixth Amendment, which (i) assigned amounts outstanding of approximately $5.0 million under the Credit Agreement, with such refinancing being in the form of a single tranche of term loans to the New First Lien Lenders, (ii) cash collateralized certain outstanding letters of credit issued under the Credit Agreement in an aggregate amount of approximately $39.0 million and (iii) provided the Company with an additional new term loan in the aggregate principal amount of approximately $16.0 million , which was funded in full by the New First Lien Lenders on the closing date of the Sixth Amendment. Second Lien Term Loan On October 22, 2014, the Company entered into the Second Lien Term Loan Agreement by and among the Company, as borrower, Credit Suisse AG, Cayman Islands Branch, as administrative agent and collateral agent, the lenders party thereto and the agents party thereto. The Second Lien Term Loan Agreement requires the Company to satisfy certain financial covenants, including maintaining: i. a ratio of the present value of proved reserves using five year strip pricing to secured debt of not less than 1.5 to 1.0 and a ratio of the present value of proved developed and producing reserves using five year strip pricing to secured debt of not less than 1.0 to 1.0 , each as of the last day of any fiscal quarter commencing with the fiscal quarter ending December 31, 2014; and ii. commencing with the fiscal quarter ending March 31, 2016, a leverage ratio (secured net debt to EBITDAX (as defined in the Second Lien Term Loan Agreement) with a limitation on netting of up to $100.0 million of unencumbered cash) of not more than 2.5 to 1.0 as of the last day of any fiscal quarter for the trailing four-quarter period then ended. In accordance with the terms of the Second Lien Term Loan Agreement, the Company may not have accounts payable outstanding in excess of 90 days from the invoice date, in excess of permissible amounts provided for in the Second Lien Term Loan Agreement. On and effective as of April 17, 2015, the Company entered into a First Amendment to Credit Agreement and Limited Waiver (the "Second Lien Amendment"), by and among the Company, as borrower, Credit Suisse AG Cayman Islands Branch, as administrative agent and collateral agent, and the several lenders and guarantors party thereto. The Second Lien Amendment amended the Second Lien Term Loan Agreement by permanently extending the amount of time the Company and its Restricted Subsidiaries (as defined in the Second Lien Term Loan Agreement) may have accounts payable outstanding after the invoice date from 90 days to 180 days. In addition, pursuant to the Second Lien Amendment, the lenders waived any default or event of default that may have occurred in connection with any non-compliance with the accounts payable aging limitation in effect prior to the effective date of the Second Lien Amendment. On November 3, 2015, the Company entered into the Second Amendment. The Second Amendment provides for a forbearance by the lenders under the Second Lien Term Loan Agreement that entered into the Refinancing Facility with respect to exercising remedies regarding any default or event of default that results from the failure of the Company to make any interest payment under the Second Lien Term Loan Agreement, the failure to meet certain financial covenants thereunder, and certain other matters (including the default that arose on account of trade payables being outstanding for more than 180 days). The Second Amendment also amends certain other terms of the Second Lien Term Loan Agreement as necessary to permit the Refinancing Facility and to make certain covenants in the Second Lien Term Loan Agreement consistent with the revised covenants in the Refinancing Facility. The covenants under the Second Lien Term Loan Agreement otherwise remain substantially the same, subject to customary adjustments for such financings described herein. Under the Second Amendment, the lenders under the Second Lien Term Loan Agreement that entered into the Refinancing Facility agreed to forbear from exercising remedies under the Second Lien Term Loan Agreement with respect to any failure by the Company to make the October 30, 2015 interest payment under the Second Lien Term Loan Agreement and certain other defaults and events of default (including the default that arose on account of trade payables being outstanding for more than 180 days) until the earlier of (a) December 30, 2015, (b) the occurrence of an event of default under the Refinancing Facility, which such event of default is not cured or waived in accordance with the terms of the Refinancing Facility within 10 business days, (c) the occurrence of any event of default under the Second Lien Term Loan Agreement, and (d) the filing of a Chapter 11 case (or cases) by the Company or any of its subsidiaries. Defaults under the Second Lien Term Loan Agreement On July 27, 2015, the Company became aware of a default under the Second Lien Term Loan Agreement relating to accounts payable. In accordance with the terms of the Second Lien Term Loan Agreement the Company may not have accounts payable outstanding (subject to certain permissible amounts) in excess of 180 days from the invoice date. The Company cured the default in accordance with the Second Lien Term Loan Agreement on August 26, 2015. On September 8, 2015, the Company became aware of an additional default under the Second Lien Term Loan Agreement because the Company had approximately $1.4 million in accounts payable outstanding (other than such permissible amounts) in excess of 180 days from the invoice date. Under the Second Lien Term Loan Agreement, the Company had 30 days to cure this default. As of October 8, 2015, the Company continued to have accounts payable outstanding (other than such permissible amounts) in excess of 180 days from the invoice date, resulting in an event of default. Due to the event of default, the lenders under the Second Lien Term Loan Agreement may declare the outstanding loan amounts immediately due and payable. As such, the Company's outstanding balance under the Second Lien Term Loan Agreement is reflected as a current liability in the accompanying consolidated balance sheet as of September 30, 2015. However, defaults and events of default under the Company's credit facilities are currently subject to certain forbearance agreements. As described above, under the Second Amendment, the lenders under the Second Lien Term Loan Agreement that entered into the Refinancing Facility agreed to forbear from exercising remedies under the Second Lien Term Loan Agreement with respect to any failure by the Company to make the October 30, 2015 interest payment under the Second Lien Term Loan Agreement and certain other defaults (including the default that arose on account of trade payables being outstanding for more than 180 days)and events of default until the earlier of (a) December 30, 2015, (b) the occurrence of an event of default under the Refinancing Facility, which such event of default is not cured or waived in accordance with the terms of the Refinancing Facility within 10 business days, (c) the occurrence of any event of default under the Second Lien Term Loan Agreement, and (d) the filing of a Chapter 11 case (or cases) by the Company or any of its subsidiaries. Senior Notes On May 16, 2012, the Company issued $450 million in aggregate principal amount of its Senior Notes. The Senior Notes were issued pursuant to an indenture entered into on May 16, 2012 as supplemented, among the Company, the subsidiary guarantors party thereto, Wilmington Trust, National Association, as the trustee, and Citibank, N.A., as the paying agent, registrar and authenticating agent (the "Indenture"). On December 18, 2012, the Company issued an additional $150 million in aggregate principal amount of Senior Notes pursuant to a supplement to the Indenture. The Senior Notes issued in May 2012 and the Senior Notes issued in December 2012 have identical terms and are treated as a single class of securities under the Indenture. Interest on the Senior Notes is payable semi-annually in arrears on May 15 and November 15. The event of default under the Credit Agreement and Second Lien Term Loan Agreement may result in a cross-default under the Company's Senior Notes if the obligations under the Credit Agreement or the Second Lien Term Loan Agreement are accelerated. However, if, prior to any acceleration of the Senior Notes, the acceleration of the indebtedness under the Credit Agreement or Second Lien Term Loan Agreement is rescinded, or the obligations are repaid during the 10 business day period commencing upon the end of any applicable grace period for the occurrence of such acceleration, any event of default caused by such acceleration shall automatically be rescinded, so long as the rescission does not conflict with any judgment, decree or applicable law. If an event of default under the Indenture occurs and is continuing, the trustee or the holders of at least 25% in aggregate principal amount of the then outstanding Senior Notes may declare all the Senior Notes to be due a

SHARE-BASED COMPENSATION

SHARE-BASED COMPENSATION	9 Months Ended
	Sep. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
SHARE-BASED COMPENSATION	NOTE 10 - SHARE-BASED COMPENSATION Employees, officers, directors, and other persons who contribute to the success of Magnum Hunter are eligible for grants of unrestricted common stock, restricted common stock, common stock options, and stock appreciation rights under the Company's Amended and Restated Stock Incentive Plan. At September 30, 2015 , 27,500,000 shares of the Company's common stock are authorized to be issued under the plan, and 12,753,463 shares had been issued under the plan as of September 30, 2015 , of which 4,156.772 shares were unvested at September 30, 2015 . Additionally, 10,093,000 options to purchase shares and stock appreciation rights were outstanding as of September 30, 2015 , of which 7,953,000 were unvested at September 30, 2015 . The Company recognized share-based compensation expense of $1.4 million and $6.5 million for the three and nine months ended September 30, 2015 , respectively, and $2.3 million and $5.7 million for the three and nine months ended September 30, 2014 , respectively. A summary of common stock option activity for the nine months ended September 30, 2015 and 2014 is presented below: Nine Months Ended September 30, 2015 2014 2015 2014 (in thousands of shares) Weighted Average Exercise Price per Share Outstanding at beginning of period 13,195 16,891 $ 5.92 $ 5.69 Granted — — $ — $ — Exercised (100 ) (2,355 ) $ 0.51 $ 4.09 Forfeited (3,002 ) (1,241 ) $ 6.30 $ 6.28 Outstanding at end of period 10,093 13,295 $ 5.86 $ 5.91 Exercisable at end of period 7,953 9,179 $ 5.95 $ 6.22 A summary of the Company's non-vested common stock options and stock appreciation rights for the nine months ended September 30, 2015 and 2014 is presented below: Nine Months Ended September 30, 2015 2014 (in thousands of shares) Non-vested at beginning of period 4,055 6,908 Granted — — Vested (1,637 ) (1,916 ) Forfeited (278 ) (876 ) Non-vested at end of period 2,140 4,116 Total unrecognized compensation cost related to the non-vested common stock options and stock appreciation rights was $0.6 million and $4.7 million as of September 30, 2015 and 2014 , respectively. The unrecognized compensation cost at September 30, 2015 is expected to be recognized over a weighted-average period of 0.39 years . At September 30, 2015 , the weighted average remaining contract life of outstanding options was 4.26 years . On March 30, 2015, the Company granted 535,274 shares of common stock for 2014 bonuses to executives and officers of the Company. The shares had a fair value at the time of grant of $1.4 million based on the Company's stock price on the grant date. On June 18, 2015, the Company granted 600,000 restricted shares of common stock to non-employee members of the board of directors of the Company which vest two years from the date of grant, or if earlier, (i) upon the death or disability of the director or (ii) upon a change in control of the Company that occurs at least six months following the date of grant. The shares had a fair value of $0.7 million based on the Company's stock price on the grant date and an estimated forfeiture rate of 5.6% . On September 1, 2015, the Company granted 2,000,000 restricted shares of common stock outside of the Company's Amended and Restated Stock Incentive Plan to a newly hired officer. These restricted shares will vest in equal amounts on March 31, 2016, September 1, 2017, and September 1, 2018. The shares had a fair value of $1.5 million based on the Company's stock price on the grant date and an estimated forfeiture rate of 5.6% . During the nine months ended September 30, 2015 , the Company also granted an additional 205,000 restricted shares of common stock to certain newly hired officers. These 205,000 shares will vest over a 3 -year period and had a fair value of $0.3 million based on the Company's stock price on the grant date and an estimated forfeiture rate of 5.6% . Total unrecognized compensation cost related to non-vested restricted shares amounted to $6.4 million and $7.1 million as of September 30, 2015 and 2014 , respectively. The unrecognized cost at September 30, 2015 is expected to be recognized over a weighted-average period of 2.17 years.

SHAREHOLDERS_ EQUITY

SHAREHOLDERS’ EQUITY	9 Months Ended
	Sep. 30, 2015
Equity [Abstract]
SHAREHOLDERS’ EQUITY	NOTE 11 - SHAREHOLDERS' EQUITY Common Stock During the nine months ended September 30, 2015 , the Company issued 1,255,225 shares of the Company's common stock in connection with share-based compensation which had fully vested to senior management and directors of the Company. On March 13, 2015, the Company filed a universal shelf Form S-3 Registration Statement to register the sale by the Company of a maximum aggregate amount of up to $500 million of debt and equity securities. The Company filed amendments to this Form S-3 Registration Statement on April 15, 2015 and April 20, 2015 and the Form S-3 Registration Statement became effective on April 22, 2015. On April 23, 2015, the Company entered into an "At the Market" Sales Agreement with a sales agent to conduct ATM offerings of its equity securities. As of September 30, 2015 , the Company had sold an aggregate of 56,202,517 shares of its common stock for aggregate proceeds of $58.2 million , net of $1.3 million in sales commissions and other fees, through this ATM offering under the Form S-3 Registration Statement. On August 6, 2015, the Company issued 2,290,565 shares of the Company's common stock as "safe harbor" and discretionary matching contributions to the Magnum Hunter Resources Corporation 401(k) Employee Stock Ownership Plan. As a result of the suspension of monthly cash dividends on its preferred stock issuances, the Company became ineligible to issue securities, including issuances of common stock in ATM offerings, under its universal shelf Registration Statement on Form S-3, which was declared effective on April 22, 2015. See "Note 2 - Going Concern and Liquidity; Forbearance Agreements" and “-Preferred Dividends Incurred” for additional information regarding the Company’s suspension of monthly cash dividends. Preferred Dividends Incurred A summary of the Company's preferred dividends for the three and nine months ended September 30, 2015 and 2014 is presented below: Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 (in thousands) (in thousands) Dividend on Series C Preferred Stock $ 2,562 $ 2,562 $ 7,686 $ 7,686 Dividend on Series D Preferred Stock 4,424 4,424 13,273 13,273 Dividend on Series E Preferred Stock 1,862 1,862 5,584 5,557 Total dividends on Preferred Stock $ 8,848 $ 8,848 $ 26,543 $ 26,516 Dividend on Eureka Hunter Holdings Series A Preferred Units $ — $ 4,338 $ — $ 12,619 Accretion of the carrying value of the Eureka Hunter Holdings Series A Preferred Units — 2,306 — 6,583 Total dividends on Preferred Stock of discontinued operations $ — $ 6,644 $ — $ 19,202 On October 9, 2015, the Company announced that it had suspended monthly cash dividends on all of its outstanding series of preferred stock. The suspension commenced with the monthly cash dividend that would otherwise have been declared and paid for the month ending October 31, 2015 and will continue indefinitely. The outstanding shares of Series E Preferred Stock are represented by depositary shares (the "Depositary Shares"), each representing a 1/1,000th interest of a share of Series E Preferred Stock. Under the terms of the Company's Series C, Series D and Series E Preferred Stock, any unpaid dividends, including the unpaid dividends for the month ending October 31, 2015 and any future unpaid dividends, will continue to accumulate. Additionally, if the Company does not pay dividends on its Series C, Series D and Series E Preferred Stock for any month within a quarter for a total of four quarterly periods (whether consecutive or non-consecutive), (i) the holders of each series of preferred stock will have the right to elect two additional directors to serve on the Company's Board of Directors (the "Board") until all accumulated and unpaid dividends have been paid in full, (ii) the annual dividend rates on the Series C, Series D and Series E Preferred Stock will be increased to 12.5% , 10.0% and 10.0% , respectively (the "Penalty Rates"), until all accumulated and unpaid dividends have been paid in full and the Company has paid cash dividends at the respective Penalty Rates in full for an additional two consecutive quarters, and (iii) if not paid in cash, dividends must be paid in shares of common stock or (if the common stock is not publicly traded) in shares of the series of preferred stock (until the dividend default has been cured). The Company has previously suspended dividends on its Series C, Series D and Series E Preferred Stock affecting two quarterly periods during 2013. Net Loss per Share Data Basic income or loss per common share is computed by dividing the income or loss attributable to common shareholders by the weighted average number of shares of common stock outstanding during the period. Diluted income or loss per common share considers the impact to net income and common shares for the potential dilution from stock options and stock appreciation rights, common stock purchase warrants and any outstanding convertible securities. The Company has issued potentially dilutive instruments in the form of restricted common stock of Magnum Hunter granted and not yet issued, common stock warrants, common stock options granted to the Company's employees and directors, and the Company's Series E Preferred Stock. The Company did not include any of these instruments in its calculation of diluted loss per share during the periods presented, because to include them would be anti-dilutive due to the Company's loss from continuing operations during those periods. The following table summarizes the types of potentially dilutive securities outstanding as of September 30, 2015 and 2014 : September 30, 2015 2014 (in thousands of shares) Series E Preferred Stock 10,946 10,946 Warrants 19,173 19,214 Unvested restricted shares 4,157 1,445 Common stock options and stock appreciation rights 10,093 13,295 Total 44,369 44,900

REDEEMABLE PREFERRED STOCK

REDEEMABLE PREFERRED STOCK	9 Months Ended
	Sep. 30, 2015
Equity [Abstract]
REDEEMABLE PREFERRED STOCK	NOTE 12 - REDEEMABLE PREFERRED STOCK Eureka Hunter Holdings Series A Preferred Units On March 21, 2012, Eureka Hunter Holdings entered into a Series A Convertible Preferred Unit Purchase Agreement (the "Unit Purchase Agreement") with Magnum Hunter and Ridgeline Midstream Holdings, LLC ("Ridgeline"). Pursuant to this Unit Purchase Agreement, Ridgeline had purchased $200.0 million of Eureka Hunter Holdings Series A Preferred Units as of September 16, 2014. On September 16, 2014, the Company entered into an agreement (the "Transaction Agreement") with MSI and Eureka Hunter Holdings relating to a separate purchase agreement between MSI and Ridgeline providing for the purchase by MSI of all the Eureka Hunter Holdings Series A Preferred Units and Class A Common Units owned by Ridgeline. The Transaction Agreement also provided for the execution of the LLC Agreement to be entered into by Magnum Hunter, MSI and the minority interest members of Eureka Hunter Holdings contingent upon and contemporaneously with the closing of MSI's purchase of Ridgeline's equity interests in Eureka Hunter Holdings, which occurred on October 3, 2014. In accordance with the terms of the LLC Agreement, all of the Eureka Hunter Holdings Series A Preferred Units and Class A Common Units of Eureka Hunter Holdings acquired by MSI from Ridgeline were converted into Series A-2 Common Units, a new class of equity interests of Eureka Hunter Holdings, which were subsequently derecognized by the Company and included in the gain on deconsolidation of Eureka Hunter Holdings on December 18, 2014.

TAXES

TAXES	9 Months Ended
	Sep. 30, 2015
Income Tax Disclosure [Abstract]
Taxes	NOTE 13 - TAXES The Company did not recognize an income tax benefit or expense from continuing operations for the three and nine months ended September 30, 2015 and 2014 as a result of its large net operating losses and corresponding valuation allowance. The Company recognizes deferred income taxes for the future tax consequences attributable to differences between the financial statement carrying amounts of the existing assets and liabilities and their respective tax basis and net operating loss and credit carry forwards. The Company maintains a full valuation allowance on deferred tax assets where the realization of those deferred tax assets is not more likely than not. The valuation allowance will continue to be recognized until the realization of future deferred tax benefits is more likely than not to be utilized. The Company files income tax returns in the United States, various states and Canada. As of September 30, 2015 , no adjustments have been proposed by any tax jurisdiction that would have a significant impact on the Company's liquidity, future results of operations or financial position.

RELATED PARTY TRANSACTIONS

RELATED PARTY TRANSACTIONS	9 Months Ended
	Sep. 30, 2015
Related Party Transactions [Abstract]
RELATED PARTY TRANSACTIONS	NOTE 14 - RELATED PARTY TRANSACTIONS The following table sets forth the related party balances as of September 30, 2015 and December 31, 2014 : September 30, 2015 December 31, 2014 (in thousands) GreenHunter (1) Accounts payable - net $ (783 ) $ (224 ) Derivative assets (2) $ 3 $ 75 Investments (2) $ 436 $ 1,311 Notes receivable (2) $ 816 $ 1,224 Prepaid expenses $ 5 $ 1,000 Eureka Hunter Holdings (3) Accounts receivable (payable) - net $ (10,405 ) $ 122 Assets of discontinued operations $ 343,307 $ 347,191 Pilatus Hunter (4) Accounts receivable - net $ 12 $ 12 Classic Petroleum, Inc. (5) Accounts payable $ (51 ) $ — Kirk Trosclair Enterprises, LLC (6) Accounts payable $ (7 ) $ — The Company holds investments in a related party consisting of 1,846,722 shares of common stock of GreenHunter with no carrying value as of September 30, 2015 and 88,000 shares of Series C preferred stock of GreenHunter with a carrying value of $0.4 million as of September 30, 2015 . The following table sets forth the related party transaction activities for the three and nine months ended September 30, 2015 and 2014 , respectively: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in thousands) GreenHunter Production costs (1) $ 840 $ 894 $ 3,039 $ 1,969 Midstream natural gas gathering, processing, and marketing $ — $ 132 $ — $ 532 Oilfield services (1) $ 151 $ — $ 256 $ — General and administrative (1) $ 7 $ — $ 19 $ 36 Interest income (2) $ 23 $ 38 $ 94 $ 121 Miscellaneous income (expense) (2) $ (1,709 ) $ 55 $ (1,599 ) $ 165 Loss from equity method investment (2) $ 176 $ 79 $ 494 $ 436 Capitalized costs incurred (1) $ 5 $ — $ 470 $ — Pilatus Hunter, LLC (4) General and administrative $ 81 $ 49 $ 117 $ 207 Eureka Hunter Holdings (3) Production costs $ 144 $ — $ 740 $ — Transportation, processing, and other related costs $ 7,503 $ — $ 18,218 $ — Oilfield services $ 11 $ — $ 27 $ — Capitalized costs incurred $ — $ 715 $ 121 $ 2,526 Classic Petroleum (5) Capitalized costs incurred $ 21 $ 447 $ 206 $ 971 Kirk Trosclair Enterprises, LLC (6) General and administrative $ 52 $ — $ 141 $ — _________________________________ (1) GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman and a major shareholder. Triad Hunter and Viking International Resources Co., Inc., wholly owned subsidiaries of the Company, receive services related to brine water and rental equipment from GreenHunter and certain affiliated companies. The Company believes that such services were and are provided at competitive market rates and were and are comparable to, or more attractive than, rates that could be obtained from unaffiliated third party suppliers of such services. (2) On February 17, 2012, the Company sold its wholly owned subsidiary, Hunter Disposal, to GreenHunter Water, LLC ("GreenHunter Water"), a wholly owned subsidiary of GreenHunter. The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note it received as partial consideration for the sale. See "Note 7 - Fair Value of Financial Instruments" for additional information. The Company has recorded interest income as a result of the note receivable from GreenHunter. Also as a result of this transaction, the Company has an equity method investment in GreenHunter that is included in derivatives and investment in affiliates - equity method and an available for sale investment in GreenHunter included in investments. Miscellaneous income (expense) includes other than temporary impairment loss on the GreenHunter available for sale security of $1.8 million for the three and nine months ended September 2015. See "Note 8 - Investments and Derivatives" for additional information. (3) Following a series of transactions up to and including, December 18, 2014, the Company no longer held a controlling financial interest in Eureka Hunter Holdings. The Company deconsolidated Eureka Hunter Holdings and accounts for its retained interest as of December 31, 2014 under the equity method of accounting. As discussed in "Note 3 - Acquisitions, Divestitures, and Discontinued Operations" , in June 2015 the Company adopted a plan to dispose of its equity method investment in Eureka Hunter Holdings, and has classified the related operations as discontinued operations and the investment as assets of discontinued operations for all periods presented. (4) The Company rented an airplane for business use for certain members of Company management at various times from Pilatus Hunter, LLC, an entity 100% owned by Mr. Evans. Airplane rental expenses are recorded in general and administrative expense. (5) Classic Petroleum, Inc. is an entity owned by the brother of James W. Denny, III, the Company's former Executive Vice President and President of the Company's Appalachian Division. Triad Hunter received land brokerage services from Classic Petroleum, Inc., including courthouse abstracting, contract negotiations, GIS mapping and leasing services. (6) On July 18, 2014, the Company entered into a consulting agreement with Kirk J. Trosclair, a former executive of Alpha Hunter Drilling, LLC, a wholly owned subsidiary of the Company. Mr. Trosclair ceased employment with the Company on July 18, 2014 and is currently the Chief Operating Officer of GreenHunter. The agreement has a term of 12 months and provides that Mr. Trosclair will receive monthly compensation of $10,000 , and Mr. Trosclair is eligible to continue vesting in previously granted stock options and unvested restricted stock awards, subject to continued service under the consulting agreement. In connection with this agreement, for the nine months ended September 30, 2015 , the Company paid Mr. Trosclair $141,000 , which includes reimbursement of expenses incurred on behalf of the Company, and recognized $161,888 in stock compensation expense. In connection with the sale of Hunter Disposal, Triad Hunter entered into agreements with Hunter Disposal and GreenHunter Water for wastewater hauling and disposal capacity in Kentucky, Ohio, and West Virginia and a five -year tank rental agreement with GreenHunter Water. On December 22, 2014, Triad Hunter entered into an Amendment to Produced Water Hauling and Disposal Agreement with GreenHunter Water to secure long-term water disposal at reduced rates through December 31, 2019. To ensure disposal capacity, in connection with the amendment on December 29, 2014, Triad Hunter made a prepayment of $1.0 million towards services to be provided under the Produced Water Hauling and Disposal Agreement. GreenHunter Water provided a 50% credit for all services performed under the agreement until the prepayment amount was utilized in full, which occurred during the first half of 2015. As of September 30, 2015 , the Company had a note receivable from GreenHunter with an outstanding principal balance of approximately $0.8 million . Under the terms of the promissory note, GreenHunter is required to make quarterly payments to the Company comprised of principal of $137,500 and accrued interest through the maturity of the note in February 2017. Under the terms of the note, failure to pay timely is considered an event of default. As of March 31, 2015, GreenHunter was past due on principal and interest payments in aggregate of $168,437 , which were due on February 17, 2015. On May 4, 2015, GreenHunter made this past due principal and interest payment of $168,437 . As of September 30, 2015 , Mr. Evans, the Company's Chairman and Chief Executive Officer, held 27,641 Series A-1 Common Units of Eureka Hunter Holdings. Triad Hunter and Eureka Hunter Pipeline are parties to an Amended and Restated Gas Gathering Services Agreement (the "Gas Gathering Services Agreement"), which was executed on March 21, 2012, and amended on October 3, 2014 in contemplation of the LLC Agreement. Under the terms of the Gas Gathering Services Agreement, Triad Hunter reserved throughput capacity in the gas gathering pipeline system of Eureka Hunter Pipeline for which Triad Hunter has committed to minimum reservation fees of approximately $0.75 per MMBtu. As of October 31, 2015, Triad Hunter owed Eureka Hunter Pipeline approximately $10.7 million in past due gathering fees under the Gas Gathering Services Agreement. On November 5, 2015, the Company received a demand notice from MSI, on behalf of Eureka Hunter Pipeline, demanding, in connection with past due amounts, adequate assurance of performance of security in the amount of approximately $20.8 million on or before November 10, 2015. Additionally, Eureka Hunter Pipeline can also demand adequate assurance of performance for any payments if it determines that Triad Hunter’s credit is unsatisfactory. MSI advised the Company that its failure to provide such adequate assurance of performance by the specified deadline will result in a suspension of services under the Gas Gathering Services Agreement until such time as the Company provides such adequate assurance of performance. MSI further advised the Company that if the Company has not provided the adequate assurance of performance and/or paid in full all amounts past due by November 20, 2015, then Eureka Hunter Pipeline will terminate the Gas Gathering Services Agreement. The Company does not expect that it will be able to provide such adequate assurance of performance by the specified deadline. The Company has initiated discussions with MSI regarding a forbearance by Eureka Hunter Pipeline and MSI of their rights and remedies with respect to past due amounts under the Gas Gathering Services Agreement, including the provision of adequate assurance of performance. The Company can provide no assurance regarding whether a forbearance will be obtained. If such forbearance is not obtained, and Eureka Hunter Pipeline suspends performance under or terminates the Gas Gathering Services Agreement, such suspension in service or termination would force a temporary shut-in of certain of our wells (until the suspension is lifted or new gas gathering services are arranged) and could materially impact our business, financial condition and results of operations. We cannot predict at this time whether we would be able to secure any alternate gas gathering services or the timing thereof, especially in view of the limited amount of gas gathering service capacity in these areas of operation. Even if such services became available to us, such services may not be on terms we find suitable or attractive. See "Item 1A. Risk Factors - We are and may continue to become subject to claims by vendor creditors.” Upon the deconsolidation of Eureka Hunter Holdings on December 18, 2014, Eureka Hunter Holdings and its subsidiaries became related parties of the Company. The Company and Eureka Hunter Holdings entered into a Services Agreement on March 20, 2012, and amended on September 15, 2014, under which the Company agreed to provide administrative services to Eureka Hunter Holdings related to its operations. The terms of the Services Agreement provide that the Company will receive an administrative fee of $500,000 per annum and a personnel services fee equal to the Company's employee cost plus 1.5% subject to mutually agreed upon increases from time to time. Under the terms of the LLC Agreement, certain specified employees of the Company that perform services for Eureka Hunter Holdings and its subsidiaries and for whom the Company previously billed a personnel services fee, are expected to become employees of Eureka Hunter Holdings or a subsidiary of Eureka Hunter Holdings.

COMMITMENTS AND CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	9 Months Ended
	Sep. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	NOTE 15 - COMMITMENTS AND CONTINGENCIES Agreement to Purchase Utica Shale Acreage On August 12, 2013, Triad Hunter entered into an asset purchase agreement with MNW, referred to herein as the "MNW Purchase Agreement". Pursuant to the MNW Purchase Agreement, Triad Hunter has agreed to acquire from MNW up to 32,000 net mineral acres, including currently leased and subleased acreage, located in such counties, over a period of time, in staggered closings, subject to certain conditions. On January 14, 2015, Triad Hunter closed on the acquisition of 2,665 net leasehold acres for $12.0 million from MNW. To date, under the asset purchase agreement, Triad Hunter has now acquired a total of approximately 25,044 net leasehold acres from MNW, or approximately 78.3% of the approximately 32,000 total net leasehold acres anticipated under the asset purchase agreement. The Company believes that MNW will not be able to provide Triad Hunter with satisfactory title to any of the remaining net leasehold acres subject to purchase under the MNW Purchase Agreement, and therefore the Company anticipates that none of the remaining net leasehold acres will be acquired by Triad Hunter. Drilling Rig Purchase During June 2014, the Company, through its wholly owned subsidiary, Alpha Hunter Drilling, LLC, executed an agreement to purchase a new drilling rig for a total purchase price of approximately $6.5 million , including a $1.3 million deposit due on July 1, 2014 with the remainder due upon delivery, which was expected to be on or about January 15, 2015. In February 2015, the Company was notified that the rig was complete and available for delivery. However, the Company has not taken delivery of the rig and has initiated negotiations to apply the deposit towards a trade on a different drilling rig or associated equipment. Legal Proceedings Securities Cases On April 23, 2013, Anthony Rosian, individually and on behalf of all other persons similarly situated, filed a class action complaint in the United States District Court, Southern District of New York, against the Company and certain of its officers, two of whom, at that time, also served as directors, and one of whom continues to serve as a director. On April 24, 2013, Horace Carvalho, individually and on behalf of all other persons similarly situated, filed a similar class action complaint in the United States District Court, Southern District of Texas, against the Company and certain of its officers. Several substantially similar putative class actions were filed in the Southern District of New York and in the Southern District of Texas. All such cases are collectively referred to as the Securities Cases. The cases filed in the Southern District of Texas have since been dismissed. The cases filed in the Southern District of New York were consolidated and have since been dismissed. The plaintiffs in the Securities Cases had filed a consolidated amended complaint alleging that the Company made certain false or misleading statements in its filings with the SEC, including statements related to the Company's internal and financial controls, the calculation of non-cash share-based compensation expense, the late filing of the Company's 2012 Form 10-K, the dismissal of Magnum Hunter's previous independent registered accounting firm, the Company's characterization of the auditors' position with respect to the dismissal, and other matters identified in the Company's April 16, 2013 Form 8-K, as amended. The consolidated amended complaint asserted claims under Sections 10(b) and 20 of the Exchange Act based on alleged false statements made regarding these issues throughout the alleged class period, as well as claims under Sections 11, 12, and 15 of the Securities Act based on alleged false statements and omissions regarding the Company's internal controls made in connection with a public offering that Magnum Hunter completed on May 14, 2012. The consolidated amended complaint demanded that the defendants pay unspecified damages to the class action plaintiffs, including damages allegedly caused by the decline in the Company's stock price between February 22, 2013 and April 22, 2013. In January 2014, the Company and the individual defendants filed a motion to dismiss the Securities Cases. On June 23, 2014, the United States District Court for the Southern District of New York granted the Company's and the individual defendants' motion to dismiss the Securities Cases and, accordingly, the Securities Cases have now been dismissed. The plaintiffs subsequently appealed the decision dismissing the Securities Cases to the U.S. Court of Appeals for the Second Circuit. On June 23, 2015, the U.S. Court of Appeals for the Second Circuit entered a Summary Order unanimously affirming the Southern District of New York's dismissal of the Securities Cases in favor of the Company and the individual defendants. It is possible that additional investor lawsuits could be filed over these events. On May 10, 2013, Steven Handshu filed a stockholder derivative suit in the 151st Judicial District Court of Harris County, Texas on behalf of the Company against the Company's directors and senior officers. On June 6, 2013, Zachariah Hanft filed another stockholder derivative suit in the Southern District of New York on behalf of the Company against the Company's directors and senior officers. On June 18, 2013, Mark Respler filed another stockholder derivative suit in the District of Delaware on behalf of the Company against the Company's directors and senior officers. On June 27, 2013, Timothy Bassett filed another stockholder derivative suit in the Southern District of Texas on behalf of the Company against the Company's directors and senior officers. On September 16, 2013, the Southern District of Texas allowed Joseph Vitellone to substitute for Mr. Bassett as plaintiff in that action. On March 19, 2014 Richard Harveth filed another stockholder derivative suit in the 125th District Court of Harris County, Texas. These suits are collectively referred to as the Derivative Cases. The Derivative Cases assert that the individual defendants unjustly enriched themselves and breached their fiduciary duties to the Company by publishing allegedly false and misleading statements to the Company's investors regarding the Company's business and financial position and results, and allegedly failing to maintain adequate internal controls. The complaints demand that the defendants pay unspecified damages to the Company, including damages allegedly sustained by the Company as a result of the alleged breaches of fiduciary duties by the defendants, as well as disgorgement of profits and benefits obtained by the defendants, and reasonable attorneys', accountants' and experts' fees and costs to the plaintiff. On December 20, 2013, the United States District Court for the Southern District of Texas granted the Company's motion to dismiss the stockholder derivative case maintained by Joseph Vitellone and entered a final judgment of dismissal. The court held that Mr. Vitellone failed to plead particularized facts demonstrating that pre-suit demand on the Company's board was excused. In addition, on December 13, 2013, the 151st Judicial District Court of Harris County, Texas dismissed the lawsuit filed by Steven Handshu for want of prosecution after the plaintiff failed to serve any defendant in that matter. On January 21, 2014, the Hanft complaint was dismissed with prejudice after the plaintiff in that action filed a voluntary motion for dismissal. On February 18, 2014, the United States District Judge for the District of Delaware granted the Company's supplemental motion to dismiss the Derivative Case filed by Mark Respler. On July 22, 2014, the 125th District Court of Harris County, Texas issued an Order and Final Judgment granting the Company's and the individual defendants' motion for summary judgment in its entirety and entering a final judgment dismissing the suit filed by Richard Harveth. The plaintiffs may file an appeal. All of the Derivative Cases have now been dismissed. It is possible that additional stockholder derivative suits could be filed over these events. In addition, the Company received several demand letters from stockholders seeking books and records relating to the allegations in the Securities Cases and the Derivative Cases under Section 220 of the General Corporation Law of the State of Delaware. On September 17, 2013, Anthony Scavo, who is one of the stockholders that made a demand, filed a books and records action in the Delaware Court of Chancery pursuant to Section 220 of the Delaware General Corporation Law ("Scavo Action"). The Scavo Action sought various books and records relating to the claims in the Securities Cases and the Derivative Cases, as well as costs and attorneys' fees. The Company filed an answer in the Scavo Action, which has now been dismissed. It is possible that additional similar actions may be filed and that similar stockholder demands could be made. SEC Wells Notice In April 2013, the Company also received a letter from the staff of the SEC's Division of Enforcement (the "Staff") stating that the Staff was conducting an inquiry regarding the Company's internal controls, change in outside auditors and public statements to investors and asking the Company to preserve documents relating to these matters. The Company is complying with this request. On December 30, 2013, the Company received a document subpoena relating to the issues identified in the April 2013 letter. In 2014, the SEC issued additional subpoenas for documents and testimony and has taken testimony from certain individuals. The Company intends to cooperate with the subpoenas. In connection with the Staff's inquiry, on March 24, 2015, the Company received a "Wells Notice" from the Staff, stating that the Staff has made a preliminary determination to recommend that the SEC file an enforcement action against the Company. On that date, the Staff issued similar Wells Notices to Gary C. Evans, the Company's Chairman and Chief Executive Officer, J. Raleigh Bailes, Sr., a director of the Company and former Chairman of the Company's Audit Committee, the former chief financial officer of the Company who was in office at the time of the Company's decision to dismiss its prior independent registered public accounting firm and the former chief accounting officer of the Company who had resigned from that position with the Company in October 2012. The Wells Notice issued to the Company states that the proposed action against the Company would allege violations of Sections 17(a)(2) and 17(a)(3) of the Securities Act of 1933 and Sections 13(a), 13(b)(2)(A), and 13(b)(2)(B) of the Securities Exchange Act of 1934 and Rules 13a-l, 13a-13, and 13a-15(a) thereunder. The proposed actions against the individuals would allege violations of those same provisions, as well as violations of Section 13(b)(5) of the Securities Exchange Act of 1934 and Rules 13a-14 and 13a-15(c) thereunder. The proposed actions described in the Wells Notices do not include any claims for securities fraud under Section 10(b) of the Securities Exchange Act of 1934 or Rule 10b-5 thereunder or under Section 17(a)(1) of the Securities Act of 1933. The Wells Notices state that the Staff's recommendation may involve a civil injunctive action, public administrative proceeding, and/or cease-and-desist proceeding, and may seek remedies that might include, among other things, a cease-and-desist order, injunctions, disgorgement with pre-judgment interest and civil money penalties, as well as potential administrative remedies against Mr. Bailes under Rule 102(e)(1)(iii) of the SEC's Rules of Practice. A Wells Notice is neither a formal allegation nor a finding of wrongdoing. It allows the recipient the opportunity, through a "Wells Submission", to provide the recipient's reasons of law, policy or fact as to why the proposed enforcement action should not be filed and to address the issues raised by the Staff before any decision is made by the SEC on whether to authorize the commencement of an enforcement proceeding. On April 21, 2015, the Company responded to its Wells Notice in the form of a Wells Submission, pursuant to which the Company set forth why it believes an enforcement action against it and the individuals should not be commenced. The Company has engaged and continues to engage in discussions with the Staff regarding the issues raised in the Wells Notices. The Company cannot predict with confidence or certainty the ultimate outcome of the SEC process, including whether a settlement with respect to the issues raised in the Wells Notices may be reached with the Staff. If a contested enforcement action is subsequently brought against the Company by the SEC, the Company intends to mount a vigorous defense consistent with the defenses that were successfully mounted with respect to all of the previous Securities Cases and Derivative Cases. Twin Hickory Matter On April 11, 2013, a flash fire occurred at Eureka Hunter Pipeline's Twin Hickory site located in Tyler County, West Virginia. The incident occurred during a pigging operation at a natural gas receiving station. Two employees of third-party contractors received fatal injuries. Another employee of a third-party contractor was also injured. In mid-February 2014, the estate of one of the deceased third-party contractor employees sued Eureka Hunter Pipeline and certain other parties in a case styled Karen S. Phipps v. Eureka Hunter Pipeline, LLC et al., Civil Action No. 14-C-41, in the Circuit Court of Ohio County, West Virginia. In October 2014, in a case styled Exterran Energy Solutions, LP v. Eureka Hunter Pipeline, LLC and Magnum Hunter Resources Corporation, Civil Action No. 2014-63353, in the District Court of Harris County, Texas, Exterran Energy Solutions, LP, one of the co-defendants in the Phipps lawsuit, filed suit against the Company and Eureka Hunter Pipeline seeking a declaratory judgment that Eureka Hunter Pipeline is obligated to indemnify Exterran with respect to the Phipps lawsuit. In April 2014, the estate of the other deceased third-party contractor employee sued the Company, Eureka Hunter Pipeline and certain other parties in a case styled Antoinette M. Miller v. Magnum Hunter Resources Corporation et al, Civil Action No. 14-C-111, in the Circuit Court of Ohio County, West Virginia. The plaintiffs alleged that Eureka Hunter Pipeline and the other defendants engaged in certain negligent and reckless conduct which resulted in the wrongful death of the third-party contractor employees. The plaintiffs demanded judgments for an unspecified amount of compensatory, general and punitive damages. Various cross-claims were asserted. In May 2014, the injured third-party contractor employee sued Magnum Hunter and certain other parties in a case styled Jonathan Whisenhunt v. Magnum Hunter Resources Corporation et al, Civil Action No. 14-C-135, in the Circuit Court of Ohio County, West Virginia. The claim filed by the injured third-party contractor employee, Jonathan Whisenhunt, has been resolved and dismissed. A portion of the settlement was paid by an insurer of Eureka Hunter Pipeline, and the remainder paid by the co-defendants or their insurers. The cross-claims among the defendants in the Whisenhunt litigation have been resolved. In addition, the claims filed by Antoinette M. Miller and Karen S. Phipps have been successfully mediated and have been resolved and dismissed. Insurers providing coverage to Eureka Hunter Pipeline, Magnum Hunter and other affiliated or related entities paid a portion of the settlements, with the remainder being paid by the co-defendants or their insurers. Accordingly, all lawsuits relating to this matter have been resolved. General We are also a defendant in several other lawsuits that have arisen in the ordinary course of business. While the outcome of these lawsuits cannot be predicted with certainty, management does not expect any of these to have a material adverse effect on our consolidated financial condition or results of operations. In addition, we are subject to claims from vendor creditors arising from payments owed to such vendor creditors or disputes regarding such payments. In certain instances, such claims have resulted in lawsuits, threatened lawsuits, materialmen's and workmen's liens or other proceedings brought against us. See "Item 1A. Risk Factors - We are and may continue to become subject to claims by vendor creditors.”

SUPPLEMENTAL CASH FLOW INFORMAT

SUPPLEMENTAL CASH FLOW INFORMATION	9 Months Ended
	Sep. 30, 2015
Supplemental Cash Flow Elements [Abstract]
SUPPLEMENTAL CASH FLOW INFORMATION	NOTE 16 - SUPPLEMENTAL CASH FLOW INFORMATION The following table summarizes cash paid (received) for interest, as well as non-cash investing and financing transactions: Nine Months Ended September 30, 2015 2014 (in thousands) Cash paid for interest $ 49,271 $ 38,565 Non-cash transactions Common stock issued for 401k matching contributions $ 1,878 $ 1,593 Non-cash consideration received from sale of assets $ — $ 9,447 Change in accrued capital expenditures $ (98,296 ) $ 129,778 Non-cash changes in asset retirement obligation $ (556 ) $ 2,439 Eureka Hunter Holdings Series A Preferred Unit dividends paid in kind $ — $ 1,950

SEGMENT REPORTING

SEGMENT REPORTING	9 Months Ended
	Sep. 30, 2015
Segment Reporting [Abstract]
SEGMENT REPORTING	NOTE 17 - SEGMENT REPORTING Upstream, Midstream, and Oilfield Services represent the operating segments of the Company. The following tables set forth operating activities and capital expenditures by segment for the three and nine months ended, and segment assets as of September 30, 2015 and 2014 , respectively. As of and for the Three Months Ended September 30, 2015 Upstream Midstream and Marketing Oilfield Services Corporate Unallocated (1) Inter-segment Eliminations Total (in thousands) Total revenue $ 28,252 $ 118 $ 6,368 $ — $ (1,074 ) $ 33,664 Depletion, depreciation, amortization and accretion 22,444 — 934 — — 23,378 (Gain) loss on sale of assets, net (2,956 ) — 64 — — (2,892 ) Other operating expenses 87,629 88 3,584 7,603 (1,074 ) 97,830 Other expense (2,627 ) — (132 ) (23,759 ) — (26,518 ) Income (loss) from continuing operations before income tax (81,492 ) 30 1,654 (31,362 ) — (111,170 ) Total loss from discontinued operations, net of tax — — — (2,011 ) — (2,011 ) Net income (loss) $ (81,492 ) $ 30 $ 1,654 $ (33,373 ) $ — $ (113,181 ) Total assets $ 1,031,975 $ 104 $ 44,477 $ 384,156 $ (3,997 ) $ 1,456,715 Total capital expenditures $ 5,278 $ — $ 181 $ 184 $ — $ 5,643 As of and for the Three Months Ended September 30, 2014 Upstream Midstream and Marketing Oilfield Services Corporate Unallocated Inter-segment Eliminations Total (in thousands) Total revenue $ 63,438 $ 1,133 $ 8,176 $ — $ (2,190 ) $ 70,557 Depletion, depreciation, amortization and accretion 31,218 — 929 — — 32,147 Gain on sale of assets, net (7,988 ) — — — — (7,988 ) Other operating expenses 87,035 937 6,569 11,711 (3,789 ) 102,463 Other income (expense) 1,908 — (205 ) (9,237 ) — (7,534 ) Income (loss) from continuing operations before income tax (44,919 ) 196 473 (20,948 ) 1,599 (63,599 ) Total income (loss) from discontinued operations, net of tax (259 ) (57,991 ) — 1 (1,599 ) (59,848 ) Net income (loss) $ (45,178 ) $ (57,795 ) $ 473 $ (20,947 ) $ — $ (123,447 ) Total assets $ 1,475,305 $ 443,008 $ 45,661 $ 74,614 $ (5,023 ) $ 2,033,565 Total capital expenditures $ 104,265 $ 88,525 $ 3,628 $ 21 $ — $ 196,439 As of and for the Nine Months Ended September 30, 2015 Upstream Midstream and Marketing Oilfield Services Corporate Unallocated (1) Inter-segment Eliminations Total (in thousands) Total revenue $ 112,167 $ 867 $ 19,920 $ — $ (4,368 ) $ 128,586 Depletion, depreciation, amortization and accretion 100,607 — 2,939 — (105 ) 103,441 (Gain) loss on sale of assets, net (31,340 ) — 52 — — (31,288 ) Other operating expenses 176,618 689 13,709 27,247 (4,219 ) 214,044 Other expense (11,440 ) — (440 ) (67,401 ) — (79,281 ) Income (loss) from continuing operations before income tax (145,158 ) 178 2,780 (94,648 ) (44 ) (236,892 ) Total loss from discontinued operations, net of tax — — — (3,884 ) — (3,884 ) Net income (loss) $ (145,158 ) $ 178 $ 2,780 $ (98,532 ) $ (44 ) $ (240,776 ) Total assets $ 1,031,975 $ 104 $ 44,477 $ 384,156 $ (3,997 ) $ 1,456,715 Total capital expenditures $ 65,700 $ — $ 650 $ 2,042 $ — $ 68,392 As of and for the Nine Months Ended September 30, 2014 Upstream Midstream and Marketing Oilfield Services Corporate Unallocated Inter-segment Eliminations Total (in thousands) Total revenue $ 223,788 $ 66,726 $ 23,882 $ — $ (6,321 ) $ 308,075 Depletion, depreciation, amortization and accretion 87,346 — 2,557 — — 89,903 Gain on sale of assets, net (4,231 ) — (369 ) — — (4,600 ) Other operating expenses 197,013 66,380 19,643 35,253 (14,752 ) 303,537 Other income (expense) 1,740 — (625 ) (54,979 ) — (53,864 ) Income (loss) from continuing operations before income tax (54,600 ) 346 1,426 (90,232 ) 8,431 (134,629 ) Total income (loss) from discontinued operations, net of tax 3,353 (98,093 ) — (12,775 ) (8,431 ) (115,946 ) Net income (loss) $ (51,247 ) $ (97,747 ) $ 1,426 $ (103,007 ) $ — $ (250,575 ) Total assets $ 1,475,305 $ 443,008 $ 45,661 $ 74,614 $ (5,023 ) $ 2,033,565 Total capital expenditures $ 321,024 $ 171,152 $ 6,575 $ 127 $ — $ 498,878 _________________________________ (1) Includes the Company's retained interest in Eureka Hunter Holdings which was valued at $343.3 million at September 30, 2015 . As discussed in "Note 3 - Acquisitions, Divestitures, and Discontinued Operations" , in June 2015 the Company adopted a plan to dispose of its equity method investment in Eureka Hunter Holdings, and has classified the related operations as discontinued operations and the investment as assets of discontinued operations for all periods presented.

CONDENSED CONSOLIDATING GUARANT

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	9 Months Ended
	Sep. 30, 2015
Guarantees [Abstract]
CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	NOTE 18 - CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS Guarantor Subsidiaries Certain of the Company's subsidiaries, including Alpha Hunter Drilling, LLC, Bakken Hunter, LLC, Shale Hunter, LLC, Magnum Hunter Marketing, LLC, MHP, NGAS Hunter, LLC, Triad Hunter, Viking International Resources, Co., Inc., and Bakken Hunter Canada, Inc., (collectively, "Guarantor Subsidiaries"), jointly and severally guarantee on a senior unsecured basis, the obligations of the Company under all the Senior Notes issued under the indenture entered into by the Company on May 16, 2012, as supplemented. The Guarantor Subsidiaries may also guarantee any debt of the Company issued pursuant to the Form S-3 Registration Statement filed by the Company with the SEC on March 15, 2015, amended on April 20, 2015, and declared effective on April 22, 2015. Condensed consolidating financial information for Magnum Hunter Resources Corporation, the Guarantor Subsidiaries and the other subsidiaries of the Company (the "Non Guarantor Subsidiaries") as of September 30, 2015 and December 31, 2014 , and for the three and nine months ended September 30, 2015 and 2014 , are as follows: Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Balance Sheets (in thousands) As of September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter ASSETS Current assets $ 11,316 $ 32,016 $ 281 $ (3,953 ) $ 39,660 Intercompany accounts receivable 1,153,644 — — (1,153,644 ) — Property and equipment (using successful efforts method of accounting) 6,461 1,047,148 — (45 ) 1,053,564 Investment in subsidiaries (224,706 ) 91,947 — 132,759 — Assets of discontinued operations and other 363,118 373 — — 363,491 Total Assets $ 1,309,833 $ 1,171,484 $ 281 $ (1,024,883 ) $ 1,456,715 LIABILITIES AND SHAREHOLDERS' EQUITY Current liabilities $ 967,762 $ 113,033 $ 17 $ (3,953 ) $ 1,076,859 Intercompany accounts payable — 1,114,504 41,377 (1,155,881 ) — Long-term liabilities 2,382 37,784 — — 40,166 Redeemable preferred stock 100,000 — — — 100,000 Shareholders' equity (deficit) 239,689 (93,837 ) (41,113 ) 134,951 239,690 Total Liabilities and Shareholders' Equity $ 1,309,833 $ 1,171,484 $ 281 $ (1,024,883 ) $ 1,456,715 Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Balance Sheets (in thousands) As of December 31, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter ASSETS Current assets $ 85,647 $ 41,533 $ 589 $ (2,378 ) $ 125,391 Intercompany accounts receivable 1,113,417 — — (1,113,417 ) — Property and equipment (using successful efforts method of accounting) 5,506 1,170,122 30 — 1,175,658 Investment in subsidiaries (91,595 ) 94,134 — (2,539 ) — Assets of discontinued operations and other 369,995 3,980 — — 373,975 Total Assets $ 1,482,970 $ 1,309,769 $ 619 $ (1,118,334 ) $ 1,675,024 LIABILITIES AND SHAREHOLDERS' EQUITY Current liabilities $ 25,347 $ 148,109 $ 2,567 $ (2,383 ) $ 173,640 Intercompany accounts payable — 1,073,091 42,560 (1,115,651 ) — Long-term liabilities 925,767 43,762 — — 969,529 Redeemable preferred stock 100,000 — — — 100,000 Shareholders' equity (deficit) 431,856 44,807 (44,508 ) (300 ) 431,855 Total Liabilities and Shareholders' Equity $ 1,482,970 $ 1,309,769 $ 619 $ (1,118,334 ) $ 1,675,024 Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Operations (in thousands) Three Months Ended September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Revenues $ 2 $ 35,071 $ 143 $ (1,552 ) $ 33,664 Expenses 31,784 114,533 69 (1,552 ) 144,834 Income (loss) from continuing operations before equity in net income of subsidiaries (31,782 ) (79,462 ) 74 — (111,170 ) Equity in net income of subsidiaries (79,388 ) (366 ) — 79,754 — Income (loss) from continuing operations (111,170 ) (79,828 ) 74 79,754 (111,170 ) Gain on dilution of interest in Eureka Hunter Holdings, net of tax 2,211 — — — 2,211 Loss from discontinued operations, net of tax (4,222 ) — — — (4,222 ) Net income (loss) (113,181 ) (79,828 ) 74 79,754 (113,181 ) Dividends on preferred stock (8,848 ) — — — (8,848 ) Net income (loss) attributable to common shareholders $ (122,029 ) $ (79,828 ) $ 74 $ 79,754 $ (122,029 ) Three Months Ended September 30, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Revenues $ 10 $ 72,809 $ 430 $ (2,692 ) $ 70,557 Expenses 21,317 115,817 1,311 (4,289 ) 134,156 Income (loss) from continuing operations before equity in net income of subsidiaries (21,307 ) (43,008 ) (881 ) 1,597 (63,599 ) Equity in net income of wholly owned subsidiaries (105,440 ) (1,093 ) — 106,533 — Income (loss) from continuing operations (126,747 ) (44,101 ) (881 ) 108,130 (63,599 ) Loss from discontinued operations, net of tax — — (57,991 ) (1,599 ) (59,590 ) Gain (loss) on sale of discontinued operations, net of tax (259 ) — 1 — (258 ) Net income (loss) (127,006 ) (44,101 ) (58,871 ) 106,531 (123,447 ) Net income attributable to non-controlling interest — — — 2,764 2,764 Net income (loss) attributable to Magnum Hunter Resources Corporation (127,006 ) (44,101 ) (58,871 ) 109,295 (120,683 ) Dividends on preferred stock (8,848 ) — — — (8,848 ) Dividends on preferred stock of discontinued operations — — (6,644 ) — (6,644 ) Net income (loss) attributable to common shareholders $ (135,854 ) $ (44,101 ) $ (65,515 ) $ 109,295 $ (136,175 ) Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Operations (in thousands) Nine Months Ended September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Revenues $ 15 $ 133,281 $ 904 $ (5,614 ) $ 128,586 Expenses 94,992 275,583 473 (5,570 ) 365,478 Income (loss) from continuing operations before equity in net income of subsidiaries (94,977 ) (142,302 ) 431 (44 ) (236,892 ) Equity in net income of subsidiaries (141,915 ) (2,186 ) — 144,101 — Income (loss) from continuing operations (236,892 ) (144,488 ) 431 144,057 (236,892 ) Gain on dilution of interest in Eureka Hunter Holdings, net of tax 4,601 — — — 4,601 Income from discontinued operations, net of tax (8,485 ) — — — (8,485 ) Net income (loss) (240,776 ) (144,488 ) 431 144,057 (240,776 ) Dividends on preferred stock (26,543 ) — — — (26,543 ) Net income (loss) attributable to common shareholders $ (267,319 ) $ (144,488 ) $ 431 $ 144,057 $ (267,319 ) Nine Months Ended September 30, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Revenues $ 124 $ 313,898 $ 875 $ (6,822 ) $ 308,075 Expenses 92,622 363,587 1,748 (15,253 ) 442,704 Income (loss) from continuing operations before equity in net income of subsidiaries (92,498 ) (49,689 ) (873 ) 8,431 (134,629 ) Equity in net income of wholly owned subsidiaries (153,569 ) (1,922 ) — 155,491 — Income (loss) from continuing operations (246,067 ) (51,611 ) (873 ) 163,922 (134,629 ) Loss from discontinued operations, net of tax — — (93,532 ) (8,431 ) (101,963 ) Gain (loss) on sale of discontinued operations, net of tax (20,058 ) — 6,075 — (13,983 ) Net income (loss) (266,125 ) (51,611 ) (88,330 ) 155,491 (250,575 ) Net income attributable to non-controlling interest — — — 3,653 3,653 Net income (loss) attributable to Magnum Hunter Resources Corporation (266,125 ) (51,611 ) (88,330 ) 159,144 (246,922 ) Dividends on preferred stock (26,516 ) — — — (26,516 ) Dividends on preferred stock of discontinued operations — — (19,202 ) — (19,202 ) Net income (loss) attributable to common shareholders $ (292,641 ) $ (51,611 ) $ (107,532 ) $ 159,144 $ (292,640 ) Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Comprehensive Income (Loss) (in thousands) Three Months Ended September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Net income (loss) $ (113,181 ) $ (79,828 ) $ 74 $ 79,754 $ (113,181 ) Foreign currency translation loss — (2 ) — — (2 ) Unrealized loss on available for sale securities — (1,304 ) — — (1,304 ) Amounts reclassified for other than temporary impairment of available for sale securities — 2,115 — — 2,115 Comprehensive income (loss) (113,181 ) (79,019 ) 74 79,754 (112,372 ) Three Months Ended September 30, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Net income (loss) $ (127,006 ) $ (44,101 ) $ (58,871 ) $ 106,531 $ (123,447 ) Unrealized loss on available for sale securities — (2,583 ) — — (2,583 ) Comprehensive income (loss) (127,006 ) (46,684 ) (58,871 ) 106,531 (126,030 ) Comprehensive income attributable to non-controlling interest — — — 2,764 2,764 Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation $ (127,006 ) $ (46,684 ) $ (58,871 ) $ 109,295 $ (123,266 ) Nine Months Ended September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Net income (loss) $ (240,776 ) $ (144,488 ) $ 431 $ 144,057 $ (240,776 ) Foreign currency translation gain — 100 — 100 Unrealized loss on available for sale securities — (2,403 ) — — (2,403 ) Amounts reclassified for other than temporary impairment of available for sale securities — 11,107 — — 11,107 Comprehensive income (loss) (240,776 ) (135,684 ) 431 144,057 (231,972 ) Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Comprehensive Income (Loss) (in thousands) Nine Months Ended September 30, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Net income (loss) $ (266,125 ) $ (51,611 ) $ (88,330 ) $ 155,491 $ (250,575 ) Foreign currency translation loss — — (1,218 ) — (1,218 ) Unrealized loss on available for sale securities — (3,188 ) — — (3,188 ) Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc. 20,741 — — — 20,741 Comprehensive income (loss) (245,384 ) (54,799 ) (89,548 ) 155,491 (234,240 ) Comprehensive income attributable to non-controlling interest — — — 3,653 3,653 Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation $ (245,384 ) $ (54,799 ) $ (89,548 ) $ 159,144 $ (230,587 ) Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Cash Flows (in thousands) Nine Months Ended September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Cash flows from operating activities $ (88,117 ) $ 135,077 $ — $ (149 ) $ 46,811 Cash flows from investing activities (1,437 ) (121,813 ) — 149 (123,101 ) Cash flows from financing activities 33,670 (4,093 ) — — 29,577 Effect of exchange rate changes on cash — (4 ) — — (4 ) Net increase (decrease) in cash (55,884 ) 9,167 — — (46,717 ) Cash at beginning of period 64,165 (10,985 ) — — 53,180 Cash at end of period $ 8,281 $ (1,818 ) $ — $ — $ 6,463 Nine Months Ended September 30, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Cash flows from operating activities $ (261,039 ) $ 222,520 $ 52,074 $ — $ 13,555 Cash flows from investing activities 63,502 (211,560 ) (99,246 ) — (247,304 ) Cash flows from financing activities 193,885 2,232 38,542 — 234,659 Effect of exchange rate changes on cash — — 44 — 44 Net increase (decrease) in cash (3,652 ) 13,192 (8,586 ) — 954 Cash at beginning of period 47,895 (17,651 ) 11,469 — 41,713 Cash at end of period $ 44,243 $ (4,459 ) $ 2,883 $ — $ 42,667

SUBSEQUENT EVENTS

SUBSEQUENT EVENTS	9 Months Ended
	Sep. 30, 2015
Subsequent Events [Abstract]
SUBSEQUENT EVENTS	NOTE 19 - SUBSEQUENT EVENTS Event of Default under Credit Agreement and Second Lien Term Loan On October 8, 2015, the Company had an event of default under the Credit Agreement and the Second Lien Term Loan Agreement. The events of default resulted in cross-defaults under (a) the Company's derivative contracts with Bank of Montreal (such derivative contracts were terminated on November 2, 2015; see " Note 8 - Investments and Derivatives - Commodity and Financial Derivative Instruments"), (b) Alpha Hunter Drilling, LLC's equipment Note Payable, and (c) the Credit Agreement and Second Lien Term Loan Agreement, as applicable. The events of default may also result in cross-defaults under the Company's Senior Notes and its derivative contracts with Citibank, N.A., should there be an acceleration of debt under the Credit Agreement or Second Lien Term Loan Agreement. The Company has not received any notice of acceleration of any of the obligations described above. In addition, on November 3, 2015, the Company entered into forbearance agreements with the New First Lien Lenders with respect to certain events of default under the Credit Agreement and the Second Lien Term Loan Agreement, as applicable. See "Note 2 - Going Concern and Liquidity; Forbearance Agreements" and "Note 9 - Debt" . Suspension of Dividends on Preferred Stock On October 9, 2015, the Company announced that it had suspended monthly cash dividends on all of its outstanding series of preferred stock, as described in "Note 2 - Going Concern and Liquidity; Forbearance Agreements" and "Note 11 - Shareholders' Equity" . Hiring of Advisors for Restructuring On October 9, 2015, the Company announced it has engaged a financial advisor and a special legal advisor to advise management and the Board regarding potential strategic alternatives to enhance liquidity and address the Company's current capital structure. See "Note 2 - Going Concern and Liquidity; Forbearance Agreements" . Sale of Common Stock of NSE On October 20, 2015, the Company sold its entire investment in NSE consisting of 65,650,000 shares of common stock of NSE. See "Note 8 - Investments and Derivatives" . Termination of Certain Derivatives Contracts On November 2, 2015, the Company terminated its open commodity derivative positions with Bank of Montreal and received approximately $0.9 million in cash proceeds. See "Note 8 - Investments and Derivatives" . Sixth Amendment to the Credit Agreement On November 3, 2015, the Company entered into the Sixth Amendment in order to, among other things: i. assign amounts outstanding of approximately $5.0 million under the Credit Facility in the form of a single tranche of term loans to the New First Lien Lenders; ii. cash collateralize certain outstanding letters of credit issued under the Credit Facility in an aggregate amount of approximately $39.0 million ; and iii. provide the Company with an additional new term loan in the aggregate principal amount of approximately $16.0 million , which was funded in full by the New First Lien Lenders on the Closing Date. The Company believes that the Refinancing Facility will provide the Company with liquidity for approximately 30 to 45 days, during which time the Company and the New First Lien Lenders will continue to discuss various options and alternatives regarding the Company's balance sheet. See "Note 2 - Going Concern and Liquidity; Forbearance Agreements" and "Note 9 - Debt" . Forbearance Agreement Under the Indenture On November 3, 2015, the Company and the New Senior Notes Lenders entered into the Forbearance Agreement whereby the New Senior Notes Lenders agreed to forbear during the Forbearance Period from exercising any remedies as a result of any default, Default or Event of Default (as such terms are defined in the Indenture), under the Indenture that is present as a result of (i) the failure of the Company to make any interest payment otherwise due under the Senior Notes, (ii) a breach of the debt incurrence covenant under the Indenture, or (iii) the failure of the Company to make any interest payment otherwise due pursuant to the Second Lien Term Loan Agreement. See "Note 9 - Debt" . Second Amendment On November 3, 2015, the Company entered into the Second Amendment whereby the lenders under the Second Lien Term Loan Agreement agreed to forbear from exercising remedies with respect to any default or event of default that results from the failure of the Company to make any interest payment under the Second Lien Term Loan Agreement, the failure to meet certain financial covenants, and certain other matters. See "Note 9 - Debt" .

GENERAL (Policies)

GENERAL (Policies)	9 Months Ended
	Sep. 30, 2015
Accounting Policies [Abstract]
Presentation of Consolidated Financial Statements	Presentation of Consolidated Financial Statements The accompanying unaudited interim consolidated financial statements of Magnum Hunter have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). The preparation of these consolidated financial statements in accordance with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during reporting periods. Actual results could differ materially from those estimates. In the opinion of management, all adjustments (consisting of normal recurring adjustments unless otherwise indicated) necessary for the fair statement of the financial position and the results of operations for the interim periods presented have been reflected herein. The results of operations for interim periods are not necessarily indicative of the results to be expected for the full year. The year-end balance sheet data were derived from audited financial statements, but do not include all disclosures required by GAAP. Certain information and disclosures normally included in the consolidated financial statements prepared in accordance with GAAP that would substantially duplicate the disclosures contained in the audited consolidated financial statements as reported in the Company's Annual Report on Form 10-K have been condensed or omitted.
Reclassification of Prior-Year Balances	The Company has separately classified transportation and processing expenses incurred to deliver gas to processing plants and/or to selling points, which were previously included as components of lease operating expenses and severance taxes and marketing, in the accompanying consolidated statements of operations for all periods presented. The Company has also renamed lease operating expenses as "Production costs" and presented transportation and processing expenses as "Transportation, processing, and other related costs" in order to provide more meaningful information on costs associated with production and development. The Company has reclassified approximately $5.2 million of oil and gas transportation, processing and production taxes payables from accounts receivable - oil and natural gas sales to accounts payable as of December 31, 2014.
Non-Controlling Interest in Consolidated Subsidiaries	Non-Controlling Interest in Consolidated Subsidiaries Prior to July 24, 2014, the Company owned 87.5% of the equity interests in PRC Williston, LLC ("PRC Williston"), which sold substantially all of its assets on December 30, 2013. On July 24, 2014, the Company executed a settlement and release agreement with Drawbridge Special Opportunities Fund LP and Fortress Value Recovery Fund I LLC f/k/a D.B. Zwirn Special Opportunities Fund, L.P. As a result of this settlement agreement, the Company owns 100% of the equity interests in PRC Williston and has all rights and claims to its remaining assets and liabilities, which are not significant.
Regulated Activities	Regulated Activities Sentra Corporation, a wholly owned subsidiary of the Company, owns and operates distribution systems for retail sales of natural gas in south central Kentucky. Sentra Corporation's gas distribution billing rates are regulated by the Kentucky Public Service Commission based on recovery of purchased gas costs. The Company accounts for its operations based on the provisions of the FASB Accounting Standards Codification ("ASC") Subtopic 980-605, Regulated Operations-Revenue Recognition , which requires covered entities to record regulatory assets and liabilities resulting from actions of regulators.
Recently Issued Accounting Standards	Recently Issued Accounting Standards Accounting standards-setting organizations frequently issue new or revised accounting rules. The Company regularly reviews all new pronouncements to determine their impact, if any, on its financial statements. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) . ASU 2014-09 supersedes the revenue recognition requirements in ASC Topic 605, Revenue Recognition , and most industry-specific guidance throughout the Industry Topics of the ASC. The core principle of the revised standard is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods and services. To achieve that core principle, an entity should apply the following steps: (i) identify the contract(s) with a customer; (ii) identify the performance obligations in the contract; (iii) determine the transaction price; (iv) allocate the transaction price to the performance obligations in the contract; and (v) recognize revenue when (or as) the entity satisfies a performance obligation. ASU 2014-09 requires entities to disclose both quantitative and qualitative information that enables users of financial statements to understand the nature, amount, timing, and uncertainty of revenues and cash flows arising from contracts with customers. In August 2015, the FASB issued ASU 2015-14, Revenue from Contracts with Customers (Topic 606): Deferral of the Effective Date , which defers the effective date of ASU 2014-09 for all entities by one year. As such, this amendment is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those reporting periods. The guidance allows for either a "full retrospective" adoption or a "modified retrospective" adoption, and earlier application is permitted as of annual reporting periods beginning after December 14, 2016, including interim reporting periods within that reporting period. The Company is currently evaluating the adoption methods and the impact of this ASU on its consolidated financial statements and financial statement disclosures. In April 2015, the FASB issued ASU 2015-03, Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs . This update requires that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by this update. This amendment is effective for financial statements issued for fiscal years beginning after December 15, 2015, and interim periods within those fiscal years. Early adoption is permitted for financial statements that have not been previously issued. As of September 30, 2015 , the Company had $19.8 million of debt issuance costs, which under this standard would be reclassified from an asset to a direct deduction from the related debt liability. In April 2015, the FASB issued ASU 2015-04, Intangibles - Goodwill and Other - Internal-Use Software: Customer's Accounting for Fees Paid in a Cloud Computing Agreement . This update provides guidance to customers about whether a cloud computing arrangement includes a software license. If a cloud computing arrangement includes a software license, then the customer should account for the software license element of the arrangement consistent with the acquisition of other software licenses. If a cloud computing arrangement does not include a software license, the customer should account for the arrangement as a service contract. This update does not change GAAP for a customer's accounting for service contracts. This amendment is effective for annual periods, including interim periods within those annual periods, beginning after December 15, 2015. Early adoption is permitted for all entities, either prospectively to all arrangements entered into or materially modified after the effective date, or retrospectively. The Company has several cloud computing arrangements and is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.

ACQUISITIONS, DIVESTITURES, A28

ACQUISITIONS, DIVESTITURES, AND DISCONTINUED OPERATIONS (Tables)	9 Months Ended
	Sep. 30, 2015
Discontinued Operations and Disposal Groups [Abstract]
Deconsolidation of subsidiary, allocation of basis difference	The Company recognized a basis difference of $201.9 million upon deconsolidation related to its investment in Eureka Hunter Holdings which has been allocated to the following identifiable assets of Eureka Hunter Holdings: Identifiable Assets Ending Basis December 31, 2014 Basis Amortization Basis Reduction Ending Basis September 30, 2015 (in thousands) Fixed assets $ 5,088 $ (187 ) $ (289 ) $ 4,612 Intangible assets 155,189 (5,471 ) (8,727 ) 140,991 Goodwill 41,597 — (2,518 ) 39,079 Total basis difference $ 201,874 $ (5,658 ) $ (11,534 ) $ 184,682
Deconsolidation of subsidiary, results of operations and stockholders equity	Summarized income information for Eureka Hunter Holdings for the three and nine months ended September 30, 2015 is as follows: Three Months Ended Nine Months Ended (in thousands) Operating revenues $ 22,457 $ 53,581 Operating income $ 12,231 $ 13,549 Net income $ 11,469 $ 10,623 Magnum Hunter's interest in Eureka Hunter Holdings net income (loss) $ 5,222 $ 4,837 Basis difference amortization $ (1,780 ) $ (5,658 ) Loss on downward adjustment of units $ (7,664 ) $ (7,664 ) Magnum Hunter's equity in earnings (loss), net $ (4,222 ) $ (8,485 )
Schedule of discontinued operations	The following presents the results of the Company's discontinued operations for the three and nine months ended September 30, 2015 and 2014 . Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in thousands) Revenues $ — $ 9,113 $ — $ 32,073 Depreciation, depletion, amortization and accretion — (4,224 ) — (11,831 ) Other operating expenses — (6,401 ) — (23,703 ) Interest expense — (159 ) — (6,646 ) Loss on derivative contracts, net — (57,898 ) — (91,792 ) Loss from equity method investments (4,222 ) — (8,485 ) — Other expense — (21 ) — (64 ) Loss from discontinued operations, net of tax (4,222 ) (59,590 ) (8,485 ) (101,963 ) Gain on dilution of interest in Eureka Hunter Holdings, net of tax 2,211 — 4,601 — Loss on disposal of discontinued operations, net of taxes of $0 — (258 ) — (13,983 ) Loss from discontinued operations, net of taxes $ (2,011 ) $ (59,848 ) $ (3,884 ) $ (115,946 )

OIL & NATURAL GAS SALES (Tables

OIL & NATURAL GAS SALES (Tables)	9 Months Ended
	Sep. 30, 2015
Other Income and Expenses [Abstract]
Schedule of Oil Natural Gas And NGL Revenue	During the three and nine months ended September 30, 2015 and 2014 , the Company recognized sales from oil, natural gas, and natural gas liquids ("NGLs") as follows: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in thousands) Oil $ 9,962 $ 34,495 $ 34,593 $ 111,354 Natural gas 14,532 18,247 59,415 74,031 NGLs 3,358 9,768 16,653 36,862 Total oil and natural gas sales $ 27,852 $ 62,510 $ 110,661 $ 222,247

PROPERTY, PLANT, & EQUIPMENT (T

PROPERTY, PLANT, & EQUIPMENT (Tables)	9 Months Ended
	Sep. 30, 2015
Property, Plant and Equipment [Line Items]
Schedule of the Company's geological and geophysical costs and leasehold abandonments expense	During the three and nine months ended September 30, 2015 and 2014 , the Company recognized exploration expense as follows: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in thousands) Leasehold impairments Williston Basin $ 1,898 $ 17,846 $ 9,504 $ 37,765 Appalachian Basin 1,789 7,150 2,952 9,720 Western Kentucky — 1,925 — 3,820 South Texas 124 — 124 — Total leasehold impairments 3,811 26,921 12,580 51,305 Geological and geophysical 547 363 1,747 1,089 Total exploration expense $ 4,358 $ 27,284 $ 14,327 $ 52,394
Proved Oil and Natural Gas Properties
Property, Plant and Equipment [Line Items]
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure	The following sets forth the net capitalized costs under the successful efforts method for oil and natural gas properties as of: September 30, December 31, (in thousands) Mineral interests in properties Unproved leasehold costs $ 442,799 $ 481,643 Proved leasehold costs 276,818 257,185 Wells and related equipment and facilities 602,258 606,406 Advances to operators for wells in progress 1,278 1,411 Total costs 1,323,153 1,346,645 Less accumulated depletion, depreciation, and amortization (344,006 ) (248,410 ) Net capitalized costs $ 979,147 $ 1,098,235
Gas transportation, gathering and processing equipment and other
Property, Plant and Equipment [Line Items]
Capitalized Costs Relating to Oil and Gas Producing Activities Disclosure	The historical cost of gas transportation, gathering, and processing equipment and other property, presented on a gross basis with accumulated depreciation, as of September 30, 2015 and December 31, 2014 is summarized as follows: September 30, December 31, (in thousands) Gas transportation, gathering and processing equipment and other $ 102,959 $ 100,436 Less accumulated depreciation (28,542 ) (23,013 ) Net capitalized costs $ 74,417 $ 77,423

ASSET RETIREMENT OBLIGATIONS (T

ASSET RETIREMENT OBLIGATIONS (Tables)	9 Months Ended
	Sep. 30, 2015
Asset Retirement Obligation Disclosure [Abstract]
Summary of asset retirement obligation	The following table summarizes the Company's asset retirement obligation ("ARO") activities during the nine -month period ended September 30, 2015 and for the year ended December 31, 2014 : September 30, 2015 December 31, 2014 (in thousands) Asset retirement obligations at beginning of period $ 26,524 $ 16,216 Liabilities incurred 40 218 Liabilities settled (136 ) (107 ) Liabilities sold (74 ) (2,598 ) Accretion expense 1,928 1,478 Revisions in estimated liabilities (1) (596 ) 3,208 Reclassified from liabilities associated with assets of MHP — 8,109 Asset retirement obligation at end of period 27,686 26,524 Less: current portion (included in other liabilities) (1,235 ) (295 ) Asset retirement obligations, net of current portion $ 26,451 $ 26,229 ________________________________ (1) Revisions in estimated liabilities during 2014 relate to a change in assumptions used with respect to certain wells in the Appalachian Basin in Ohio and West Virginia.

FAIR VALUE OF FINANCIAL INSTR32

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)	9 Months Ended
	Sep. 30, 2015
Fair Value Disclosures [Abstract]
Schedule of inputs used to calculated fair value of convertible security embedded derivative	The key inputs used in the Black-Scholes option pricing model were as follows: September 30, 2015 Life (in years) 1.4 Risk-free interest rate 0.60% Estimated volatility 92% Dividend — GreenHunter stock price at end of period $0.30
Schedule of reconciliation of derivative assets and (liabilities) measured at fair value using significant unobservable inputs	The following table presents the changes in fair value of the derivative assets and liabilities measured at fair value using significant unobservable inputs (Level 3 inputs) for the nine -month period ended September 30, 2015 : Convertible Security Embedded Derivative Asset (in thousands) Fair value as of December 31, 2014 $ 75 Decrease in fair value recognized in gain (loss) on derivative contracts, net (72 ) Fair value as of September 30, 2015 $ 3
Fair value measurements on a recurring basis	The following tables present the fair value hierarchy levels of the Company's financial assets and liabilities which are measured and carried at fair value on a recurring basis: Fair Value Measurements on a Recurring Basis September 30, 2015 (in thousands) Assets Level 1 Level 2 Level 3 Available for sale securities $ 968 $ — $ — Commodity derivative assets — 1,051 — Convertible security derivative assets — — 3 Total assets at fair value $ 968 $ 1,051 $ 3 Liabilities Commodity derivative liabilities $ — $ 569 $ — Total liabilities at fair value $ — $ 569 $ — Fair Value Measurements on a Recurring Basis December 31, 2014 (in thousands) Assets Level 1 Level 2 Level 3 Available for sale securities $ 3,864 $ — $ — Commodity derivative assets — 16,511 — Convertible security derivative assets — — 75 Total assets at fair value $ 3,864 $ 16,511 $ 75
Carrying amounts and fair values of long-term debt	The following table presents the carrying amounts and fair values categorized by fair value hierarchy level of the Company's financial instruments not carried at fair value: September 30, 2015 December 31, 2014 Fair Value Hierarchy Carrying Amount Estimated Fair Value Carrying Amount Estimated Fair Value (in thousands) Senior Notes Level 2 $ 597,521 $ 275,700 $ 597,355 $ 498,000 MHR Senior Revolving Credit Facility Level 3 $ 5,000 $ 5,000 $ — $ — MHR Second Lien Term Loan Level 3 $ 327,469 $ 319,873 $ 329,140 $ 329,140 Equipment Notes Payable Level 3 $ 17,990 $ 17,990 $ 22,238 $ 22,150

INVESTMENTS AND DERIVATIVES (Ta

INVESTMENTS AND DERIVATIVES (Tables)	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Summary of changes in investments	Below is a summary of changes in investments for the nine months ended September 30, 2015 : Available for Sale Securities (in thousands) Carrying value as of December 31, 2014 $ 3,864 Loss from equity method investment (1) (494 ) Change in fair value recognized in other comprehensive loss (2,402 ) Carrying value as of September 30, 2015 $ 968 (1) As a result of the carrying value of the Company's investment in common stock of GreenHunter being reduced to zero from equity method losses, the Company is required to allocate any additional losses to its investment in the Series C preferred stock of GreenHunter. The Company recorded additional equity method loss against the carrying value of its investment in the Series C preferred stock of GreenHunter before recording any mark-to-market adjustments.
Summary of cost for equity securities and fair value	The cost for equity securities and their respective fair values as of September 30, 2015 and December 31, 2014 are as follows: September 30, 2015 (in thousands) Cost Gross Unrealized Losses Fair Value Securities available for sale, carried at fair value: Equity securities $ 532 $ — $ 532 Equity securities - related party (see "Note 14 - Related Party Transactions") 436 — 436 Total Securities available for sale $ 968 $ — $ 968 December 31, 2014 (in thousands) Cost Gross Unrealized Losses Fair Value Securities available for sale, carried at fair value: Equity securities $ 9,876 $ (7,323 ) $ 2,553 Equity securities - related party (see "Note 14 - Related Party Transactions") 2,200 (889 ) 1,311 Total Securities available for sale $ 12,076 $ (8,212 ) $ 3,864
Estimated fair values of commodity derivatives	As of September 30, 2015 , the Company had the following commodity derivative instruments: Weighted Average Natural Gas Period MMBtu/day Price per MMBtu Collars Aug 2015 - Dec 2015 80,000 $2.66 - $3.15 Weighted Average Crude Oil Period Bbl/day Price per Bbl Collars Aug 2015 - Dec 2015 1,500 $45.00 - $48.00 Ceilings sold (call) Jan 2015 - Dec 2015 1,570 $120.00 Floors sold (put) Jan 2015 - Dec 2015 259 $70.00
Schedule of fair value of commodity derivative contracts	The following table summarizes the fair value of the Company's commodity and financial derivative contracts as of the dates indicated: Derivatives not designated as hedging instruments Derivative Assets Derivative Liabilities September 30, December 31, September 30, December 31, (in thousands) Commodity Derivative assets $ 1,051 $ 16,511 $ — $ — Derivative liabilities — — 569 — Total commodity $ 1,051 $ 16,511 $ 569 $ — Financial Derivative assets $ 3 $ 75 $ — $ — Total financial $ 3 $ 75 $ — $ — Total derivatives $ 1,054 $ 16,586 $ 569 $ —
Schedule of commodity derivatives and master netting arrangements	The tables below summarize the Company's commodity derivatives and the effect of master netting arrangements on the presentation of those derivatives in the Company's consolidated balance sheets as of: September 30, 2015 Gross Amounts of Recognized Assets and Liabilities Gross Amounts Offset on the Consolidated Balance Sheet Net Amount (in thousands) Current assets: Fair value of derivative contracts $ 1,051 $ — $ 1,051 Current liabilities: Fair value of derivative contracts (569 ) — (569 ) $ 482 $ — $ 482 December 31, 2014 Gross Amounts of Assets and Liabilities Gross Amounts Offset on the Consolidated Balance Sheet Net Amount (in thousands) Current assets: Fair value of derivative contracts $ 18,146 $ (1,635 ) $ 16,511 Current liabilities: Fair value of derivative contracts (1,635 ) 1,635 — $ 16,511 $ — $ 16,511
Schedule of the realized and unrealized gain (loss) on derivatives	The following table summarizes the net gain (loss) on all derivative contracts included in gain (loss) on derivative contracts, net on the consolidated statements of operations for the three and nine months ended September 30, 2015 and 2014 : Three Months Ended September 30, Nine Months Ended 2015 2014 2015 2014 (in thousands) Gain (loss) on settled transactions $ (380 ) $ 477 $ 2,814 $ (4,074 ) Gain (loss) on open contracts 948 7,785 531 3,741 Total gain (loss), net $ 568 $ 8,262 $ 3,345 $ (333 )

DEBT (Tables)

DEBT (Tables)	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Schedule of long-term debt	Long-term debt at September 30, 2015 and December 31, 2014 consisted of the following: September 30, December 31, (in thousands) Senior Notes payable due May 15, 2020, interest rate of 9.75%, net of unamortized net discount of $2.5 million and $2.6 million at September 30, 2015 and December 31, 2014, respectively $ 597,521 $ 597,355 Various equipment and real estate notes payable with maturity dates February 2015 - November 2017, interest rates of 4.25% - 7.94% 17,990 22,238 MHR Senior Revolving Credit Facility due on demand as of October 8, 2015, original maturity of October 22, 2018, interest rate of 4.21% at September 30, 2015 and 2.92% at December 31, 2014 5,000 — MHR second lien term loan due on demand as of October 8, 2015, original maturity of October 22, 2019, interest rate of 8.5%, net of unamortized discount of $9.1 million and $10.0 million at September 30, 2015 and December 31, 2014, respectively 327,469 329,140 947,980 948,733 Less: current portion (939,680 ) (10,770 ) Total long-term debt obligations, net of current portion $ 8,300 $ 937,963
Schedule of expected approximate annual maturities of debt	The following table presents the scheduled or expected approximate annual maturities of debt, gross of unamortized discount of $11.6 million as of September 30, 2015 : (in thousands) 2015 $ 946,533 2016 8,226 2017 1,240 2018 558 2019 207 Thereafter 2,826 Total $ 959,590
Schedule of Interest Expense	The following table sets forth interest expense for the three and nine month periods ended September 30, 2015 and 2014 , respectively: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in thousands) Interest expense incurred on debt, net of amounts capitalized $ 23,136 $ 16,937 $ 69,056 $ 50,021 Amortization and write-off of deferred financing costs 1,895 999 3,542 5,806 Total interest expense $ 25,031 $ 17,936 $ 72,598 $ 55,827

SHARE-BASED COMPENSATION (Table

SHARE-BASED COMPENSATION (Tables)	9 Months Ended
	Sep. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of common stock option and stock appreciation rights	A summary of common stock option activity for the nine months ended September 30, 2015 and 2014 is presented below: Nine Months Ended September 30, 2015 2014 2015 2014 (in thousands of shares) Weighted Average Exercise Price per Share Outstanding at beginning of period 13,195 16,891 $ 5.92 $ 5.69 Granted — — $ — $ — Exercised (100 ) (2,355 ) $ 0.51 $ 4.09 Forfeited (3,002 ) (1,241 ) $ 6.30 $ 6.28 Outstanding at end of period 10,093 13,295 $ 5.86 $ 5.91 Exercisable at end of period 7,953 9,179 $ 5.95 $ 6.22
Summary of non-vested shares	A summary of the Company's non-vested common stock options and stock appreciation rights for the nine months ended September 30, 2015 and 2014 is presented below: Nine Months Ended September 30, 2015 2014 (in thousands of shares) Non-vested at beginning of period 4,055 6,908 Granted — — Vested (1,637 ) (1,916 ) Forfeited (278 ) (876 ) Non-vested at end of period 2,140 4,116

SHAREHOLDERS' EQUITY (Tables)

SHAREHOLDERS' EQUITY (Tables)	9 Months Ended
	Sep. 30, 2015
Equity [Abstract]
Schedule of dividends paid	A summary of the Company's preferred dividends for the three and nine months ended September 30, 2015 and 2014 is presented below: Three Months Ended September 30, Nine Months Ended September 30, 2015 2014 2015 2014 (in thousands) (in thousands) Dividend on Series C Preferred Stock $ 2,562 $ 2,562 $ 7,686 $ 7,686 Dividend on Series D Preferred Stock 4,424 4,424 13,273 13,273 Dividend on Series E Preferred Stock 1,862 1,862 5,584 5,557 Total dividends on Preferred Stock $ 8,848 $ 8,848 $ 26,543 $ 26,516 Dividend on Eureka Hunter Holdings Series A Preferred Units $ — $ 4,338 $ — $ 12,619 Accretion of the carrying value of the Eureka Hunter Holdings Series A Preferred Units — 2,306 — 6,583 Total dividends on Preferred Stock of discontinued operations $ — $ 6,644 $ — $ 19,202
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share	The following table summarizes the types of potentially dilutive securities outstanding as of September 30, 2015 and 2014 : September 30, 2015 2014 (in thousands of shares) Series E Preferred Stock 10,946 10,946 Warrants 19,173 19,214 Unvested restricted shares 4,157 1,445 Common stock options and stock appreciation rights 10,093 13,295 Total 44,369 44,900

RELATED PARTY TRANSACTIONS (Tab

RELATED PARTY TRANSACTIONS (Tables)	9 Months Ended
	Sep. 30, 2015
Related Party Transactions [Abstract]
Schedule of Related Party Balances	The following table sets forth the related party balances as of September 30, 2015 and December 31, 2014 : September 30, 2015 December 31, 2014 (in thousands) GreenHunter (1) Accounts payable - net $ (783 ) $ (224 ) Derivative assets (2) $ 3 $ 75 Investments (2) $ 436 $ 1,311 Notes receivable (2) $ 816 $ 1,224 Prepaid expenses $ 5 $ 1,000 Eureka Hunter Holdings (3) Accounts receivable (payable) - net $ (10,405 ) $ 122 Assets of discontinued operations $ 343,307 $ 347,191 Pilatus Hunter (4) Accounts receivable - net $ 12 $ 12 Classic Petroleum, Inc. (5) Accounts payable $ (51 ) $ — Kirk Trosclair Enterprises, LLC (6) Accounts payable $ (7 ) $ —
Schedule of Related Party Transactions	The following table sets forth the related party transaction activities for the three and nine months ended September 30, 2015 and 2014 , respectively: Three Months Ended Nine Months Ended 2015 2014 2015 2014 (in thousands) GreenHunter Production costs (1) $ 840 $ 894 $ 3,039 $ 1,969 Midstream natural gas gathering, processing, and marketing $ — $ 132 $ — $ 532 Oilfield services (1) $ 151 $ — $ 256 $ — General and administrative (1) $ 7 $ — $ 19 $ 36 Interest income (2) $ 23 $ 38 $ 94 $ 121 Miscellaneous income (expense) (2) $ (1,709 ) $ 55 $ (1,599 ) $ 165 Loss from equity method investment (2) $ 176 $ 79 $ 494 $ 436 Capitalized costs incurred (1) $ 5 $ — $ 470 $ — Pilatus Hunter, LLC (4) General and administrative $ 81 $ 49 $ 117 $ 207 Eureka Hunter Holdings (3) Production costs $ 144 $ — $ 740 $ — Transportation, processing, and other related costs $ 7,503 $ — $ 18,218 $ — Oilfield services $ 11 $ — $ 27 $ — Capitalized costs incurred $ — $ 715 $ 121 $ 2,526 Classic Petroleum (5) Capitalized costs incurred $ 21 $ 447 $ 206 $ 971 Kirk Trosclair Enterprises, LLC (6) General and administrative $ 52 $ — $ 141 $ — _________________________________ (1) GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman and a major shareholder. Triad Hunter and Viking International Resources Co., Inc., wholly owned subsidiaries of the Company, receive services related to brine water and rental equipment from GreenHunter and certain affiliated companies. The Company believes that such services were and are provided at competitive market rates and were and are comparable to, or more attractive than, rates that could be obtained from unaffiliated third party suppliers of such services. (2) On February 17, 2012, the Company sold its wholly owned subsidiary, Hunter Disposal, to GreenHunter Water, LLC ("GreenHunter Water"), a wholly owned subsidiary of GreenHunter. The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note it received as partial consideration for the sale. See "Note 7 - Fair Value of Financial Instruments" for additional information. The Company has recorded interest income as a result of the note receivable from GreenHunter. Also as a result of this transaction, the Company has an equity method investment in GreenHunter that is included in derivatives and investment in affiliates - equity method and an available for sale investment in GreenHunter included in investments. Miscellaneous income (expense) includes other than temporary impairment loss on the GreenHunter available for sale security of $1.8 million for the three and nine months ended September 2015. See "Note 8 - Investments and Derivatives" for additional information. (3) Following a series of transactions up to and including, December 18, 2014, the Company no longer held a controlling financial interest in Eureka Hunter Holdings. The Company deconsolidated Eureka Hunter Holdings and accounts for its retained interest as of December 31, 2014 under the equity method of accounting. As discussed in "Note 3 - Acquisitions, Divestitures, and Discontinued Operations" , in June 2015 the Company adopted a plan to dispose of its equity method investment in Eureka Hunter Holdings, and has classified the related operations as discontinued operations and the investment as assets of discontinued operations for all periods presented. (4) The Company rented an airplane for business use for certain members of Company management at various times from Pilatus Hunter, LLC, an entity 100% owned by Mr. Evans. Airplane rental expenses are recorded in general and administrative expense. (5) Classic Petroleum, Inc. is an entity owned by the brother of James W. Denny, III, the Company's former Executive Vice President and President of the Company's Appalachian Division. Triad Hunter received land brokerage services from Classic Petroleum, Inc., including courthouse abstracting, contract negotiations, GIS mapping and leasing services. (6) On July 18, 2014, the Company entered into a consulting agreement with Kirk J. Trosclair, a former executive of Alpha Hunter Drilling, LLC, a wholly owned subsidiary of the Company. Mr. Trosclair ceased employment with the Company on July 18, 2014 and is currently the Chief Operating Officer of GreenHunter. The agreement has a term of 12 months and provides that Mr. Trosclair will receive monthly compensation of $10,000 , and Mr. Trosclair is eligible to continue vesting in previously granted stock options and unvested restricted stock awards, subject to continued service under the consulting agreement. In connection with this agreement, for the nine months ended September 30, 2015 , the Company paid Mr. Trosclair $141,000 , which includes reimbursement of expenses incurred on behalf of the Company, and recognized $161,888 in stock compensation expense.

SUPPLEMENTAL CASH FLOW INFORM38

SUPPLEMENTAL CASH FLOW INFORMATION (Tables)	9 Months Ended
	Sep. 30, 2015
Supplemental Cash Flow Elements [Abstract]
Schedule of Cash Flow, Supplemental Disclosures	The following table summarizes cash paid (received) for interest, as well as non-cash investing and financing transactions: Nine Months Ended September 30, 2015 2014 (in thousands) Cash paid for interest $ 49,271 $ 38,565 Non-cash transactions Common stock issued for 401k matching contributions $ 1,878 $ 1,593 Non-cash consideration received from sale of assets $ — $ 9,447 Change in accrued capital expenditures $ (98,296 ) $ 129,778 Non-cash changes in asset retirement obligation $ (556 ) $ 2,439 Eureka Hunter Holdings Series A Preferred Unit dividends paid in kind $ — $ 1,950

SEGMENT REPORTING (Tables)

SEGMENT REPORTING (Tables)	9 Months Ended
	Sep. 30, 2015
Segment Reporting [Abstract]
Details of operating activities by segment	The following tables set forth operating activities and capital expenditures by segment for the three and nine months ended, and segment assets as of September 30, 2015 and 2014 , respectively. As of and for the Three Months Ended September 30, 2015 Upstream Midstream and Marketing Oilfield Services Corporate Unallocated (1) Inter-segment Eliminations Total (in thousands) Total revenue $ 28,252 $ 118 $ 6,368 $ — $ (1,074 ) $ 33,664 Depletion, depreciation, amortization and accretion 22,444 — 934 — — 23,378 (Gain) loss on sale of assets, net (2,956 ) — 64 — — (2,892 ) Other operating expenses 87,629 88 3,584 7,603 (1,074 ) 97,830 Other expense (2,627 ) — (132 ) (23,759 ) — (26,518 ) Income (loss) from continuing operations before income tax (81,492 ) 30 1,654 (31,362 ) — (111,170 ) Total loss from discontinued operations, net of tax — — — (2,011 ) — (2,011 ) Net income (loss) $ (81,492 ) $ 30 $ 1,654 $ (33,373 ) $ — $ (113,181 ) Total assets $ 1,031,975 $ 104 $ 44,477 $ 384,156 $ (3,997 ) $ 1,456,715 Total capital expenditures $ 5,278 $ — $ 181 $ 184 $ — $ 5,643 As of and for the Three Months Ended September 30, 2014 Upstream Midstream and Marketing Oilfield Services Corporate Unallocated Inter-segment Eliminations Total (in thousands) Total revenue $ 63,438 $ 1,133 $ 8,176 $ — $ (2,190 ) $ 70,557 Depletion, depreciation, amortization and accretion 31,218 — 929 — — 32,147 Gain on sale of assets, net (7,988 ) — — — — (7,988 ) Other operating expenses 87,035 937 6,569 11,711 (3,789 ) 102,463 Other income (expense) 1,908 — (205 ) (9,237 ) — (7,534 ) Income (loss) from continuing operations before income tax (44,919 ) 196 473 (20,948 ) 1,599 (63,599 ) Total income (loss) from discontinued operations, net of tax (259 ) (57,991 ) — 1 (1,599 ) (59,848 ) Net income (loss) $ (45,178 ) $ (57,795 ) $ 473 $ (20,947 ) $ — $ (123,447 ) Total assets $ 1,475,305 $ 443,008 $ 45,661 $ 74,614 $ (5,023 ) $ 2,033,565 Total capital expenditures $ 104,265 $ 88,525 $ 3,628 $ 21 $ — $ 196,439 As of and for the Nine Months Ended September 30, 2015 Upstream Midstream and Marketing Oilfield Services Corporate Unallocated (1) Inter-segment Eliminations Total (in thousands) Total revenue $ 112,167 $ 867 $ 19,920 $ — $ (4,368 ) $ 128,586 Depletion, depreciation, amortization and accretion 100,607 — 2,939 — (105 ) 103,441 (Gain) loss on sale of assets, net (31,340 ) — 52 — — (31,288 ) Other operating expenses 176,618 689 13,709 27,247 (4,219 ) 214,044 Other expense (11,440 ) — (440 ) (67,401 ) — (79,281 ) Income (loss) from continuing operations before income tax (145,158 ) 178 2,780 (94,648 ) (44 ) (236,892 ) Total loss from discontinued operations, net of tax — — — (3,884 ) — (3,884 ) Net income (loss) $ (145,158 ) $ 178 $ 2,780 $ (98,532 ) $ (44 ) $ (240,776 ) Total assets $ 1,031,975 $ 104 $ 44,477 $ 384,156 $ (3,997 ) $ 1,456,715 Total capital expenditures $ 65,700 $ — $ 650 $ 2,042 $ — $ 68,392 As of and for the Nine Months Ended September 30, 2014 Upstream Midstream and Marketing Oilfield Services Corporate Unallocated Inter-segment Eliminations Total (in thousands) Total revenue $ 223,788 $ 66,726 $ 23,882 $ — $ (6,321 ) $ 308,075 Depletion, depreciation, amortization and accretion 87,346 — 2,557 — — 89,903 Gain on sale of assets, net (4,231 ) — (369 ) — — (4,600 ) Other operating expenses 197,013 66,380 19,643 35,253 (14,752 ) 303,537 Other income (expense) 1,740 — (625 ) (54,979 ) — (53,864 ) Income (loss) from continuing operations before income tax (54,600 ) 346 1,426 (90,232 ) 8,431 (134,629 ) Total income (loss) from discontinued operations, net of tax 3,353 (98,093 ) — (12,775 ) (8,431 ) (115,946 ) Net income (loss) $ (51,247 ) $ (97,747 ) $ 1,426 $ (103,007 ) $ — $ (250,575 ) Total assets $ 1,475,305 $ 443,008 $ 45,661 $ 74,614 $ (5,023 ) $ 2,033,565 Total capital expenditures $ 321,024 $ 171,152 $ 6,575 $ 127 $ — $ 498,878

CONDENSED CONSOLIDATING GUARA40

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Tables)	9 Months Ended
	Sep. 30, 2015
Condensed Financial Statements, Captions [Line Items]
Schedule of Comprehensive Income (Loss)	Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Comprehensive Income (Loss) (in thousands) Three Months Ended September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Net income (loss) $ (113,181 ) $ (79,828 ) $ 74 $ 79,754 $ (113,181 ) Foreign currency translation loss — (2 ) — — (2 ) Unrealized loss on available for sale securities — (1,304 ) — — (1,304 ) Amounts reclassified for other than temporary impairment of available for sale securities — 2,115 — — 2,115 Comprehensive income (loss) (113,181 ) (79,019 ) 74 79,754 (112,372 ) Three Months Ended September 30, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Net income (loss) $ (127,006 ) $ (44,101 ) $ (58,871 ) $ 106,531 $ (123,447 ) Unrealized loss on available for sale securities — (2,583 ) — — (2,583 ) Comprehensive income (loss) (127,006 ) (46,684 ) (58,871 ) 106,531 (126,030 ) Comprehensive income attributable to non-controlling interest — — — 2,764 2,764 Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation $ (127,006 ) $ (46,684 ) $ (58,871 ) $ 109,295 $ (123,266 ) Nine Months Ended September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Net income (loss) $ (240,776 ) $ (144,488 ) $ 431 $ 144,057 $ (240,776 ) Foreign currency translation gain — 100 — 100 Unrealized loss on available for sale securities — (2,403 ) — — (2,403 ) Amounts reclassified for other than temporary impairment of available for sale securities — 11,107 — — 11,107 Comprehensive income (loss) (240,776 ) (135,684 ) 431 144,057 (231,972 ) Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Comprehensive Income (Loss) (in thousands) Nine Months Ended September 30, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Net income (loss) $ (266,125 ) $ (51,611 ) $ (88,330 ) $ 155,491 $ (250,575 ) Foreign currency translation loss — — (1,218 ) — (1,218 ) Unrealized loss on available for sale securities — (3,188 ) — — (3,188 ) Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc. 20,741 — — — 20,741 Comprehensive income (loss) (245,384 ) (54,799 ) (89,548 ) 155,491 (234,240 ) Comprehensive income attributable to non-controlling interest — — — 3,653 3,653 Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation $ (245,384 ) $ (54,799 ) $ (89,548 ) $ 159,144 $ (230,587 )
Debt Securities Under Universal Shelf Registration Statement Form S-4
Condensed Financial Statements, Captions [Line Items]
Schedule of condensed consolidating balance sheets	Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Balance Sheets (in thousands) As of September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter ASSETS Current assets $ 11,316 $ 32,016 $ 281 $ (3,953 ) $ 39,660 Intercompany accounts receivable 1,153,644 — — (1,153,644 ) — Property and equipment (using successful efforts method of accounting) 6,461 1,047,148 — (45 ) 1,053,564 Investment in subsidiaries (224,706 ) 91,947 — 132,759 — Assets of discontinued operations and other 363,118 373 — — 363,491 Total Assets $ 1,309,833 $ 1,171,484 $ 281 $ (1,024,883 ) $ 1,456,715 LIABILITIES AND SHAREHOLDERS' EQUITY Current liabilities $ 967,762 $ 113,033 $ 17 $ (3,953 ) $ 1,076,859 Intercompany accounts payable — 1,114,504 41,377 (1,155,881 ) — Long-term liabilities 2,382 37,784 — — 40,166 Redeemable preferred stock 100,000 — — — 100,000 Shareholders' equity (deficit) 239,689 (93,837 ) (41,113 ) 134,951 239,690 Total Liabilities and Shareholders' Equity $ 1,309,833 $ 1,171,484 $ 281 $ (1,024,883 ) $ 1,456,715 Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Balance Sheets (in thousands) As of December 31, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter ASSETS Current assets $ 85,647 $ 41,533 $ 589 $ (2,378 ) $ 125,391 Intercompany accounts receivable 1,113,417 — — (1,113,417 ) — Property and equipment (using successful efforts method of accounting) 5,506 1,170,122 30 — 1,175,658 Investment in subsidiaries (91,595 ) 94,134 — (2,539 ) — Assets of discontinued operations and other 369,995 3,980 — — 373,975 Total Assets $ 1,482,970 $ 1,309,769 $ 619 $ (1,118,334 ) $ 1,675,024 LIABILITIES AND SHAREHOLDERS' EQUITY Current liabilities $ 25,347 $ 148,109 $ 2,567 $ (2,383 ) $ 173,640 Intercompany accounts payable — 1,073,091 42,560 (1,115,651 ) — Long-term liabilities 925,767 43,762 — — 969,529 Redeemable preferred stock 100,000 — — — 100,000 Shareholders' equity (deficit) 431,856 44,807 (44,508 ) (300 ) 431,855 Total Liabilities and Shareholders' Equity $ 1,482,970 $ 1,309,769 $ 619 $ (1,118,334 ) $ 1,675,024
Schedule of condensed consolidating statements of operations	Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Operations (in thousands) Three Months Ended September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Revenues $ 2 $ 35,071 $ 143 $ (1,552 ) $ 33,664 Expenses 31,784 114,533 69 (1,552 ) 144,834 Income (loss) from continuing operations before equity in net income of subsidiaries (31,782 ) (79,462 ) 74 — (111,170 ) Equity in net income of subsidiaries (79,388 ) (366 ) — 79,754 — Income (loss) from continuing operations (111,170 ) (79,828 ) 74 79,754 (111,170 ) Gain on dilution of interest in Eureka Hunter Holdings, net of tax 2,211 — — — 2,211 Loss from discontinued operations, net of tax (4,222 ) — — — (4,222 ) Net income (loss) (113,181 ) (79,828 ) 74 79,754 (113,181 ) Dividends on preferred stock (8,848 ) — — — (8,848 ) Net income (loss) attributable to common shareholders $ (122,029 ) $ (79,828 ) $ 74 $ 79,754 $ (122,029 ) Three Months Ended September 30, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Revenues $ 10 $ 72,809 $ 430 $ (2,692 ) $ 70,557 Expenses 21,317 115,817 1,311 (4,289 ) 134,156 Income (loss) from continuing operations before equity in net income of subsidiaries (21,307 ) (43,008 ) (881 ) 1,597 (63,599 ) Equity in net income of wholly owned subsidiaries (105,440 ) (1,093 ) — 106,533 — Income (loss) from continuing operations (126,747 ) (44,101 ) (881 ) 108,130 (63,599 ) Loss from discontinued operations, net of tax — — (57,991 ) (1,599 ) (59,590 ) Gain (loss) on sale of discontinued operations, net of tax (259 ) — 1 — (258 ) Net income (loss) (127,006 ) (44,101 ) (58,871 ) 106,531 (123,447 ) Net income attributable to non-controlling interest — — — 2,764 2,764 Net income (loss) attributable to Magnum Hunter Resources Corporation (127,006 ) (44,101 ) (58,871 ) 109,295 (120,683 ) Dividends on preferred stock (8,848 ) — — — (8,848 ) Dividends on preferred stock of discontinued operations — — (6,644 ) — (6,644 ) Net income (loss) attributable to common shareholders $ (135,854 ) $ (44,101 ) $ (65,515 ) $ 109,295 $ (136,175 ) Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Operations (in thousands) Nine Months Ended September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Revenues $ 15 $ 133,281 $ 904 $ (5,614 ) $ 128,586 Expenses 94,992 275,583 473 (5,570 ) 365,478 Income (loss) from continuing operations before equity in net income of subsidiaries (94,977 ) (142,302 ) 431 (44 ) (236,892 ) Equity in net income of subsidiaries (141,915 ) (2,186 ) — 144,101 — Income (loss) from continuing operations (236,892 ) (144,488 ) 431 144,057 (236,892 ) Gain on dilution of interest in Eureka Hunter Holdings, net of tax 4,601 — — — 4,601 Income from discontinued operations, net of tax (8,485 ) — — — (8,485 ) Net income (loss) (240,776 ) (144,488 ) 431 144,057 (240,776 ) Dividends on preferred stock (26,543 ) — — — (26,543 ) Net income (loss) attributable to common shareholders $ (267,319 ) $ (144,488 ) $ 431 $ 144,057 $ (267,319 ) Nine Months Ended September 30, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Revenues $ 124 $ 313,898 $ 875 $ (6,822 ) $ 308,075 Expenses 92,622 363,587 1,748 (15,253 ) 442,704 Income (loss) from continuing operations before equity in net income of subsidiaries (92,498 ) (49,689 ) (873 ) 8,431 (134,629 ) Equity in net income of wholly owned subsidiaries (153,569 ) (1,922 ) — 155,491 — Income (loss) from continuing operations (246,067 ) (51,611 ) (873 ) 163,922 (134,629 ) Loss from discontinued operations, net of tax — — (93,532 ) (8,431 ) (101,963 ) Gain (loss) on sale of discontinued operations, net of tax (20,058 ) — 6,075 — (13,983 ) Net income (loss) (266,125 ) (51,611 ) (88,330 ) 155,491 (250,575 ) Net income attributable to non-controlling interest — — — 3,653 3,653 Net income (loss) attributable to Magnum Hunter Resources Corporation (266,125 ) (51,611 ) (88,330 ) 159,144 (246,922 ) Dividends on preferred stock (26,516 ) — — — (26,516 ) Dividends on preferred stock of discontinued operations — — (19,202 ) — (19,202 ) Net income (loss) attributable to common shareholders $ (292,641 ) $ (51,611 ) $ (107,532 ) $ 159,144 $ (292,640 )
Schedule of condensed consolidating statements of cash flows	Magnum Hunter Resources Corporation and Subsidiaries Condensed Consolidating Statements of Cash Flows (in thousands) Nine Months Ended September 30, 2015 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Cash flows from operating activities $ (88,117 ) $ 135,077 $ — $ (149 ) $ 46,811 Cash flows from investing activities (1,437 ) (121,813 ) — 149 (123,101 ) Cash flows from financing activities 33,670 (4,093 ) — — 29,577 Effect of exchange rate changes on cash — (4 ) — — (4 ) Net increase (decrease) in cash (55,884 ) 9,167 — — (46,717 ) Cash at beginning of period 64,165 (10,985 ) — — 53,180 Cash at end of period $ 8,281 $ (1,818 ) $ — $ — $ 6,463 Nine Months Ended September 30, 2014 Magnum Hunter 100% Owned Guarantor Non Guarantor Consolidating/ Eliminating Adjustments Magnum Hunter Cash flows from operating activities $ (261,039 ) $ 222,520 $ 52,074 $ — $ 13,555 Cash flows from investing activities 63,502 (211,560 ) (99,246 ) — (247,304 ) Cash flows from financing activities 193,885 2,232 38,542 — 234,659 Effect of exchange rate changes on cash — — 44 — 44 Net increase (decrease) in cash (3,652 ) 13,192 (8,586 ) — 954 Cash at beginning of period 47,895 (17,651 ) 11,469 — 41,713 Cash at end of period $ 44,243 $ (4,459 ) $ 2,883 $ — $ 42,667

GENERAL (Details)

GENERAL (Details) - USD ($)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014	Jul. 23, 2014
Summary of Significant Accounting Policies [Line Items]
Debt issuance costs	$ 19,765,000		$ 19,765,000		$ 22,856,000
PRC Williston, LLC (PRC)
Summary of Significant Accounting Policies [Line Items]
Consolidated controlling interest (as a percent)	100.00%		100.00%			87.50%
Sentra Corporation
Summary of Significant Accounting Policies [Line Items]
Regulated operating revenue, gas	$ 42,845	$ 27,656	$ 504,075	$ 473,555
Accounts Payable
Summary of Significant Accounting Policies [Line Items]
Prior period reclassification adjustment					5,200,000
Accounts Receivable
Summary of Significant Accounting Policies [Line Items]
Prior period reclassification adjustment					$ (5,200,000)

GOING CONCERN AND LIQUIDITY; 42

GOING CONCERN AND LIQUIDITY; FORBEARANCE AGREEMENTS (Details)

Nov. 02, 2015

Oct. 08, 2015

Sep. 08, 2015

Apr. 17, 2015

Oct. 31, 2015USD ($)periodofficer

Sep. 30, 2015USD ($)

Nov. 15, 2015USD ($)

Nov. 05, 2015USD ($)

Nov. 03, 2015USD ($)

Aug. 07, 2015USD ($)

Dec. 31, 2014USD ($)

Oct. 03, 2014$ / MMBTU

Sep. 30, 2014USD ($)

Dec. 31, 2013USD ($)

Debt Instrument [Line Items]

Cash and cash equivalents

$ 6,463,000

$ 53,180,000

$ 42,667,000

$ 41,713,000

Working capital deficit

(1,037,200,000)

Accounts payable, net (in excess of 180 days outstanding)

$ 1,400,000

Outstanding borrowings

947,980,000

948,733,000

Senior Notes

Debt Instrument [Line Items]

Interest payable, current

$ 22,100,000

Period interest to be paid before event of default

30 days

Senior Notes | 9.75 Percent Senior Notes Due May 15, 2020

Debt Instrument [Line Items]

Outstanding borrowings

$ 597,521,000

$ 597,355,000

Long-term debt, stated interest rate

9.75%

9.75%

Term Loan | Line of Credit | Second Lien Amendment

Debt Instrument [Line Items]

Number of days accounts payable outstanding

180 days

180 days

90 days

Number of days to cure technical default

30 days

Subsequent Event | Senior Notes

Debt Instrument [Line Items]

Number of consecutive quarters dividend fully paid at increased annual dividend rates | period

2

Subsequent Event | Term Loan | Sixth Amendment

Debt Instrument [Line Items]

Borrowing base

$ 16,000,000

Amount outstanding

5,000,000

Subsequent Event | Term Loan | Forbearance Agreement

Debt Instrument [Line Items]

Borrowing base

70,000,000

Subsequent Event | Senior Secured Term Loan Facility | Sixth Amendment

Debt Instrument [Line Items]

Borrowing base

60,000,000

Incremental borrowing capacity

10,000,000

Subsequent Event | Letter of Credit | Sixth Amendment

Debt Instrument [Line Items]

Collateral amount of outstanding debt

$ 39,000,000

Subsequent Event | Series C, Series D and Series E Preferred Stock

Debt Instrument [Line Items]

Number of quarterly periods of unpaid dividends after which dividends accrue at penalty rate | period

4

Number of additional directors to be elected after four quarterly periods of unpaid dividends | officer

2

Subsequent Event | Series C Preferred Stock

Debt Instrument [Line Items]

Preferred stock dividend rate percentage increased

12.50%

Subsequent Event | Series D Preferred Stock

Debt Instrument [Line Items]

Preferred stock dividend rate percentage increased

10.00%

Subsequent Event | Series E Preferred Stock

Debt Instrument [Line Items]

Depositary shares interest of a Series E Preferred Stock share

0.001

Preferred stock dividend rate percentage increased

10.00%

Scenario, Forecast | Senior Notes

Debt Instrument [Line Items]

Interest payment due on November 15, 2015

$ 29,300,000

Minimum | Subsequent Event | Sixth Amendment

Debt Instrument [Line Items]

Expected liquidity period after refinancing

30 days

Maximum | Subsequent Event | Sixth Amendment

Debt Instrument [Line Items]

Expected liquidity period after refinancing

45 days

Alpha Hunter Drilling LLC | Note Payable

Debt Instrument [Line Items]

Outstanding borrowings

$ 3,100,000

Eureka Hunter Pipeline Gas Gathering Agreement

Debt Instrument [Line Items]

Oil and gas delivery commitments and contracts, fixed price | $ / MMBTU

0.75

Eureka Hunter Pipeline Gas Gathering Agreement | Subsequent Event

Debt Instrument [Line Items]

Demand notice of performance security (by November 10, 2015)

$ 20,800,000

Triad Hunter | Eureka Hunter Pipeline | Subsequent Event

Debt Instrument [Line Items]

Accounts payable

$ 10,700,000

ACQUISITIONS, DIVESTITURES, A43

ACQUISITIONS, DIVESTITURES, AND DISCONTINUED OPERATIONS (Agreements to Purchase Utica Shale Acreage) (Details) $ in Millions	Jan. 14, 2015USD ($)	Sep. 30, 2015USD ($)a	Sep. 30, 2014USD ($)a	Sep. 30, 2015USD ($)a	Aug. 12, 2013USD ($)a
Utica Shale, Ohio
Discontinued operations
Net mineral acres acquired | a					32,000
Maximum purchase price					$ 142.1
Leasehold Acreage From MNW Energy, LLC
Discontinued operations
Payment to acquire leasehold acres	$ 12
Leasehold Acreage From MNW Energy, LLC | Utica Shale, Ohio
Discontinued operations
Net leasehold acres purchased, to date | a		25,044		25,044
Triad Hunter | Asset purchase agreement with MNW | Utica Shale, Ohio
Discontinued operations
Net acreage of undeveloped leasehold acquired | a		2,665	11,296	2,665
Payment to acquire leasehold acres		$ 12	$ 46.7	$ 103.9

ACQUISITIONS, DIVESTITURES, A44

ACQUISITIONS, DIVESTITURES, AND DISCONTINUED OPERATIONS (Sale of Certain West Virginia Assets) (Details) - Antero Resources Corporation - Triad Hunter - Right, title and interest in undeveloped and unproven leasehold acreage $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2015USD ($)	Sep. 30, 2015USD ($)	Aug. 06, 2015USD ($)	Jun. 18, 2015USD ($)a
Discontinued operations
Consideration received			$ 4.2	$ 33.6
Leasehold acres of properties sold | a				5,210
Gain on sale	$ 5.5	$ 31.7

ACQUISITIONS, DIVESTITURES, A45

ACQUISITIONS, DIVESTITURES, AND DISCONTINUED OPERATIONS (Eureka Hunter Holdings) (Details) - USD ($) $ in Thousands	Mar. 31, 2015	Nov. 18, 2014	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Discontinued operations
Loss from equity method investments			$ (176)	$ (79)	$ (494)	$ (436)
Deconsolidation gain			2,211	$ 0	4,601	$ 0
Basis difference upon deconsolidation			$ 184,682		$ 184,682		$ 201,874
Eureka Hunter Holdings, LLC | Series A-1 Units
Discontinued operations
Equity method investment, ownership percentage			45.53%		45.53%
Eureka Hunter Holdings, LLC | Series A-1 Units | Morgan Stanley Infrastructure (MSI)
Discontinued operations
Payments for Limited Liability Company (LLC) Units		$ 13,300
Eureka Hunter Holdings, LLC | Series A-2 Units | Morgan Stanley Infrastructure (MSI)
Discontinued operations
Equity method investment, ownership percentage			53.00%		53.00%
Eureka Hunter Holdings, LLC | 2015 Growth CapEx Projects Contribution | Series A-2 Units | Morgan Stanley Infrastructure (MSI)
Discontinued operations
Payments for Limited Liability Company (LLC) Units	$ 27,200
Eureka Hunter Holdings, LLC | Additional Contribution | Series A-2 Units | Morgan Stanley Infrastructure (MSI)
Discontinued operations
Payments for Limited Liability Company (LLC) Units	37,800
Eureka Hunter Holdings, LLC | MHR 2015 Make-Up Contribution | Series A-2 Units | Morgan Stanley Infrastructure (MSI)
Discontinued operations
Payments for Limited Liability Company (LLC) Units	$ 18,700
Downward adjustment in LLC units	529,190
Eureka Hunter Holdings, LLC
Discontinued operations
Equity method investment, ownership percentage			44.53%		44.53%		48.60%
Loss from equity method investments			$ 5,222		$ 4,837
Deconsolidation gain			2,200		4,600
Deconsolidation, decrease in equity method basis difference			3,600		7,500
Equity method investments			$ 343,300		$ 343,300		$ 347,200
Eureka Hunter Holdings, LLC | Morgan Stanley Infrastructure (MSI)
Discontinued operations
Equity method investment, ownership percentage			53.98%		53.98%		49.84%
Retained interest upon deconsolidation			$ 347,300		$ 347,300
Eureka Hunter Holdings, LLC | Series A-1 Units
Discontinued operations
Loss from equity method investments			(7,664)		(7,664)
Equity method basis difference reduction			$ 4,000		$ 4,000

ACQUISITIONS, DIVESTITURES, A46

ACQUISITIONS, DIVESTITURES, AND DISCONTINUED OPERATIONS (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Identifiable Assets Basis Amortization And Reduction [Roll Forward]
Ending Basis December 31, 2014			$ 201,874,000
Basis Amortization			(5,658,000)
Basis Reduction			(11,534,000)
Ending Basis September 30, 2015	$ 184,682,000		184,682,000
Magnum Hunter's interest in Eureka Hunter Holdings net loss	(176,000)	$ (79,000)	(494,000)	$ (436,000)
Results reclassified to discontinued operations
Loss from discontinued operations, net of tax	(4,222,000)	(59,590,000)	(8,485,000)	(101,963,000)
Gain on dilution of interest in Eureka Hunter Holdings, LLC, net of tax	2,211,000	0	4,601,000	0
Loss on disposal of discontinued operations, net of tax	0	(258,000)	0	(13,983,000)
Loss from discontinued operations, net of taxes	(2,011,000)	(59,848,000)	(3,884,000)	(115,946,000)
Eureka Hunter Holdings, LLC
Identifiable Assets Basis Amortization And Reduction [Roll Forward]
Operating revenues	22,457,000		53,581,000
Operating income	12,231,000		13,549,000
Net income	11,469,000		10,623,000
Magnum Hunter's interest in Eureka Hunter Holdings net loss	5,222,000		4,837,000
Magnum Hunter's equity in earnings (loss), net	(4,222,000)		(8,485,000)
Assets of discontinued operations					$ 347,200,000
Results reclassified to discontinued operations
Gain on dilution of interest in Eureka Hunter Holdings, LLC, net of tax	2,200,000		4,600,000
Operating cash inflows		28,900,000		67,300,000
Investing cash outflows		(46,700,000)		(111,100,000)
WHI Canada
Results reclassified to discontinued operations
Revenues	0	9,113,000	0	32,073,000
Depreciation, depletion, amortization and accretion	0	(4,224,000)	0	(11,831,000)
Other operating expenses	0	(6,401,000)	0	(23,703,000)
Interest expense	0	(159,000)	0	(6,646,000)
Loss on derivative contracts, net	0	(57,898,000)	0	(91,792,000)
Loss from equity method investments	(4,222,000)	0	(8,485,000)	0
Other expense	0	(21,000)	0	(64,000)
Loss from discontinued operations, net of tax	(4,222,000)	(59,590,000)	(8,485,000)	(101,963,000)
Gain on dilution of interest in Eureka Hunter Holdings, LLC, net of tax	2,211,000	0	4,601,000	0
Loss on disposal of discontinued operations, net of tax	0	(258,000)	0	(13,983,000)
Loss from discontinued operations, net of taxes	(2,011,000)	(59,848,000)	(3,884,000)	(115,946,000)
Loss on disposal of discontinued operation, tax		$ 0		$ 0
Eureka Hunter Holdings, LLC
Identifiable Assets Basis Amortization And Reduction [Roll Forward]
Assets of discontinued operations	343,300,000		343,300,000
Basis Difference Resulting from Deconsolidation | Eureka Hunter Holdings, LLC
Identifiable Assets Basis Amortization And Reduction [Roll Forward]
Basis difference amortization	(1,780,000)		$ (5,658,000)
Minimum
Identifiable Assets Basis Amortization And Reduction [Roll Forward]
Components of basis difference, estimated useful lives amortization period			3 years
Maximum
Identifiable Assets Basis Amortization And Reduction [Roll Forward]
Components of basis difference, estimated useful lives amortization period			39 years
Fixed assets
Identifiable Assets Basis Amortization And Reduction [Roll Forward]
Ending Basis December 31, 2014			$ 5,088,000
Basis Amortization			(187,000)
Basis Reduction			(289,000)
Ending Basis September 30, 2015	4,612,000		4,612,000
Intangible assets
Identifiable Assets Basis Amortization And Reduction [Roll Forward]
Ending Basis December 31, 2014			155,189,000
Basis Amortization			(5,471,000)
Basis Reduction			(8,727,000)
Ending Basis September 30, 2015	140,991,000		140,991,000
Goodwill
Identifiable Assets Basis Amortization And Reduction [Roll Forward]
Ending Basis December 31, 2014			41,597,000
Basis Amortization			0
Basis Reduction			(2,518,000)
Ending Basis September 30, 2015	39,079,000		39,079,000
Series A-1 Units | Eureka Hunter Holdings, LLC
Identifiable Assets Basis Amortization And Reduction [Roll Forward]
Magnum Hunter's interest in Eureka Hunter Holdings net loss	$ (7,664,000)		$ (7,664,000)

OIL & NATURAL GAS SALES (Detail

OIL & NATURAL GAS SALES (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Oil and Gas In Process Activities [Line Items]
Oil and natural gas sales	$ 27,852	$ 62,510	$ 110,661	$ 222,247
Oil
Oil and Gas In Process Activities [Line Items]
Oil and natural gas sales	9,962	34,495	34,593	111,354
Natural gas
Oil and Gas In Process Activities [Line Items]
Oil and natural gas sales	14,532	18,247	59,415	74,031
NGLs
Oil and Gas In Process Activities [Line Items]
Oil and natural gas sales	$ 3,358	$ 9,768	$ 16,653	$ 36,862

PROPERTY, PLANT, & EQUIPMENT (D

PROPERTY, PLANT, & EQUIPMENT (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Mineral interests in properties
Unproved leasehold costs	$ 442,799		$ 442,799		$ 481,643
Proved leasehold costs	276,818		276,818		257,185
Wells and related equipment and facilities	602,258		602,258		606,406
Advances to operators for wells in progress	1,278		1,278		1,411
Total costs	1,323,153		1,323,153		1,346,645
Less accumulated depreciation	(344,006)		(344,006)		(248,410)
Net capitalized costs	979,147		979,147		$ 1,098,235
Impairment of proved oil and gas properties			63,791	$ 39,798
Proved Oil and Natural Gas Properties
Mineral interests in properties
Impairment of proved oil and gas properties	49,800	$ 22,900	63,800	39,800
Depreciation, depletion and amortization	$ 20,800	$ 28,000	$ 95,700	$ 81,900

PROPERTY, PLANT, & EQUIPMENT (E

PROPERTY, PLANT, & EQUIPMENT (Exploration) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Property, Plant and Equipment [Line Items]
Leasehold impairments	$ 3,811	$ 26,921	$ 12,580	$ 51,305
Geological and geophysical	547	363	1,747	1,089
Total exploration expense	4,358	27,284	14,327	52,394
Magnum Hunter Production, Inc.
Property, Plant and Equipment [Line Items]
Leasehold impairments		1,900		3,800
Williston Basin
Property, Plant and Equipment [Line Items]
Leasehold impairments	1,898	17,846	9,504	37,765
Appalachian Basin
Property, Plant and Equipment [Line Items]
Leasehold impairments	1,789	7,150	2,952	9,720
Western Kentucky
Property, Plant and Equipment [Line Items]
Leasehold impairments	0	1,925	0	3,820
South Texas
Property, Plant and Equipment [Line Items]
Leasehold impairments	$ 124	$ 0	$ 124	$ 0

PROPERTY, PLANT, & EQUIPMENT (C

PROPERTY, PLANT, & EQUIPMENT (Capitalized Costs of Oil and Gas Properties) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Property, Plant and Equipment [Line Items]
Capitalized costs, gross	$ 1,323,153		$ 1,323,153		$ 1,346,645
Less accumulated depreciation	(344,006)		(344,006)		(248,410)
Net capitalized costs	979,147		979,147		1,098,235
Gas transportation, gathering and processing equipment and other
Property, Plant and Equipment [Line Items]
Capitalized costs, gross	102,959		102,959		100,436
Less accumulated depreciation	(28,542)		(28,542)		(23,013)
Net capitalized costs	74,417		74,417		$ 77,423
Depreciation, depletion and amortization	$ 1,900	$ 2,700	$ 5,800	$ 5,800

ASSET RETIREMENT OBLIGATIONS (D

ASSET RETIREMENT OBLIGATIONS (Details) - USD ($) $ in Thousands		9 Months Ended	12 Months Ended
		Sep. 30, 2015	Dec. 31, 2014
Summary of asset retirement obligation
Asset retirement obligations at beginning of period		$ 26,524	$ 16,216
Liabilities incurred		40	218
Liabilities settled		(136)	(107)
Liabilities sold		(74)	(2,598)
Accretion expense		1,928	1,478
Revisions in estimated liabilities	[1]	(596)	3,208
Reclassified from liabilities associated with assets of MHP		0	8,109
Asset retirement obligation at end of period		27,686	26,524
Less: current portion (included in other liabilities)		(1,235)	(295)
Asset retirement obligations, net of current portion		$ 26,451	$ 26,229
[1]	Revisions in estimated liabilities during 2014 relate to a change in assumptions used with respect to certain wells in the Appalachian Basin in Ohio and West Virginia.

FAIR VALUE OF FINANCIAL INSTR52

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) - USD ($) $ / shares in Units, $ in Thousands	9 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Fair value measurements on a Recurring Basis
Available for sale securities	$ 968	$ 3,864
Recurring | Level 1
Fair value measurements on a Recurring Basis
Available for sale securities	968	3,864
Total assets at fair value	968	3,864
Total liabilities at fair value	0
Recurring | Level 1 | Convertible security derivative assets
Fair value measurements on a Recurring Basis
Derivative assets	0	0
Recurring | Level 1 | Commodity derivative assets
Fair value measurements on a Recurring Basis
Derivative assets	0	0
Derivative liabilities	0
Recurring | Level 2
Fair value measurements on a Recurring Basis
Available for sale securities	0	0
Total assets at fair value	1,051	16,511
Total liabilities at fair value	569
Recurring | Level 2 | Convertible security derivative assets
Fair value measurements on a Recurring Basis
Derivative assets	0	0
Recurring | Level 2 | Commodity derivative assets
Fair value measurements on a Recurring Basis
Derivative assets	1,051	16,511
Derivative liabilities	569
Recurring | Level 3
Fair value measurements on a Recurring Basis
Available for sale securities	0	0
Total assets at fair value	3	75
Total liabilities at fair value	$ 0
Recurring | Level 3 | Convertible security derivative assets
Assumptions and methodology used for calculating fair value of assets and liabilities
Life (in years)	1 year 5 months
Risk-free interest rate	0.60%
Estimated volatility	92.00%
Dividend	0.00%
GreenHunter stock price at end of period	$ 0.30
Fair value measurements on a Recurring Basis
Derivative assets	$ 3	75
Recurring | Level 3 | Commodity derivative assets
Fair value measurements on a Recurring Basis
Derivative assets	0	$ 0
Derivative liabilities	$ 0

FAIR VALUE OF FINANCIAL INSTR53

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 2) - Embedded Derivatives, Assets - Level 3 - Convertible Security Embedded Derivative Financial Instruments [Member] $ in Thousands	9 Months Ended
	Sep. 30, 2015USD ($)
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]
Fair value as of December 31, 2014	$ 75
Decrease in fair value recognized in gain (loss) on derivative contracts, net	(72)
September 30, 2015	$ 3

FAIR VALUE OF FINANCIAL INSTR54

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 4) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Level 2 | Carrying Amount | Senior Notes
Carrying amounts and fair values of long-term debt
Fair value of senior notes	$ 597,521	$ 597,355
Level 2 | Estimated Fair Value | Senior Notes
Carrying amounts and fair values of long-term debt
Fair value of senior notes	275,700	498,000
Level 3 | Carrying Amount | MHR Senior Revolving Credit Facility
Carrying amounts and fair values of long-term debt
Fair value of senior notes	5,000	0
Level 3 | Carrying Amount | MHR Second Lien Term Loan
Carrying amounts and fair values of long-term debt
Fair value of senior notes	327,469	329,140
Level 3 | Carrying Amount | Equipment Notes Payable
Carrying amounts and fair values of long-term debt
Fair value of senior notes	17,990	22,238
Level 3 | Estimated Fair Value | MHR Senior Revolving Credit Facility
Carrying amounts and fair values of long-term debt
Fair value of senior notes	5,000	0
Level 3 | Estimated Fair Value | MHR Second Lien Term Loan
Carrying amounts and fair values of long-term debt
Fair value of senior notes	319,873	329,140
Level 3 | Estimated Fair Value | Equipment Notes Payable
Carrying amounts and fair values of long-term debt
Fair value of senior notes	$ 17,990	$ 22,150

FAIR VALUE OF FINANCIAL INSTR55

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 5) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Mar. 31, 2014	Sep. 30, 2015	Sep. 30, 2014
Fair Value of Financial Instruments
Impairment of proved oil and gas properties	$ 49,842	$ 22,886		$ 63,791	$ 39,798
Leasehold impairments	3,811	26,921		12,580	51,305
Fair Value, Measurements, Nonrecurring [Member] | Level 3
Fair Value of Financial Instruments
Fair value proved oil and gas properties	$ 511,200			$ 511,200
Oil and Gas Properties
Fair Value of Financial Instruments
Discount rate				10.00%
Magnum Hunter Production, Inc.
Fair Value of Financial Instruments
Impairment of proved oil and gas properties		17,000	$ 16,754
Leasehold impairments		1,900			3,800
Magnum Hunter Production, Inc. | Fair Value, Measurements, Nonrecurring [Member] | Level 3
Fair Value of Financial Instruments
Long-lived assets		$ 52,600	$ 60,000		$ 52,600

INVESTMENTS AND DERIVATIVES (In

INVESTMENTS AND DERIVATIVES (Investment Holdings) (Details) AUD in Millions		Oct. 20, 2015USD ($)	Oct. 20, 2015AUD	Sep. 30, 2015USD ($)issuer	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)issuer	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)
Noncontrolling Interest [Line Items]
Number of issuers with business activities in oil and natural gas or mineral mining | issuer				3		3
Amounts reclassified for other than temporary impairment of available for sale securities				$ 2,115,000	$ 0	$ 11,107,000	$ 0
Changes In Investments [Roll Forward]
Available-for-sale Securities, beginning of period						3,864,000
Loss from equity method investments				(176,000)	$ (79,000)	(494,000)	$ (436,000)
Change in fair value recognized in other comprehensive loss						(2,402,000)
Available-for-sale Securities, end of period				968,000		968,000
Redstar Gold Corp
Noncontrolling Interest [Line Items]
Amounts reclassified for other than temporary impairment of available for sale securities						400,000
Green Hunter Energy
Noncontrolling Interest [Line Items]
Equity method investments				0		0		$ 0
Common stock, value, outstanding				$ 500,000		500,000		$ 1,300,000
Available for Sale Securities
Changes In Investments [Roll Forward]
Loss from equity method investments	[1]					(494,000)
Other Expense
Noncontrolling Interest [Line Items]
Amounts reclassified for other than temporary impairment of available for sale securities						$ 8,993,000
New Standard Energy Limited | Subsequent Event | New Standard Energy Limited
Noncontrolling Interest [Line Items]
Proceeds from sale of available-for-sale securities		$ 500,000	AUD 0.7
Gain on sale of securities		$ 100,000
[1]	(1) As a result of the carrying value of the Company's investment in common stock of GreenHunter being reduced to zero from equity method losses, the Company is required to allocate any additional losses to its investment in the Series C preferred stock of GreenHunter. The Company recorded additional equity method loss against the carrying value of its investment in the Series C preferred stock of GreenHunter before recording any mark-to-market adjustments.

INVESTMENTS AND DERIVATIVES (Fa

INVESTMENTS AND DERIVATIVES (Fair Value) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Equity Securities, Amortized Cost	$ 532	$ 9,876
Equity Securities, Gross Unrealized Loss	0	(7,323)
Equity Securities	532	2,553
Equity Securities, Related Party, Amortized Cost Basis	436	2,200
Equity Securities, Related Party, Gross Unrealized Loss	0	(889)
Equity Securities, Related Party	436	1,311
Equity Securities, Including Related Party, Amortized Cost Basis	968	12,076
Equity Securities, Including Related Party, Gross Unrealized Loss	0	(8,212)
Equity Securities, Including Related Party	$ 968	$ 3,864

INVESTMENTS AND DERIVATIVES (Co

INVESTMENTS AND DERIVATIVES (Commodity Derivatives) (Details) $ in Thousands	Nov. 02, 2015USD ($)	Sep. 30, 2015USD ($)MMBTU$ / MMBTU$ / bblbbl	May. 07, 2015USD ($)	Dec. 31, 2014USD ($)
Derivative [Line Items]
Outstanding borrowings		$ 947,980		$ 948,733
Revolving Credit Facility | Line of Credit | Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018
Derivative [Line Items]
Proceeds from termination of commodity derivative positions expected			$ 11,800
Outstanding borrowings		$ 5,000
Natural gas | Aug 2015 - Dec 2015 | Collars
Derivative [Line Items]
MMBtu/day | MMBTU		80,000
Crude Oil | Aug 2015 - Dec 2015 | Collars
Derivative [Line Items]
Bbl/day | bbl		1,500
Crude Oil | Jan 2015 - Dec 2015 | Ceilings sold (call)
Derivative [Line Items]
Bbl/day | bbl		1,570
Price per Bbl | $ / bbl		120
Crude Oil | Jan 2015 - Dec 2015 | Floors sold (put)
Derivative [Line Items]
Bbl/day | bbl		259
Price per Bbl | $ / bbl		70
Minimum | Natural gas | Aug 2015 - Dec 2015 | Collars
Derivative [Line Items]
Price per Bbl | $ / MMBTU		2.66
Minimum | Crude Oil | Aug 2015 - Dec 2015 | Collars
Derivative [Line Items]
Price per Bbl | $ / bbl		45
Maximum | Natural gas | Aug 2015 - Dec 2015 | Collars
Derivative [Line Items]
Price per Bbl | $ / MMBTU		3.15
Maximum | Crude Oil | Aug 2015 - Dec 2015 | Collars
Derivative [Line Items]
Price per Bbl | $ / bbl		48
Bank Of Montreal | Commodity | Subsequent Event
Derivative [Line Items]
Proceeds from termination of open commodity derivative positions	$ 900

INVESTMENTS AND DERIVATIVES (59

INVESTMENTS AND DERIVATIVES (Commodity and Financial Derivative Contracts) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value
Derivative Assets	$ 1,054	$ 16,586
Derivative Liabilities	569	0
Commodity
Derivatives, Fair Value
Derivative Assets	1,051	16,511
Derivative Liabilities	569	0
Financial
Derivatives, Fair Value
Derivative Assets	3	75
Derivative Liabilities	0	0
Derivative assets | Commodity
Derivatives, Fair Value
Derivative Assets	1,051	16,511
Derivative assets | Financial
Derivatives, Fair Value
Derivative Assets	3	75
Derivative liabilities | Commodity
Derivatives, Fair Value
Derivative Liabilities	$ 569	$ 0

INVESTMENTS AND DERIVATIVES (Ef

INVESTMENTS AND DERIVATIVES (Effect of Master Netting) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Derivative [Line Items]
Derivative Asset, Fair Value, Amount Offset Against Collateral	$ (569)	$ 0
Gross Amounts of Recognized Assets and Liabilities	482	16,511
Gross Amounts Offset on the Consolidated Balance Sheet	0	0
Net Amount	482	16,511
Current Assets
Derivative [Line Items]
Derivative asset, fair value, gross asset including not subject to master netting arrangement	1,051	18,146
Derivative Asset, Fair Value, Amount Offset Against Collateral	0	(1,635)
Derivative assets	1,051	16,511
Current Liabilities
Derivative [Line Items]
Derivative liability, fair value, gross liability including not subject to master netting arrangement	(569)	(1,635)
Derivative Liability, Fair Value, Amount Offset Against Collateral	0	1,635
Derivative Liability	$ (569)	$ 0

INVESTMENTS AND DERIVATIVES (Ne

INVESTMENTS AND DERIVATIVES (Net Gain (Loss)) (Details) - Commodity derivative assets - Other Income (Expense) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Summary of net gain (loss) on derivative contracts
Gain (loss) on derivative contracts	$ 568	$ 8,262	$ 3,345	$ (333)
Settled Transaction
Summary of net gain (loss) on derivative contracts
Gain (loss) on derivative contracts	(380)	477	2,814	(4,074)
Open Transaction
Summary of net gain (loss) on derivative contracts
Gain (loss) on derivative contracts	$ 948	$ 7,785	$ 531	$ 3,741

DEBT (Details)

DEBT (Details) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2012	Dec. 31, 2014
Debt Instrument [Line Items]
Total long-term debt, outstanding	$ 947,980		$ 948,733
Less: current portion	(939,680)		(10,770)
Total long-term debt obligations, net of current portion	8,300		937,963
MHR second lien term loan due on demand as of October 8, 2015, original maturity of October 22, 2019, interest rate of 8.5%, net of unamortized discount of $9.1 million and $10.0 million at September 30, 2015 and December 31, 2014, respectively
Debt Instrument [Line Items]
Long-term debt, unamortized discount	9,100		10,000
Senior Notes | Senior Notes payable due May 15, 2020, interest rate of 9.75%, net of unamortized net discount of $2.5 million and $2.6 million at September 30, 2015 and December 31, 2014, respectively
Debt Instrument [Line Items]
Total long-term debt, outstanding	$ 597,521		$ 597,355
Long-term debt, stated interest rate	9.75%		9.75%
Long-term debt, unamortized discount	$ 2,500		$ 2,600
Note Payable | Various equipment and real estate notes payable with maturity dates February 2015 - November 2017, interest rates of 4.25% - 7.94%
Debt Instrument [Line Items]
Total long-term debt, outstanding	$ 17,990		22,238
Note Payable | Notes Payable Due January 2015 - April 2021
Debt Instrument [Line Items]
Long-term debt, stated interest rate, minimum	4.25%	4.25%
Long-term debt, stated interest rate, maximum	7.94%	7.94%
Line of Credit | MHR Senior Revolving Credit Facility | MHR Senior Revolving Credit Facility
Debt Instrument [Line Items]
Total long-term debt, outstanding	$ 5,000		$ 0
Line of Credit | MHR Senior Revolving Credit Facility | 2.96 and 3.56 Percent Revolving Credit Facility due April 2016 and December 2013
Debt Instrument [Line Items]
Long-term debt, stated interest rate	4.21%		2.92%
Term Loan | MHR second lien term loan due on demand as of October 8, 2015, original maturity of October 22, 2019, interest rate of 8.5%, net of unamortized discount of $9.1 million and $10.0 million at September 30, 2015 and December 31, 2014, respectively
Debt Instrument [Line Items]
Total long-term debt, outstanding	$ 327,469		$ 329,140
Long-term debt, stated interest rate	8.50%		8.50%
Senior Notes and Term Loans | Senior Notes payable due May 15, 2020, interest rate of 9.75%, net of unamortized net discount of $2.5 million and $2.6 million at September 30, 2015 and December 31, 2014, respectively
Debt Instrument [Line Items]
Long-term debt, unamortized discount	$ 11,600

DEBT (Expected Annual Maturitie

DEBT (Expected Annual Maturities of Debt) (Details) $ in Thousands	Sep. 30, 2015USD ($)
Debt Disclosure [Abstract]
2,015	$ 946,533
2,016	8,226
2,017	1,240
2,018	558
2,019	207
Thereafter	2,826
Total long-term debt, outstanding	$ 959,590

DEBT (MHR Senior Revolving Cred

DEBT (MHR Senior Revolving Credit Facility) (Details)	Nov. 02, 2015USD ($)	Sep. 08, 2015	Apr. 17, 2015	Oct. 22, 2014USD ($)	Sep. 30, 2015USD ($)	Mar. 31, 2015	Sep. 30, 2015USD ($)	Nov. 03, 2015USD ($)	Aug. 07, 2015USD ($)	May. 01, 2015USD ($)	Dec. 31, 2014USD ($)
Debt Instrument [Line Items]
Accounts payable, net (in excess of 180 days outstanding)									$ 1,400,000
Outstanding borrowings					$ 947,980,000		$ 947,980,000				$ 948,733,000
Line of Credit | Term Loan | Second Lien Amendment
Debt Instrument [Line Items]
Number of days accounts payable outstanding		180 days	180 days				90 days
Number of days to cure technical default		30 days
Line of Credit | MHR Senior Revolving Credit Facility | Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018
Debt Instrument [Line Items]
Borrowing base					50,000,000		$ 50,000,000			$ 50,000,000
Outstanding borrowings					5,000,000		5,000,000
Borrowing capacity					$ 6,000,000		$ 6,000,000
Line of Credit | MHR Senior Revolving Credit Facility | Third Amendment
Debt Instrument [Line Items]
Number of days accounts payable outstanding							90 days
Line of Credit | MHR Senior Revolving Credit Facility | Fourth Amendment
Debt Instrument [Line Items]
Number of days accounts payable outstanding							90 days
Line of Credit | MHR Senior Revolving Credit Facility | First Amendment
Debt Instrument [Line Items]
Maximum allowable investments in oil and gas properties											2,000,000
Allowed maximum investments in subsidiary											2,000,000
Threshold for liquidity event, arms length transaction											36,000,000
Threshold for liquidity event, cash proceeds receivable by company or restricted subsidiary											73,000,000
Liquidity event not met, increase in variable rate					1.00%		1.00%
Liquidity event not met, increase in commitment fee					0.25%		0.25%
Line of Credit | MHR Senior Revolving Credit Facility | Second Amendment
Debt Instrument [Line Items]
Number of days accounts payable outstanding							90 days
Line of Credit | MHR Senior Revolving Credit Facility | Fifth Amendment
Debt Instrument [Line Items]
Number of days accounts payable outstanding							90 days
Line of Credit | Letter of Credit | Senior Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit outstanding					$ 39,000,000		$ 39,000,000
Fiscal Quarter Ending December 31, 2014 | Line of Credit | Term Loan | Second Lien Term Loan Agreement
Debt Instrument [Line Items]
Ratio of present value of proved reserves to secured debt, period of strip pricing				5 years
Proved Reserves to secured debt ratio (not less than 1.5 to 1.0)				1.5
Proved developed and producing reserves to secured debt ratio (not less than 1.0 to 1.0)				1
Credit Agreement Amendment Period April 17, 2015 Through May 29, 2015 | Line of Credit | MHR Senior Revolving Credit Facility | First Amendment
Debt Instrument [Line Items]
Interest rate margin increase							25.00%
Credit Agreement Amendment Period April 17, 2015 Through May 29, 2015 | Line of Credit | MHR Senior Revolving Credit Facility | Second Amendment
Debt Instrument [Line Items]
Number of days accounts payable outstanding							180 days
Aggregate net cash proceeds, threshold for preferred stock dividend payment					$ 65,000,000		$ 65,000,000
Credit Agreement Amendment Period July 10, 2015 Through December 31, 2015 | Line of Credit | MHR Senior Revolving Credit Facility | Fifth Amendment
Debt Instrument [Line Items]
Number of days accounts payable outstanding							180 days
Number of days to cure technical default							30 days
Credit Agreement Amendment Period May 28, 2015 Through June 19, 2015 | Line of Credit | MHR Senior Revolving Credit Facility | Third Amendment
Debt Instrument [Line Items]
Number of days accounts payable outstanding							180 days
Credit Agreement Amendment Period June 19, 2015 Through July 10, 2015 | Line of Credit | MHR Senior Revolving Credit Facility | Fourth Amendment
Debt Instrument [Line Items]
Number of days accounts payable outstanding							180 days
Fiscal Quarter Ending March 31, 2015 | Line of Credit | MHR Senior Revolving Credit Facility | First Amendment
Debt Instrument [Line Items]
Current ratio						0.75
Fiscal Quarter Ending September 30, 2015 | Line of Credit | MHR Senior Revolving Credit Facility | First Amendment
Debt Instrument [Line Items]
Required maximum secured Net Debt to EBITDAX ratio						2.5
Fiscal Quarter Ending June 30, 2015 And Each Fiscal Quarter Thereafter | Line of Credit | MHR Senior Revolving Credit Facility | First Amendment
Debt Instrument [Line Items]
Current ratio					1
Fiscal Quarter Ending March 31, 2016 And Any Fiscal Quarter Trailing Four-Quarter Period Then Ended | Line of Credit | Term Loan | Second Lien Term Loan Agreement
Debt Instrument [Line Items]
Leverage ratio limitation on netting of unencumbered cash				$ 100,000,000
Required maximum secured Net Debt to EBITDAX ratio				2.5
Fiscal Quarter Ending March 31, 2016 And Any Fiscal Quarter Trailing Four-Quarter Period Then Ended | Line of Credit | MHR Senior Revolving Credit Facility | Fourth Amended And Restated Credit Agreement, Maturing October 22, 2018
Debt Instrument [Line Items]
Required maximum secured Net Debt to EBITDAX ratio					2
Alpha Hunter Drilling LLC | Note Payable
Debt Instrument [Line Items]
Outstanding borrowings					$ 3,100,000		$ 3,100,000
Current Assets
Debt Instrument [Line Items]
Derivative asset, fair value, gross asset including not subject to master netting arrangement					1,051,000		1,051,000				18,146,000
Current Liabilities
Debt Instrument [Line Items]
Derivative liability, fair value, gross liability including not subject to master netting arrangement					$ 569,000		$ 569,000				$ 1,635,000
Subsequent Event | Sixth Amendment
Debt Instrument [Line Items]
Refinancing requirements, weekly budget period	45 days
Subsequent Event | Term Loan | Sixth Amendment
Debt Instrument [Line Items]
Borrowing base								$ 16,000,000
Amount outstanding								5,000,000
Subsequent Event | Senior Secured Term Loan Facility | Sixth Amendment
Debt Instrument [Line Items]
Borrowing base								60,000,000
Incremental borrowing capacity								10,000,000
Subsequent Event | Letter of Credit | Sixth Amendment
Debt Instrument [Line Items]
Collateral amount of outstanding debt								$ 39,000,000
London Interbank Offered Rate (LIBOR) | Subsequent Event | Sixth Amendment
Debt Instrument [Line Items]
Basis spread on variable rate	4.00%
Prime Rate | Subsequent Event | Sixth Amendment
Debt Instrument [Line Items]
Basis spread on variable rate	3.00%
Bank Of Montreal | Commodity | Subsequent Event
Debt Instrument [Line Items]
Proceeds from termination of open commodity derivative positions	$ 900,000

DEBT (Eureka Hunter Pipeline Cr

DEBT (Eureka Hunter Pipeline Credit Agreement) (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Outstanding borrowings	$ 947,980	$ 948,733

DEBT (Senior Notes and Note Pay

DEBT (Senior Notes and Note Payable) (Details) - USD ($)	9 Months Ended
	Sep. 30, 2015	Nov. 15, 2015	Nov. 03, 2015	Dec. 31, 2014	Dec. 18, 2012	May. 16, 2012
Debt Instrument [Line Items]
Outstanding borrowings	$ 947,980,000			$ 948,733,000
Senior Notes
Debt Instrument [Line Items]
Interest payable, current	$ 22,100,000
Period interest to be paid before event of default	30 days
Senior Notes | 9.75 Percent Senior Notes Due May 15, 2020
Debt Instrument [Line Items]
Principal amount					$ 150,000,000	$ 450,000,000
Number of business days after grace period obligations are repaid	10 days
Threshold aggregate principal amount held to declare balance due and payable immediately, percent	25.00%
Outstanding borrowings	$ 597,521,000			$ 597,355,000
Long-term debt, stated interest rate	9.75%			9.75%
Alpha Hunter Drilling LLC | Note Payable
Debt Instrument [Line Items]
Outstanding borrowings	$ 3,100,000
Claim threshold in the event of default to accelerate financial obligation	$ 1,000,000
Interest rate until principal fully repaid	18.00%
Scenario, Forecast | Senior Notes
Debt Instrument [Line Items]
Interest payment due on November 15, 2015		$ 29,300,000
Subsequent Event | Term Loan | Forbearance Agreement
Debt Instrument [Line Items]
Borrowing base			$ 70,000,000

DEBT (Interest Expense) (Detail

DEBT (Interest Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Debt Instrument [Line Items]
Interest expense incurred on debt, net of amounts capitalized	$ 23,136	$ 16,937	$ 69,056	$ 50,021
Amortization and write-off of deferred financing costs	1,895	999	3,542	5,806
Total interest expense	$ 25,031	$ 17,936	72,598	55,827
Fifth Amendment
Debt Instrument [Line Items]
Write off of unamortized deferred financing costs			$ 1,100
Amendment to Third Amended and Restated Credit Agreement [Member]
Debt Instrument [Line Items]
Write off of unamortized deferred financing costs				$ 1,700

SHARE-BASED COMPENSATION (Detai

SHARE-BASED COMPENSATION (Details) - USD ($) $ / shares in Units, $ in Thousands	Sep. 01, 2015	Jun. 18, 2015	Mar. 30, 2015	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Share Based Compensation
Share-based compensation expense				$ 1,400	$ 2,300	$ 6,500	$ 5,700
Additional disclosures
Share based compensation						$ 6,492
Stock options and stock appreciation rights
Shares
Outstanding at beginning of period (in shares)						13,195,000	16,891,000
Granted (in shares)						0	0
Exercised (in shares)						(100,000)	(2,355,000)
Forfeited (in shares)						(3,002,000)	(1,241,000)
Outstanding at end of period (in shares)				10,093,000	13,295,000	10,093,000	13,295,000
Exercisable at end of period (in shares)				7,953,000	9,179,000	7,953,000	9,179,000
Weighted Average Exercise Price
Outstanding at beginning of period (in dollars per share)						$ 5.92	$ 5.69
Granted (in dollars per share)						0	0
Exercised (in dollars per share)						0.51	4.09
Forfeited (in dollars per share)						6.30	6.28
Outstanding at end of period (in dollars per share)				$ 5.86	$ 5.91	5.86	5.91
Exercisable at end of period (in dollars per share)				$ 5.95	$ 6.22	$ 5.95	$ 6.22
Non-vested Shares
Non-vested at beginning of period (in shares)						4,055,000	6,908,000
Granted (in shares)						0	0
Vested (in shares)						(1,637,000)	(1,916,000)
Forfeited (in shares)						(278,000)	(876,000)
Non-vested at end of period (in shares)				2,140,000	4,116,000	2,140,000	4,116,000
Additional disclosures
Unrecognized compensation cost				$ 600	$ 4,700	$ 600	$ 4,700
Weighted average period for recognition of compensation cost						4 months 21 days
Remaining contractual term						4 years 3 months 4 days
Restricted stock
Additional disclosures
Unrecognized compensation cost				$ 6,400	$ 7,100	$ 6,400	$ 7,100
Weighted average period for recognition of compensation cost						2 years 2 months 1 day
Grants in period						205,000
Estimated future forfeiture rate						5.60%
Award vesting period						3 years
Grant date fair value						$ 300
Officers executives and employees | Common Stock
Additional disclosures
Grants in period			535,274
Board of directors
Additional disclosures
Share based compensation			$ 1,400
Board Of Directors, Non Employee Members | Restricted stock
Additional disclosures
Grants in period		600,000
Share based compensation		$ 700
Estimated future forfeiture rate		5.60%
Award vesting period		2 years
Award vesting period upon change in control of the Company		6 months
Newly Hired Officer | Restricted stock
Additional disclosures
Grants in period	2,000,000
Share based compensation	$ 1,500
Estimated future forfeiture rate	5.60%
Amended And Restated Stock Incentive Plan
Share Based Compensation
Options, outstanding, number				10,093,000		10,093,000
Options, unvested, number of shares				7,953,000		7,953,000
Amended And Restated Stock Incentive Plan | Common Stock
Share Based Compensation
Number of shares authorized under the plan				27,500,000		27,500,000
Number of shares issued under the plan				12,753,463		12,753,463
Common stock shares unvested, number				4,156,772		4,156,772

SHAREHOLDERS_ EQUITY (Details)

SHAREHOLDERS’ EQUITY (Details)	Oct. 08, 2015	Aug. 06, 2015shares	Oct. 31, 2015periodofficer	Sep. 30, 2015USD ($)shares	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)shares	Sep. 30, 2014USD ($)shares	Mar. 13, 2015USD ($)	Dec. 31, 2014shares
Class of Stock [Line Items]
Shares issued in connection with share-based compensation | shares						1,255,225
Common stock, shares issued | shares				261,269,008		261,269,008			201,420,701
Net proceeds from sales of common shares						$ 58,239,000	$ 178,432,000
Shares issued as safe harbor and discretionary matching contribution to 401(k) plan | shares		2,290,565
Preferred stock dividends				$ 8,848,000	$ 8,848,000	26,543,000	26,516,000
Series C Preferred Stock
Class of Stock [Line Items]
Preferred stock dividends				2,562,000	2,562,000	7,686,000	7,686,000
Series D Preferred Stock
Class of Stock [Line Items]
Preferred stock dividends				4,424,000	4,424,000	13,273,000	13,273,000
Series E Preferred Stock
Class of Stock [Line Items]
Preferred stock dividends				$ 1,862,000	1,862,000	$ 5,584,000	$ 5,557,000
Dilutive
Class of Stock [Line Items]
Potentially dilutive securities outstanding (shares) | shares						44,369,000	44,900,000
Series E Preferred Stock | Dilutive
Class of Stock [Line Items]
Potentially dilutive securities outstanding (shares) | shares						10,946,000	10,946,000
Warrant | Dilutive
Class of Stock [Line Items]
Potentially dilutive securities outstanding (shares) | shares						19,173,000	19,214,000
Unvested restricted shares | Dilutive
Class of Stock [Line Items]
Potentially dilutive securities outstanding (shares) | shares						4,157,000	1,445,000
Common stock options and stock appreciation rights | Dilutive
Class of Stock [Line Items]
Potentially dilutive securities outstanding (shares) | shares						10,093,000	13,295,000
Universal Shelf Registration Statement Form S3
Class of Stock [Line Items]
Shelf registration maximum offering								$ 500,000,000
Common stock, shares issued | shares				56,202,517		56,202,517
Net proceeds from sales of common shares						$ 58,200,000
Sales commissions						1,300,000
Eureka Hunter Holdings, LLC
Class of Stock [Line Items]
Accretion of the carrying value of the Eureka Hunter Holdings Series A Preferred Units				$ 0	2,306,000	0	$ 6,583,000
Total dividends on Preferred Stock of discontinued operations				0	6,644,000	0	19,202,000
Eureka Hunter Holdings, LLC | Class A Preferred Units
Class of Stock [Line Items]
Preferred stock dividends				$ 0	$ 4,338,000	$ 0	$ 12,619,000
Subsequent Event | Series C, Series D and Series E Preferred Stock
Class of Stock [Line Items]
Number of quarterly periods of unpaid dividends after which dividends accrue at penalty rate | period			4
Number of additional directors to be elected after four quarterly periods of unpaid dividends | officer			2
Subsequent Event | Series C Preferred Stock
Class of Stock [Line Items]
Preferred stock dividend rate percentage increased			12.50%
Subsequent Event | Series D Preferred Stock
Class of Stock [Line Items]
Preferred stock dividend rate percentage increased			10.00%
Subsequent Event | Series E Preferred Stock
Class of Stock [Line Items]
Depositary shares interest of a Series E Preferred Stock share	0.001
Preferred stock dividend rate percentage increased			10.00%
Senior Notes | Subsequent Event
Class of Stock [Line Items]
Number of consecutive quarters dividend fully paid at increased annual dividend rates | period			2

REDEEMABLE PREFERRED STOCK (Det

REDEEMABLE PREFERRED STOCK (Details) $ in Millions	Sep. 16, 2014USD ($)
Series A Preferred Units | Eureka Hunter Holdings, LLC
Class of Stock [Line Items]
Preferred units sold to Ridgeline	$ 200

RELATED PARTY TRANSACTIONS (Bal

RELATED PARTY TRANSACTIONS (Balances) (Details) - USD ($)		Sep. 30, 2015	Dec. 31, 2014
GreenHunter Resources, Inc.
Related Party Transaction
Accounts payable - net	[1]	$ (783,000)	$ (224,000)
Derivative assets	[1],[2]	3,000	75,000
Investments	[1],[2]	436,000	1,311,000
Notes receivable	[1],[2]	816,000	1,224,000
Prepaid expense	[1]	5,000	1,000,000
Eureka Hunter Holdings, LLC
Related Party Transaction
Accounts receivable (payable) - net	[3]	(10,405,000)	122,000
Equity method investments	[3]	343,307,000	347,191,000
Pilatus Hunter
Related Party Transaction
Accounts receivable (payable) - net	[4]	12,000	12,000
Classic Petroleum, Inc.
Related Party Transaction
Accounts payable - net	[5]	(51,000)	0
Kirk Trosclair Enterprises, LLC
Related Party Transaction
Accounts payable - net	[6]	$ (7,000)	$ 0
Common Stock | GreenHunter Resources, Inc.
Related Party Transaction
Investment in related parties, shares		1,846,722
Investment in related parties, carrying value		$ 0
Series C Preferred Stock | GreenHunter Resources, Inc.
Related Party Transaction
Investment in related parties, shares		88,000
Investment in related parties, carrying value		$ 400,000
[1]	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman and a major shareholder. Triad Hunter and Viking International Resources Co., Inc., wholly owned subsidiaries of the Company, receive services related to brine water and rental equipment from GreenHunter and certain affiliated companies. The Company believes that such services were and are provided at competitive market rates and were and are comparable to, or more attractive than, rates that could be obtained from unaffiliated third party suppliers of such services.
[2]	On February 17, 2012, the Company sold its wholly owned subsidiary, Hunter Disposal, to GreenHunter Water, LLC ("GreenHunter Water"), a wholly owned subsidiary of GreenHunter. The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note it received as partial consideration for the sale. See "Note 7 - Fair Value of Financial Instruments" for additional information. The Company has recorded interest income as a result of the note receivable from GreenHunter. Also as a result of this transaction, the Company has an equity method investment in GreenHunter that is included in derivatives and investment in affiliates - equity method and an available for sale investment in GreenHunter included in investments. Miscellaneous income (expense) includes other than temporary impairment loss on the GreenHunter available for sale security of $1.8 million for the three and nine months ended September 2015. See "Note 8 - Investments and Derivatives" for additional information.
[3]	Following a series of transactions up to and including, December 18, 2014, the Company no longer held a controlling financial interest in Eureka Hunter Holdings. The Company deconsolidated Eureka Hunter Holdings and accounts for its retained interest as of December 31, 2014 under the equity method of accounting. As discussed in "Note 3 - Acquisitions, Divestitures, and Discontinued Operations", in June 2015 the Company adopted a plan to dispose of its equity method investment in Eureka Hunter Holdings, and has classified the related operations as discontinued operations and the investment as assets of discontinued operations for all periods presented.
[4]	The Company rented an airplane for business use for certain members of Company management at various times from Pilatus Hunter, LLC, an entity 100% owned by Mr. Evans. Airplane rental expenses are recorded in general and administrative expense.
[5]	Classic Petroleum, Inc. is an entity owned by the brother of James W. Denny, III, the Company's former Executive Vice President and President of the Company's Appalachian Division. Triad Hunter received land brokerage services from Classic Petroleum, Inc., including courthouse abstracting, contract negotiations, GIS mapping and leasing services.
[6]	On July 18, 2014, the Company entered into a consulting agreement with Kirk J. Trosclair, a former executive of Alpha Hunter Drilling, LLC, a wholly owned subsidiary of the Company. Mr. Trosclair ceased employment with the Company on July 18, 2014 and is currently the Chief Operating Officer of GreenHunter. The agreement has a term of 12 months and provides that Mr. Trosclair will receive monthly compensation of $10,000, and Mr. Trosclair is eligible to continue vesting in previously granted stock options and unvested restricted stock awards, subject to continued service under the consulting agreement. In connection with this agreement, for the nine months ended September 30, 2015, the Company paid Mr. Trosclair $141,000, which includes reimbursement of expenses incurred on behalf of the Company, and recognized $161,888 in stock compensation expense.

RELATED PARTY TRANSACTIONS (Det

RELATED PARTY TRANSACTIONS (Details)		May. 04, 2015USD ($)	Dec. 29, 2014USD ($)	Sep. 15, 2014USD ($)	Jul. 18, 2014USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)shares	Sep. 30, 2014USD ($)	Nov. 05, 2015USD ($)	Oct. 31, 2015USD ($)	Mar. 31, 2015USD ($)	Oct. 03, 2014$ / MMBTU
Related Party Transaction
Amounts reclassified for other than temporary impairment of available for sale securities						$ 2,115,000	$ 0	$ 11,107,000	$ 0
Loss from equity method investment						176,000	79,000	494,000	436,000
Consulting agreement, term					12 months
Share-based compensation								8,059,000	7,267,000
GreenHunter Resources, Inc.
Related Party Transaction
Interest income	[1]					23,000	38,000	94,000	121,000
Loss from equity method investment	[1]					176,000	79,000	494,000	436,000
Capitalized Costs Incurred, Disposal Costs	[2]					5,000	0	$ 470,000	0
Rental agreement term								5 years
Rental agreement, prepayment			$ 1,000,000
Rental agreement, credit for services, percent			50.00%
Notes receivable						800,000		$ 800,000
Quarterly payment of principal and interest (through February 2017)						137,500		137,500
Note receivable, past due amount												$ 168,437
Repayment of principal and interest of note receivable		$ 168,437
GreenHunter Resources, Inc. | Production Costs
Related Party Transaction
Related party expenses	[2]					840,000	894,000	3,039,000	1,969,000
GreenHunter Resources, Inc. | Midstream natural gas gathering, processing, and marketing
Related Party Transaction
Related party expenses						0	132,000	0	532,000
GreenHunter Resources, Inc. | Oilfield Services
Related Party Transaction
Related party expenses	[2]					151,000	0	256,000	0
GreenHunter Resources, Inc. | General and administrative
Related Party Transaction
Related party expenses	[2]					7,000	0	19,000	36,000
GreenHunter Resources, Inc. | Miscellaneous income
Related Party Transaction
Miscellaneous income	[1]					(1,709,000)	55,000	$ (1,599,000)	165,000
Pilatus Hunter
Related Party Transaction
Percentage of owned in subsidiary								100.00%
Pilatus Hunter | General and administrative
Related Party Transaction
Related party expenses	[3]					81,000	49,000	$ 117,000	207,000
Eureka Hunter Holdings, LLC
Related Party Transaction
Capitalized Costs Incurred, Disposal Costs	[4]					0	715,000	121,000	2,526,000
Eureka Hunter Holdings, LLC | Production Costs
Related Party Transaction
Related party expenses	[4]					144,000	0	740,000	0
Eureka Hunter Holdings, LLC | Oilfield Services
Related Party Transaction
Related party expenses	[4]					11,000	0	27,000	0
Eureka Hunter Holdings, LLC | Transportation, processing, and other related costs
Related Party Transaction
Related party expenses	[4]					7,503,000	0	18,218,000	0
Kirk Trosclair Enterprises, LLC
Related Party Transaction
Monthly labor and related expense					$ 10,000
Labor and related expense								141,000
Share-based compensation								161,888
Kirk Trosclair Enterprises, LLC | General and administrative
Related Party Transaction
Related party expenses						52,000	0	141,000	0
Classic Petroleum, Inc.
Related Party Transaction
Capitalized Costs Incurred, Land Services	[5]					21,000	$ 447,000	$ 206,000	$ 971,000
Chief Executive Officer | GreenHunter Resources, Inc.
Related Party Transaction
Shares purchased by related party from agreement for acquisition of assets | shares								27,641
Eureka Hunter Pipeline Gas Gathering Agreement
Related Party Transaction
Oil and gas delivery commitments and contracts, fixed price | $ / MMBTU													0.75
Amended and Restated Gas Gathering Services Agreement
Related Party Transaction
Administrative services revenue				$ 500,000
Administrative services revenue, additional percentage on annual fee				1.50%
Green Hunter Energy | GreenHunter Resources, Inc.
Related Party Transaction
Amounts reclassified for other than temporary impairment of available for sale securities						$ 1,800,000		$ 1,800,000
Subsequent Event | Eureka Hunter Pipeline Gas Gathering Agreement
Related Party Transaction
Demand notice of performance security (by November 10, 2015)										$ 20,800,000
Triad Hunter | Subsequent Event | Eureka Hunter Pipeline
Related Party Transaction
Accounts payable											$ 10,700,000
[1]	On February 17, 2012, the Company sold its wholly owned subsidiary, Hunter Disposal, to GreenHunter Water, LLC ("GreenHunter Water"), a wholly owned subsidiary of GreenHunter. The Company recognized an embedded derivative asset resulting from the conversion option under the convertible promissory note it received as partial consideration for the sale. See "Note 7 - Fair Value of Financial Instruments" for additional information. The Company has recorded interest income as a result of the note receivable from GreenHunter. Also as a result of this transaction, the Company has an equity method investment in GreenHunter that is included in derivatives and investment in affiliates - equity method and an available for sale investment in GreenHunter included in investments. Miscellaneous income (expense) includes other than temporary impairment loss on the GreenHunter available for sale security of $1.8 million for the three and nine months ended September 2015. See "Note 8 - Investments and Derivatives" for additional information.
[2]	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman and a major shareholder. Triad Hunter and Viking International Resources Co., Inc., wholly owned subsidiaries of the Company, receive services related to brine water and rental equipment from GreenHunter and certain affiliated companies. The Company believes that such services were and are provided at competitive market rates and were and are comparable to, or more attractive than, rates that could be obtained from unaffiliated third party suppliers of such services.
[3]	The Company rented an airplane for business use for certain members of Company management at various times from Pilatus Hunter, LLC, an entity 100% owned by Mr. Evans. Airplane rental expenses are recorded in general and administrative expense.
[4]	Following a series of transactions up to and including, December 18, 2014, the Company no longer held a controlling financial interest in Eureka Hunter Holdings. The Company deconsolidated Eureka Hunter Holdings and accounts for its retained interest as of December 31, 2014 under the equity method of accounting. As discussed in "Note 3 - Acquisitions, Divestitures, and Discontinued Operations", in June 2015 the Company adopted a plan to dispose of its equity method investment in Eureka Hunter Holdings, and has classified the related operations as discontinued operations and the investment as assets of discontinued operations for all periods presented.
[5]	Classic Petroleum, Inc. is an entity owned by the brother of James W. Denny, III, the Company's former Executive Vice President and President of the Company's Appalachian Division. Triad Hunter received land brokerage services from Classic Petroleum, Inc., including courthouse abstracting, contract negotiations, GIS mapping and leasing services.

COMMITMENTS AND CONTINGENCIES (

COMMITMENTS AND CONTINGENCIES (Details) $ in Millions	Jul. 01, 2015USD ($)	Jan. 14, 2015USD ($)a	Sep. 30, 2015a	Jun. 30, 2015USD ($)	Aug. 12, 2013a
Utica Shale, Ohio
Subsequent Event [Line Items]
Net mineral acres acquired | a					32,000
Leasehold Acreage From MNW Energy, LLC
Subsequent Event [Line Items]
Net leasehold acres purchased | a		2,665.1
Payment to acquire leasehold acres		$ 12
Percent of total leasehold acres acquired under the asset purchase agreement			78.30%
Utica Shale, Ohio | Leasehold Acreage From MNW Energy, LLC
Subsequent Event [Line Items]
Net leasehold acres purchased, to date | a			25,044
Drilling Rig Purchase | Alpha Hunter Drilling LLC
Subsequent Event [Line Items]
Agreed upon purchase price				$ 6.5
Purchase price of a new drilling rig	$ 1.3

SUPPLEMENTAL CASH FLOW INFORM74

SUPPLEMENTAL CASH FLOW INFORMATION (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Supplemental Cash Flow Elements [Abstract]
Cash paid for interest	$ 49,271	$ 38,565
Non-cash transactions
Common stock issued for 401k matching contributions	1,878	1,593
Non-cash consideration received from sale of assets		9,447
Change in accrued capital expenditures	(98,296)	129,778
Non-cash changes in asset retirement obligation	$ (556)	2,439
Eureka Hunter Holdings Series A Preferred Unit dividends paid in kind		$ 1,950

SEGMENT REPORTING (Details)

SEGMENT REPORTING (Details) - USD ($) $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2015		Sep. 30, 2014	Sep. 30, 2015		Sep. 30, 2014	Dec. 31, 2014
Details of operating activities by segment
Total revenue	$ 33,664		$ 70,557	$ 128,586		$ 308,075
Depletion, depreciation, amortization and accretion	23,378		32,147	103,441		89,903
Gain on sale of assets, net	(2,892)		(7,988)	(31,288)		(4,600)
Other operating expenses	97,830		102,463	214,044		303,537
Other income (expense)	(26,518)		(7,534)	(79,281)		(53,864)
Income (loss) from continuing operations before income tax	(111,170)		(63,599)	(236,892)		(134,629)
Total income (loss) from discontinued operations, net of tax	(2,011)		(59,848)	(3,884)		(115,946)
Net income (loss)	(113,181)		(123,447)	(240,776)		(250,575)
Total assets	1,456,715		2,033,565	1,456,715		2,033,565	$ 1,675,024
Total capital expenditures	5,643		196,439	68,392		498,878
Operating Segments | U.S. Upstream
Details of operating activities by segment
Total revenue	28,252		63,438	112,167		223,788
Depletion, depreciation, amortization and accretion	22,444		31,218	100,607		87,346
Gain on sale of assets, net	(2,956)		(7,988)	(31,340)		(4,231)
Other operating expenses	87,629		87,035	176,618		197,013
Other income (expense)	(2,627)		1,908	(11,440)		1,740
Income (loss) from continuing operations before income tax	(81,492)		(44,919)	(145,158)		(54,600)
Total income (loss) from discontinued operations, net of tax	0		(259)	0		3,353
Net income (loss)	(81,492)		(45,178)	(145,158)		(51,247)
Total assets	1,031,975		1,475,305	1,031,975		1,475,305
Total capital expenditures	5,278		104,265	65,700		321,024
Operating Segments | Midstream and Marketing
Details of operating activities by segment
Total revenue	118		1,133	867		66,726
Depletion, depreciation, amortization and accretion	0		0	0		0
Gain on sale of assets, net	0		0	0		0
Other operating expenses	88		937	689		66,380
Other income (expense)	0		0	0		0
Income (loss) from continuing operations before income tax	30		196	178		346
Total income (loss) from discontinued operations, net of tax	0		(57,991)	0		(98,093)
Net income (loss)	30		(57,795)	178		(97,747)
Total assets	104		443,008	104		443,008
Total capital expenditures	0		88,525	0		171,152
Operating Segments | Oilfield Services
Details of operating activities by segment
Total revenue	6,368		8,176	19,920		23,882
Depletion, depreciation, amortization and accretion	934		929	2,939		2,557
Gain on sale of assets, net	64		0	52		(369)
Other operating expenses	3,584		6,569	13,709		19,643
Other income (expense)	(132)		(205)	(440)		(625)
Income (loss) from continuing operations before income tax	1,654		473	2,780		1,426
Total income (loss) from discontinued operations, net of tax	0		0	0		0
Net income (loss)	1,654		473	2,780		1,426
Total assets	44,477		45,661	44,477		45,661
Total capital expenditures	181		3,628	650		6,575
Corporate Unallocated
Details of operating activities by segment
Total revenue	0	[1]	0	0	[1]	0
Depletion, depreciation, amortization and accretion	0	[1]	0	0	[1]	0
Gain on sale of assets, net	0	[1]	0	0	[1]	0
Other operating expenses	7,603	[1]	11,711	27,247	[1]	35,253
Other income (expense)	(23,759)	[1]	(9,237)	(67,401)	[1]	(54,979)
Income (loss) from continuing operations before income tax	(31,362)	[1]	(20,948)	(94,648)		(90,232)
Total income (loss) from discontinued operations, net of tax	(2,011)	[1]	1	(3,884)		(12,775)
Net income (loss)	(33,373)	[1]	(20,947)	(98,532)	[1]	(103,007)
Total assets	384,156	[1]	74,614	384,156	[1]	74,614
Total capital expenditures	184	[1]	21	2,042	[1]	127
Inter-segment Eliminations
Details of operating activities by segment
Total revenue	(1,074)		(2,190)	(4,368)		(6,321)
Depletion, depreciation, amortization and accretion	0		0	(105)		0
Gain on sale of assets, net	0		0	0		0
Other operating expenses	(1,074)		(3,789)	(4,219)		(14,752)
Other income (expense)	0		0	0		0
Income (loss) from continuing operations before income tax	0		1,599	(44)		8,431
Total income (loss) from discontinued operations, net of tax	0		(1,599)	0		(8,431)
Net income (loss)	0		0	(44)		0
Total assets	(3,997)		(5,023)	(3,997)		(5,023)
Total capital expenditures	0		$ 0	0		$ 0
Eureka Hunter Holdings, LLC
Details of operating activities by segment
Equity method investments	$ 343,300			$ 343,300			$ 347,200
[1]	(1) Includes the Company's retained interest in Eureka Hunter Holdings which was valued at $343.3 million at September 30, 2015. As discussed in "Note 3 - Acquisitions, Divestitures, and Discontinued Operations", in June 2015 the Company adopted a plan to dispose of its equity method investment in Eureka Hunter Holdings, and has classified the related operations as discontinued operations and the investment as assets of discontinued operations for all periods presented.

CONDENSED CONSOLIDATING GUARA76

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	$ (113,181)	$ (123,447)	$ (240,776)	$ (250,575)
ASSETS
Current assets	39,660		39,660		$ 125,391
Property and equipment (using successful efforts method of accounting)	1,053,564		1,053,564		1,175,658
Total assets	1,456,715	2,033,565	1,456,715	2,033,565	1,675,024
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities	1,076,859		1,076,859		173,640
Shareholders’ equity	239,690		239,690		431,855
Total liabilities and shareholders’ equity	1,456,715		1,456,715		1,675,024
9.75 Percent Senior Notes Due May 15, 2020 | Magnum Hunter Resources Corporation
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(113,181)	(127,006)	(240,776)	(266,125)
ASSETS
Current assets	11,316		11,316		85,647
Intercompany accounts receivable	1,153,644		1,153,644		1,113,417
Property and equipment (using successful efforts method of accounting)	6,461		6,461		5,506
Investment in subsidiaries	(224,706)		(224,706)		(91,595)
Other assets	363,118		363,118		369,995
Total assets	1,309,833		1,309,833		1,482,970
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities	967,762		967,762		25,347
Intercompany accounts payable	0		0		0
Long-term liabilities	2,382		2,382		925,767
Redeemable preferred stock	100,000		100,000		100,000
Shareholders’ equity	239,689		239,689		431,856
Total liabilities and shareholders’ equity	1,309,833		1,309,833		1,482,970
9.75 Percent Senior Notes Due May 15, 2020 | 100% Owned Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(79,828)	(44,101)	(144,488)	(51,611)
ASSETS
Current assets	32,016		32,016		41,533
Property and equipment (using successful efforts method of accounting)	1,047,148		1,047,148		1,170,122
Investment in subsidiaries	91,947		91,947		94,134
Other assets	373		373		3,980
Total assets	1,171,484		1,171,484		1,309,769
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities	113,033		113,033		148,109
Intercompany accounts payable	1,114,504		1,114,504		1,073,091
Long-term liabilities	37,784		37,784		43,762
Redeemable preferred stock	0		0		0
Shareholders’ equity	(93,837)		(93,837)		44,807
Total liabilities and shareholders’ equity	1,171,484		1,171,484		1,309,769
9.75 Percent Senior Notes Due May 15, 2020 | Non Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	74	(58,871)	431	(88,330)
ASSETS
Current assets	281		281		589
Property and equipment (using successful efforts method of accounting)					30
Total assets	281		281		619
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities	17		17		2,567
Intercompany accounts payable	41,377		41,377		42,560
Long-term liabilities	0		0		0
Redeemable preferred stock	0		0		0
Shareholders’ equity	(41,113)		(41,113)		(44,508)
Total liabilities and shareholders’ equity	281		281		619
9.75 Percent Senior Notes Due May 15, 2020 | Eliminations
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	79,754	106,531	144,057	155,491
ASSETS
Current assets	(3,953)		(3,953)		(2,378)
Intercompany accounts receivable	(1,153,644)		(1,153,644)		(1,113,417)
Property and equipment (using successful efforts method of accounting)	(45)		(45)
Investment in subsidiaries	132,759		132,759		(2,539)
Total assets	(1,024,883)		(1,024,883)		(1,118,334)
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities	(3,953)		(3,953)		(2,383)
Intercompany accounts payable	(1,155,881)		(1,155,881)		(1,115,651)
Long-term liabilities	0		0		0
Redeemable preferred stock	0		0		0
Shareholders’ equity	134,951		134,951		(300)
Total liabilities and shareholders’ equity	(1,024,883)		(1,024,883)		(1,118,334)
9.75 Percent Senior Notes Due May 15, 2020 | Magnum Hunter Resources Corporation Consolidated
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(113,181)	$ (123,447)	(240,776)	$ (250,575)
ASSETS
Current assets	39,660		39,660		125,391
Intercompany accounts receivable	0		0		0
Property and equipment (using successful efforts method of accounting)	1,053,564		1,053,564		1,175,658
Investment in subsidiaries	0		0		0
Other assets	363,491		363,491		373,975
Total assets	1,456,715		1,456,715		1,675,024
LIABILITIES AND SHAREHOLDERS' EQUITY
Current liabilities	1,076,859		1,076,859		173,640
Intercompany accounts payable	0		0		0
Long-term liabilities	40,166		40,166		969,529
Redeemable preferred stock	100,000		100,000		100,000
Shareholders’ equity	239,690		239,690		431,855
Total liabilities and shareholders’ equity	$ 1,456,715		$ 1,456,715		$ 1,675,024

CONDENSED CONSOLIDATING GUARA77

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 2) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Condensed consolidating statements of operations
Revenues	$ 33,664	$ 70,557	$ 128,586	$ 308,075
Income (loss) from continuing operations	(111,170)	(63,599)	(236,892)	(134,629)
Gain on dilution of interest in Eureka Hunter Holdings, LLC, net of tax	2,211	0	4,601	0
Loss from discontinued operations, net of tax	(4,222)	(59,590)	(8,485)	(101,963)
Loss on disposal of discontinued operations, net of tax	0	(258)	0	(13,983)
Net income (loss)	(113,181)	(123,447)	(240,776)	(250,575)
Net loss attributed to non-controlling interests	0	2,764	0	3,653
Net income (loss) attributable to Magnum Hunter Resources Corporation	(113,181)	(120,683)	(240,776)	(246,922)
Dividends on preferred stock	(8,848)	(8,848)	(26,543)	(26,516)
Net income (loss) attributable to common shareholders	(122,029)	(136,175)	(267,319)	(292,640)
9.75 Percent Senior Notes Due May 15, 2020 | Magnum Hunter Resources Corporation
Condensed consolidating statements of operations
Revenues	2	10	15	124
Expenses	31,784	21,317	94,992	92,622
Loss from continuing operations before equity in net income of subsidiary	(31,782)	(21,307)	(94,977)	(92,498)
Equity in net income of subsidiary	(79,388)	(105,440)	(141,915)	(153,569)
Income (loss) from continuing operations	(111,170)	(126,747)	(236,892)	(246,067)
Gain on dilution of interest in Eureka Hunter Holdings, LLC, net of tax	2,211		4,601
Loss from discontinued operations, net of tax	(4,222)	0	(8,485)	0
Loss on disposal of discontinued operations, net of tax		(259)		(20,058)
Net income (loss)	(113,181)	(127,006)	(240,776)	(266,125)
Net loss attributed to non-controlling interests		0		0
Net income (loss) attributable to Magnum Hunter Resources Corporation		(127,006)		(266,125)
Dividends on preferred stock	(8,848)	(8,848)	(26,543)	(26,516)
Dividends on preferred stock of discontinued operations		0		0
Net income (loss) attributable to common shareholders	(122,029)	(135,854)	(267,319)	(292,641)
9.75 Percent Senior Notes Due May 15, 2020 | 100% Owned Guarantor Subsidiaries
Condensed consolidating statements of operations
Revenues	35,071	72,809	133,281	313,898
Expenses	114,533	115,817	275,583	363,587
Loss from continuing operations before equity in net income of subsidiary	(79,462)	(43,008)	(142,302)	(49,689)
Equity in net income of subsidiary	(366)	(1,093)	(2,186)	(1,922)
Income (loss) from continuing operations	(79,828)	(44,101)	(144,488)	(51,611)
Gain on dilution of interest in Eureka Hunter Holdings, LLC, net of tax	0		0
Loss from discontinued operations, net of tax	0	0	0	0
Loss on disposal of discontinued operations, net of tax		0		0
Net income (loss)	(79,828)	(44,101)	(144,488)	(51,611)
Net loss attributed to non-controlling interests		0		0
Net income (loss) attributable to Magnum Hunter Resources Corporation		(44,101)		(51,611)
Dividends on preferred stock	0	0	0	0
Dividends on preferred stock of discontinued operations		0		0
Net income (loss) attributable to common shareholders	(79,828)	(44,101)	(144,488)	(51,611)
9.75 Percent Senior Notes Due May 15, 2020 | Non Guarantor Subsidiaries
Condensed consolidating statements of operations
Revenues	143	430	904	875
Expenses	69	1,311	473	1,748
Loss from continuing operations before equity in net income of subsidiary	74	(881)	431	(873)
Equity in net income of subsidiary	0	0	0	0
Income (loss) from continuing operations	74	(881)	431	(873)
Gain on dilution of interest in Eureka Hunter Holdings, LLC, net of tax	0		0
Loss from discontinued operations, net of tax	0	(57,991)	0	(93,532)
Loss on disposal of discontinued operations, net of tax		1		6,075
Net income (loss)	74	(58,871)	431	(88,330)
Net loss attributed to non-controlling interests		0		0
Net income (loss) attributable to Magnum Hunter Resources Corporation		(58,871)		(88,330)
Dividends on preferred stock	0	0	0	0
Dividends on preferred stock of discontinued operations		(6,644)		(19,202)
Net income (loss) attributable to common shareholders	74	(65,515)	431	(107,532)
9.75 Percent Senior Notes Due May 15, 2020 | Eliminations
Condensed consolidating statements of operations
Revenues	(1,552)	(2,692)	(5,614)	(6,822)
Expenses	(1,552)	(4,289)	(5,570)	(15,253)
Loss from continuing operations before equity in net income of subsidiary	0	1,597	(44)	8,431
Equity in net income of subsidiary	79,754	106,533	144,101	155,491
Income (loss) from continuing operations	79,754	108,130	144,057	163,922
Gain on dilution of interest in Eureka Hunter Holdings, LLC, net of tax	0		0
Loss from discontinued operations, net of tax	0	(1,599)	0	(8,431)
Loss on disposal of discontinued operations, net of tax		0		0
Net income (loss)	79,754	106,531	144,057	155,491
Net loss attributed to non-controlling interests		2,764		3,653
Net income (loss) attributable to Magnum Hunter Resources Corporation		109,295		159,144
Dividends on preferred stock	0	0	0	0
Dividends on preferred stock of discontinued operations		0		0
Net income (loss) attributable to common shareholders	79,754	109,295	144,057	159,144
9.75 Percent Senior Notes Due May 15, 2020 | Magnum Hunter Resources Corporation Consolidated
Condensed consolidating statements of operations
Revenues	33,664	70,557	128,586	308,075
Expenses	144,834	134,156	365,478	442,704
Loss from continuing operations before equity in net income of subsidiary	(111,170)	(63,599)	(236,892)	(134,629)
Equity in net income of subsidiary	0	0	0	0
Income (loss) from continuing operations	(111,170)	(63,599)	(236,892)	(134,629)
Gain on dilution of interest in Eureka Hunter Holdings, LLC, net of tax	2,211		4,601
Loss from discontinued operations, net of tax	(4,222)	(59,590)	(8,485)	(101,963)
Loss on disposal of discontinued operations, net of tax		(258)		(13,983)
Net income (loss)	(113,181)	(123,447)	(240,776)	(250,575)
Net loss attributed to non-controlling interests		2,764		3,653
Net income (loss) attributable to Magnum Hunter Resources Corporation		(120,683)		(246,922)
Dividends on preferred stock	(8,848)	(8,848)	(26,543)	(26,516)
Dividends on preferred stock of discontinued operations		(6,644)		(19,202)
Net income (loss) attributable to common shareholders	$ (122,029)	$ (136,175)	$ (267,319)	$ (292,640)

CONDENSED CONSOLIDATING GUARA78

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 3) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	$ (113,181)	$ (123,447)	$ (240,776)	$ (250,575)
Foreign currency translation gain	(2)	0	100	(1,218)
Unrealized loss on available for sale securities	(1,304)	(2,583)	(2,403)	(3,188)
Amounts reclassified for other than temporary impairment of available for sale securities	2,115	0	11,107	0
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	0	0	20,741
COMPREHENSIVE LOSS	(112,372)	(126,030)	(231,972)	(234,240)
Comprehensive loss attributable to non-controlling interests	0	2,764	0	3,653
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	(112,372)	(123,266)	(231,972)	(230,587)
9.75 Percent Senior Notes Due May 15, 2020 | Magnum Hunter Resources Corporation
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(113,181)	(127,006)	(240,776)	(266,125)
Foreign currency translation gain	0		0	0
Unrealized loss on available for sale securities	0	0	0	0
Amounts reclassified for other than temporary impairment of available for sale securities	0		0
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.				20,741
COMPREHENSIVE LOSS	(113,181)	(127,006)	(240,776)	(245,384)
Comprehensive loss attributable to non-controlling interests		0		0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent		(127,006)		(245,384)
9.75 Percent Senior Notes Due May 15, 2020 | 100% Owned Guarantor Subsidiaries
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(79,828)	(44,101)	(144,488)	(51,611)
Foreign currency translation gain	(2)		100	0
Unrealized loss on available for sale securities	(1,304)	(2,583)	(2,403)	(3,188)
Amounts reclassified for other than temporary impairment of available for sale securities	2,115		11,107
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.				0
COMPREHENSIVE LOSS	(79,019)	(46,684)	(135,684)	(54,799)
Comprehensive loss attributable to non-controlling interests		0		0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent		(46,684)		(54,799)
9.75 Percent Senior Notes Due May 15, 2020 | Non-Guarantor Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	74	(58,871)	431	(88,330)
Foreign currency translation gain	0		0	(1,218)
Unrealized loss on available for sale securities	0	0	0	0
Amounts reclassified for other than temporary impairment of available for sale securities	0		0
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.				0
COMPREHENSIVE LOSS	74	(58,871)	431	(89,548)
Comprehensive loss attributable to non-controlling interests		0		0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent		(58,871)		(89,548)
9.75 Percent Senior Notes Due May 15, 2020 | Eliminations
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	79,754	106,531	$ 144,057	155,491
Foreign currency translation gain	0			0
Unrealized loss on available for sale securities	0	0	$ 0	0
Amounts reclassified for other than temporary impairment of available for sale securities	0		0
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.				0
COMPREHENSIVE LOSS	79,754	106,531	144,057	155,491
Comprehensive loss attributable to non-controlling interests		2,764		3,653
Comprehensive Income (Loss), Net of Tax, Attributable to Parent		109,295		159,144
9.75 Percent Senior Notes Due May 15, 2020 | Magnum Hunter Resources Corporation Consolidated
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(113,181)	(123,447)	(240,776)	(250,575)
Foreign currency translation gain	(2)		100	(1,218)
Unrealized loss on available for sale securities	(1,304)	(2,583)	(2,403)	(3,188)
Amounts reclassified for other than temporary impairment of available for sale securities	2,115		11,107
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.				20,741
COMPREHENSIVE LOSS	$ (112,372)	(126,030)	$ (231,972)	(234,240)
Comprehensive loss attributable to non-controlling interests		2,764		3,653
Comprehensive Income (Loss), Net of Tax, Attributable to Parent		$ (123,266)		$ (230,587)

CONDENSED CONSOLIDATING GUARA79

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 4) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Schedule of condensed consolidating statements of cash flows
Cash flow from operating activities	$ 46,811	$ 13,555
Cash flows from investing activities	(123,101)	(247,304)
Cash flows from financing activities	29,577	234,659
Effect of changes in exchange rate on cash	(4)	44
Net increase (decrease) in cash	(46,717)	954
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	53,180	41,713
CASH AND CASH EQUIVALENTS, END OF PERIOD	6,463	42,667
9.75 Percent Senior Notes Due May 15, 2020 | Magnum Hunter Resources Corporation
Schedule of condensed consolidating statements of cash flows
Cash flow from operating activities	(88,117)	(261,039)
Cash flows from investing activities	(1,437)	63,502
Cash flows from financing activities	33,670	193,885
Net increase (decrease) in cash	(55,884)	(3,652)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	64,165	47,895
CASH AND CASH EQUIVALENTS, END OF PERIOD	8,281	44,243
9.75 Percent Senior Notes Due May 15, 2020 | 100% Owned Guarantor Subsidiaries
Schedule of condensed consolidating statements of cash flows
Cash flow from operating activities	135,077	222,520
Cash flows from investing activities	(121,813)	(211,560)
Cash flows from financing activities	(4,093)	2,232
Effect of changes in exchange rate on cash	(4)
Net increase (decrease) in cash	9,167	13,192
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	(10,985)	(17,651)
CASH AND CASH EQUIVALENTS, END OF PERIOD	(1,818)	(4,459)
9.75 Percent Senior Notes Due May 15, 2020 | Non Guarantor Subsidiaries
Schedule of condensed consolidating statements of cash flows
Cash flow from operating activities		52,074
Cash flows from investing activities		(99,246)
Cash flows from financing activities		38,542
Effect of changes in exchange rate on cash		44
Net increase (decrease) in cash		(8,586)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD		11,469
CASH AND CASH EQUIVALENTS, END OF PERIOD		2,883
9.75 Percent Senior Notes Due May 15, 2020 | Eliminations
Schedule of condensed consolidating statements of cash flows
Cash flow from operating activities	(149)
Cash flows from investing activities	149
9.75 Percent Senior Notes Due May 15, 2020 | Magnum Hunter Resources Corporation Consolidated
Schedule of condensed consolidating statements of cash flows
Cash flow from operating activities	46,811	13,555
Cash flows from investing activities	(123,101)	(247,304)
Cash flows from financing activities	29,577	234,659
Effect of changes in exchange rate on cash	(4)	44
Net increase (decrease) in cash	(46,717)	954
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	53,180	41,713
CASH AND CASH EQUIVALENTS, END OF PERIOD	$ 6,463	$ 42,667

SUBSEQUENT EVENTS (Details)

SUBSEQUENT EVENTS (Details) - Subsequent Event - USD ($) $ in Millions	Nov. 02, 2015	Nov. 03, 2015	Oct. 20, 2015
New Standard Energy Limited
Subsequent Event [Line Items]
Number of shares sold			65,650,000
Minimum | Sixth Amendment
Subsequent Event [Line Items]
Expected liquidity period after refinancing	30 days
Maximum | Sixth Amendment
Subsequent Event [Line Items]
Expected liquidity period after refinancing	45 days
Bank Of Montreal | Commodity
Subsequent Event [Line Items]
Proceeds from termination of open commodity derivative positions	$ 0.9
Letter of Credit | Sixth Amendment
Subsequent Event [Line Items]
Collateral amount of outstanding debt		$ 39
Term Loan | Sixth Amendment
Subsequent Event [Line Items]
Amount outstanding		5
Borrowing base		$ 16