Magnum Hunter Resources 10-Q 8 Aug 14 2014 Q2 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	6 Months Ended
	Jun. 30, 2014	Aug. 07, 2014
Document and Entity Information [Abstract]	'	'
Entity Registrant Name	'MAGNUM HUNTER RESOURCES CORP	'
Entity Central Index Key	'0001335190	'
Document Type	'10-Q	'
Document Period End Date	30-Jun-14	'
Amendment Flag	'false	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Entity Common Stock, Shares Outstanding	'	199,397,350
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q2	'

CONSOLIDATED_BALANCE_SHEETS_Un

CONSOLIDATED BALANCE SHEETS (Unaudited) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
CURRENT ASSETS	'	'
Cash and cash equivalents	$9,120	$41,713
Restricted cash	5,000	5,000
Oil and natural gas sales	47,723	25,099
Joint interests and other, net of allowance for doubtful accounts of $252 at June 30, 2014 and $196 at December 31, 2013	40,160	30,582
Derivative assets	317	608
Inventory	3,830	7,158
Investments	10,771	2,262
Prepaid expenses and other assets	3,054	2,938
Assets held for sale	1,638	5,366
Total current assets	121,613	120,726
PROPERTY, PLANT AND EQUIPMENT	'	'
Oil and natural gas properties, successful efforts method of accounting, net	1,328,701	1,224,659
Gas transportation, gathering and processing equipment and other, net	369,324	289,420
Total property, plant and equipment, net	1,698,025	1,514,079
OTHER ASSETS	'	'
Deferred financing costs, net of amortization of $12,195 at June 30, 2014 and $9,735 at December 31, 2013	18,358	20,008
Derivative assets, long-term	123	25
Intangible assets, net	5,527	6,530
Goodwill	30,602	30,602
Assets held for sale	84,935	162,687
Other assets	4,174	1,994
Total assets	1,963,357	1,856,651
CURRENT LIABILITIES	'	'
Current portion of notes payable	5,431	3,804
Accounts payable	128,356	107,837
Accounts payable to related parties	690	23
Accrued liabilities	55,636	44,629
Revenue payable	10,039	6,313
Derivative liabilities	5,709	1,903
Liabilities associated with assets held for sale	17,961	12,865
Other liabilities	2,374	6,491
Total current liabilities	226,196	183,865
Long-term debt	839,009	876,106
Asset retirement obligations	16,568	16,163
Derivative liabilities, long-term	115,727	76,310
Other long-term liabilities	2,163	2,279
Long-term liabilities associated with assets held for sale	11,310	14,523
Total liabilities	1,210,973	1,169,246
COMMITMENTS AND CONTINGENCIES (Note 16)	'	'
REDEEMABLE PREFERRED STOCK	'	'
Redeemable preferred stock	249,379	236,675
SHAREHOLDERS’ EQUITY	'	'
Common stock, $0.01 par value per share, 350,000,000 shares authorized, and 200,299,799 and 172,409,023 issued, and 199,384,847 and 171,494,071 outstanding as of June 30, 2014 and December 31, 2013, respectively	2,003	1,724
Additional paid in capital	924,185	733,753
Accumulated deficit	-742,830	-586,365
Accumulated other comprehensive loss	-983	-19,901
Treasury stock, at cost	-1,914	-1,914
Total Magnum Hunter Resources Corporation shareholders’ equity	494,744	441,580
Non-controlling interest	8,261	9,150
Total shareholders’ equity	503,005	450,730
Total liabilities and shareholders’ equity	1,963,357	1,856,651
Series C Cumulative Perpetual Preferred Stock	'	'
REDEEMABLE PREFERRED STOCK	'	'
Redeemable preferred stock	100,000	100,000
Series A Preferred Units	'	'
REDEEMABLE PREFERRED STOCK	'	'
Redeemable preferred stock	149,379	136,675
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 $)	6 Months Ended	12 Months Ended
	Jun. 30, 2014	Dec. 31, 2012	Dec. 31, 2013
Accounts receivable, allowance for doubtful accounts	$252,000	'	$196,000
Amortization of deferred financing costs	12,195,000	'	9,735,000
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	'	250,000,000
Common stock, shares issued	200,299,799	'	172,409,023
Common stock, shares outstanding	199,384,847	'	171,494,071
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 A Preferred Units	'	'	'
Cumulative dividend rate (as a percent)	8.00%	8.00%	'
Preferred stock, shares issued	10,592,540	'	9,885,048
Preferred stock, shares outstanding	10,592,540	'	9,885,048
Preferred stock, liquidation preference	$214,776	'	$200,620
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

UNAUDITED_CONSOLIDATED_STATEME

UNAUDITED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) (USD $)	3 Months Ended			6 Months Ended
In Thousands, except Share data, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013	Jun. 30, 2014		Jun. 30, 2013
REVENUES AND OTHER	'		'	'		'
Oil and natural gas sales	$78,190		$49,583	$148,362		$84,224
Natural gas transportation, gathering, processing, and marketing	48,363		13,974	80,012		29,870
Oilfield services	5,954		3,612	11,575		7,305
Other revenue	9		739	11		743
Total revenue	132,516		67,908	239,960		122,142
OPERATING EXPENSES	'		'	'		'
Lease operating expenses	14,836		15,213	34,792		22,881
Severance taxes and marketing	6,627		4,016	12,201		6,848
Exploration	9,187		3,546	23,216		33,279
Impairment of proved oil and gas properties	158		9,968	158		9,968
Natural gas transportation, gathering, processing, and marketing	44,754		13,414	74,753		26,845
Oilfield services	4,089		4,066	8,036		7,401
Depletion, depreciation, amortization and accretion	35,953		26,375	65,361		43,663
Loss (gain) on sale of assets, net	-687		1,183	2,772		1,164
General and administrative	18,738		16,364	34,010		36,341
Total operating expenses	133,655		94,145	255,299		188,390
OPERATING LOSS	-1,139		-26,237	-15,339		-66,248
OTHER INCOME (EXPENSE)	'		'	'		'
Interest income	41		81	86		138
Interest expense	-20,434		-18,793	-44,283		-37,494
Gain (loss) on derivative contracts, net	-42,836		6,400	-42,489		-1,091
Other expense (income)	264		-465	20		-681
Total other expense, net	-62,965		-12,777	-86,666		-39,128
LOSS FROM CONTINUING OPERATIONS BEFORE INCOME TAX	-64,104		-39,014	-102,005		-105,376
Income tax benefit	0		39,300	0		44,199
INCOME (LOSS) FROM CONTINUING OPERATIONS, NET OF TAX	-64,104		286	-102,005		-61,177
Income (loss) from discontinued operations, net of tax	3,889		-7,684	7,251		9,079
Gain (loss) on disposal of discontinued operations, net of tax	-5,212		172,452	-32,374		172,452
NET INCOME (LOSS)	-65,427		165,054	-127,128		120,354
Net loss attributed to non-controlling interests	780		386	889		889
INCOME (LOSS) ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	-64,647		165,440	-126,239		121,243
Dividends on preferred stock	-15,330		-14,129	-30,226		-27,617
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	-79,977		151,311	-156,465		93,626
Weighted average number of common shares outstanding, basic and diluted	184,479,312		169,690,633	178,346,940		169,657,806
Loss from continuing operations per share, basic and diluted	($0.42)		($0.08)	($0.74)		($0.52)
Income (loss) from discontinued operations per share, basic and diluted	($0.01)		$0.97	($0.14)		$1.07
NET INCOME (LOSS) PER COMMON SHARE, BASIC AND DILUTED	($0.43)		$0.89	($0.88)		$0.55
Income (loss) from continuing operations, net of tax	-63,324		672	-101,116		-60,288
Income (loss) from discontinued operations, net of tax	-1,323	[1]	164,768	-25,123	[1]	181,531
Net income (loss)	($64,647)		$165,440	($126,239)		$121,243
[1]	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.

UNAUDITED_CONSOLIDATED_STATEME1

UNAUDITED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS (Unaudited) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Statement of Comprehensive Income [Abstract]	'	'	'	'
Net loss	($65,427)	$165,054	($127,128)	$120,354
OTHER COMPREHENSIVE INCOME (LOSS)	'	'	'	'
Foreign currency translation gain (loss)	1,130	-7,070	-1,218	-11,799
Unrealized gain (loss) on available for sale investments	-549	4,466	-605	4,449
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	20,741	0	20,741	0
Total other comprehensive income (loss)	21,322	-2,604	18,918	-7,350
COMPREHENSIVE INCOME (LOSS)	-44,105	162,450	-108,210	113,004
Comprehensive loss attributable to non-controlling interests	780	386	889	889
COMPREHENSIVE INCOME (LOSS) ATTRIBUTABLE TO MAGNUM HUNTER RESOURCES CORPORATION	($43,325)	$162,836	($107,321)	$113,893

UNAUDITED_CONSOLIDATED_STATEME2

UNAUDITED CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY (Unaudited) (USD $)	Total	Common Stock	Additional Paid in Capital	Accumulated Deficit	Accumulated Other Comprehensive Income (loss)	Treasury Stock	Non - controlling Interest	Series D Preferred Stock	Series E Preferred Stock	Series E Preferred Stock
In Thousands, except Share data, unless otherwise specified								Preferred Stock		Preferred Stock
BALANCE at Dec. 31, 2013	$450,730	$1,724	$733,753	($586,365)	($19,901)	($3,944)	$9,150	$221,244	'	$95,069
BALANCE (in shares) at Dec. 31, 2013	'	172,409,000	'	'	'	'	'	4,425,000	'	4,000
Increase (Decrease) in Shareholders' Equity	'	'	'	'	'	'	'	'	'	'
Share based compensation (in shares)	'	47,000	'	'	'	'	'	'	'	'
Share based compensation	3,375	1	3,374	'	'	'	'	'	'	'
Sale of common stock (in shares)	'	25,729,000	'	'	'	'	'	'	'	'
Sale of common stock	178,575	257	178,318	'	'	'	'	'	'	'
Dividends on preferred stock	-30,226	'	'	-30,226	'	'	'	'	'	'
Shares of common stock issued upon exercise of common stock options (in shares)	'	2,115,000	'	'	'	'	'	'	'	'
Shares of common stock issued upon exercise of common stock options	'	21	8,740	'	'	'	'	'	8,761	'
Net loss	-127,128	'	'	-126,239	'	'	-889	'	'	'
Foreign currency translation gain (loss)	-1,218	'	'	'	-1,218	'	'	'	'	'
Unrealized gain on available for sale securities	-605	'	'	'	-605	'	'	'	'	'
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	20,741	'	'	'	20,741	'	'	'	'	'
BALANCE at Jun. 30, 2014	$503,005	$2,003	$924,185	($742,830)	($983)	($3,944)	$8,261	$221,244	'	$95,069
BALANCE (in shares) at Jun. 30, 2014	'	200,300,000	'	'	'	'	'	4,425,000	'	4,000

UNAUDITED_CONSOLIDATED_STATEME3

UNAUDITED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Statement of Cash Flows [Abstract]	'	'
Net loss	($127,128)	$120,354
Adjustments to reconcile net loss to net cash provided by (used in) operating activities:	'	'
Depletion, depreciation, amortization and accretion	65,361	73,078
Exploration	22,489	34,168
Impairment of proved oil and gas properties	158	16,034
Impairment of other operating assets	616	263
Share-based compensation	3,375	8,699
Cash paid for plugging wells	-27	'
Loss (gain) on sale of assets	35,761	-206,082
Unrealized loss on derivative contracts	37,938	786
Unrealized loss on investments	403	1,152
Amortization and write-off of deferred financing costs and discount on Senior Notes included in interest expense	7,740	2,758
Deferred tax benefit	'	-6,475
Changes in operating assets and liabilities:	'	'
Accounts receivable, net	-15,588	7,760
Inventory	3,475	-459
Prepaid expenses and other current assets	-1,147	-802
Accounts payable	-23,817	24,099
Revenue payable	5,204	-1,204
Accrued liabilities	3,934	-261
Net cash provided by operating activities	18,747	73,868
CASH FLOWS FROM INVESTING ACTIVITIES	'	'
Capital expenditures and advances	-257,469	-277,492
Change in restricted cash	0	1,500
Change in deposits and other long-term assets	-2,406	154
Proceeds from sales of assets	74,503	380,036
Net cash provided by (used in) investing activities	-185,372	104,198
CASH FLOWS FROM FINANCING ACTIVITIES	'	'
Net proceeds from sale of common shares	178,575	0
Net proceeds from sale of preferred shares	'	10,181
Equity issuance costs	0	-109
Proceeds from sale of Eureka Hunter Holdings Series A Preferred Units	11,956	19,600
Proceeds from exercise of warrants and options	8,761	'
Preferred stock dividend	-23,646	-10,424
Repayments of debt	-197,216	-327,076
Proceeds from borrowings on debt	161,616	105,991
Deferred financing costs	-6,042	-701
Change in other long-term liabilities	-13	-52
Net cash provided by financing activities	133,991	-202,590
Effect of changes in exchange rate on cash	41	-357
NET DECREASE IN CASH AND CASH EQUIVALENTS	-32,593	-24,881
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	41,713	57,623
CASH AND CASH EQUIVALENTS, END OF PERIOD	$9,120	$32,742

GENERAL

GENERAL	6 Months Ended
	Jun. 30, 2014
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 (together with its subsidiaries, the "Company" or "Magnum Hunter"), is a Houston, Texas based independent exploration and production company engaged in the United States in the acquisition and development of producing properties and undeveloped acreage and the production of oil and natural gas, along with certain midstream and oilfield services activities.
	Presentation of Consolidated Financial Statements
	The accompanying unaudited interim consolidated financial statements of Magnum Hunter are presented in U.S. Dollars and have been prepared in accordance with accounting principles generally accepted in the United States ("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, 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, 2013, as amended.
	Non-Controlling Interest in Consolidated Subsidiaries
	The Company has consolidated Eureka Hunter Holdings, LLC ("Eureka Hunter Holdings") in which it owned 56.5% as of June 30, 2014 and 56.4% as of December 31, 2013. Eureka Hunter Holdings owns, directly or indirectly, 100% of the equity interests of Eureka Hunter Pipeline, LLC ("Eureka Hunter Pipeline"), TransTex Hunter, LLC ("TransTex Hunter"), and Eureka Hunter Land, LLC. On December 30, 2013, the Company's majority-owned subsidiary, PRC Williston, LLC ("PRC Williston"), in which the Company owned 87.5% as of June 30, 2014 and December 31, 2013, sold substantially all of its assets. The consolidated financial statements also reflect the interests of 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-Year Balances
	Certain prior period balances have been reclassified to correspond with current-year presentation.  As a result of the Company's adoption of a plan in September 2013 to dispose of certain of its U.S. and Canadian properties, operating income and expenses related to these operations have been classified as discontinued operations for all periods presented. See "Note 2 - Divestitures and Discontinued Operations".
	Regulated Activities
	Energy Hunter Securities, Inc. is a 100%-owned subsidiary and is a registered broker-dealer and member of the Financial Industry Regulatory Authority. Among other regulatory requirements, it is subject to the net capital provisions of Rule 15c3-1 under the Securities Exchange Act of 1934, as amended. Because it does not hold customer funds or securities or owe money or securities to customers, Energy Hunter Securities, Inc. is required to maintain minimum net capital equal to the greater of $5,000 or 6.67% of its aggregate indebtedness. As of June 30, 2014 and December 31, 2013, Energy Hunter Securities, Inc. had net capital of $84,919 and $77,953, respectively, and aggregate indebtedness of $7,289 and $16,657, respectively.
	Sentra Corporation, a 100%-owned subsidiary, 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 ASC 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 six months ended June 30, 2014, the Company had gas transmission, compression and processing revenue, reported in income from discontinued operations, which included gas utility sales from Sentra Corporation's regulated operations aggregating $274,827 and $445,899, respectively. During the three and six months ended June 30, 2013, the Company had no revenues related to Sentra Corporation's regulated operations.
	Energy Hunter Securities, Inc. and Sentra Corporation are included in discontinued 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 March 2013, the FASB issued ASU 2013-05, Parent’s Accounting for the Cumulative Translation Adjustment upon Derecognition of Certain Subsidiaries or Groups of Assets within a Foreign Entity or of an Investment in a Foreign Entity, to provide guidance on whether to release cumulative translation adjustments ("CTA") upon certain derecognition events. ASU 2013-05 requires a parent company to apply the guidance in ASC Subtopic 830-30 when an entity ceases to have a controlling financial interest in a subsidiary or group of assets that is a business within a foreign entity. Consequently, the CTA related to a foreign entity is released into net income only if the transaction results in complete or substantially complete liquidation of the foreign entity in which the subsidiary or group of assets resided; otherwise, no portion of the CTA is released.  The Company adopted this pronouncement prospectively on January 1, 2014. The adoption of this updated standard did not have a material impact on the Company’s consolidated financial statements.
	In July 2013, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2013-11, Presentation of Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists, an amendment to FASB Accounting Standards Codification ("ASC") Topic 740, Income Taxes ("FASB ASC Topic 740"). This update clarified that an unrecognized tax benefit, or a portion of an unrecognized tax benefit, should be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward if such settlement is required or expected in the event the uncertain tax position is disallowed. In situations where a net operating loss carryforward, a similar tax loss, or a tax credit carryforward is not available at the reporting date under the tax law of the applicable jurisdiction or the tax law of the jurisdiction does not require, and the entity does not intend to use, the deferred tax asset for such purpose, the unrecognized tax benefit should be presented in the financial statements as a liability and should not be combined with deferred tax assets. The Company adopted this ASU prospectively on January 1, 2014. The adoption of this accounting standard update did not have a material impact on the Company's consolidated financial statements or its financial statement disclosures.
	In April 2014, the FASB issued ASU 2014-08 , Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. ASU 2014-08 updates 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 or a group of components of an entity 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 or group of components of an entity 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). The amendments in this update expand the disclosure requirements related to discontinued operations and disposals of individually significant components that do not qualify for discontinued operations presentation in the financial statements. This ASU is 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. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.
	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: identify the contract(s) with a customer, identify the performance obligations in the contract, determine the transaction price, allocate the transaction price to the performance obligations in the contract, and 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. This amendment is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. Early application is not permitted. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.
	In June 2014, the FASB issued ASU 2014-12, Compensation - Stock Compensation: Accounting for Share Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period. ASU 2014-12 clarifies that a performance target that affects vesting and that could be achieved after the requisite service period should be treated as a performance condition. An entity should apply existing guidance in ASC Topic 718 as it relates to awards with performance conditions that affect vesting to account for such awards. As such, the performance target should not be reflected in estimating the grant-date fair value of the award. This amendment is effective for annual periods and interim periods within those annual periods beginning after December 15, 2015. Early adoption is permitted. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.

DIVESTITURES_AND_DISCONTINUED_

DIVESTITURES AND DISCONTINUED OPERATIONS	6 Months Ended
	Jun. 30, 2014
Discontinued Operations and Disposal Groups [Abstract]	'
DIVESTITURES AND DISCONTINUED OPERATIONS	'
	NOTE 2 - DIVESTITURES AND DISCONTINUED OPERATIONS
	Discontinued Operations
	In September 2013, the Company adopted a plan to divest all of its interests in (i) MHP, a wholly-owned subsidiary of the Company whose oil and natural gas operations are located primarily in the Southern Appalachian Basin in Kentucky and Tennessee, and (ii) the Canadian operations of Williston Hunter Canada, Inc. ("WHI Canada"), a wholly-owned subsidiary of the Company.
	Planned Divestiture of Magnum Hunter Production
	The Company is marketing its interests in MHP and its subsidiaries, and anticipates entering into a purchase and sale agreement for MHP by the end of 2014. The Company has classified the associated assets and liabilities of MHP to assets and liabilities held for sale and the operations are reflected as discontinued operations for all periods presented.
	During the year ended December 31, 2013, the Company recorded an impairment expense of $18.5 million to record MHP at the estimated selling price less costs to sell. Based upon additional information on estimated selling prices obtained through active marketing of the assets, the Company recorded an additional impairment expense as of March 31, 2014 of $18.6 million to reflect the net assets at their estimated selling prices, less costs to sell, which is recorded in gain (loss) on disposal of discontinued operations for the six months ended June 30, 2014.
	Williston Hunter Canada Asset Sale
	On April 10, 2014, WHI Canada closed on the sale of certain oil and natural gas properties and assets located in Alberta, Canada for cash consideration of CAD $9.5 million in cash (approximately U.S. $8.7 million at the exchange rate as of the close of business on April 10, 2014). The effective date of the sale was January 1, 2014. The Company recognized a gain of $6.1 million which is recorded in gain (loss) on disposal of discontinued operations.
	Sale of Williston Hunter Canada
	On May 12, 2014, the Company closed on the sale of 100% of its ownership interest in the Company's Canadian subsidiary, WHI Canada, whose assets consisted primarily of oil and natural gas properties located in the Tableland Field in Saskatchewan, Canada, for a purchase price of CAD $75.0 million (approximately U.S. $68.8 million at the exchange rate as of the close of business on May 12, 2014), prior to customary purchase price adjustments, with an effective date of March 1, 2014, of which CAD $18.4 million was placed in escrow pending final approval from the Canadian Revenue Authority and included in accounts receivable- joint interests and other as of June 30, 2014. The Company subsequently received the cash held in escrow in early July 2014. The Company recognized a loss of $12.8 million which is recorded in gain (loss) on disposal of discontinued operations. The loss on disposal of WHI Canada for the three and six months ended June 30, 2014 includes $20.7 million in foreign currency translation adjustment which was reclassified out of accumulated other comprehensive income upon closing on the sale of our foreign operation.
	The following shows the Company's assets and liabilities held for sale at June 30, 2014 and December 31, 2013:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Accounts receivable	$	927		$	4,362
	Other current assets	711			1,004
	Oil and natural gas properties, net	71,935			150,770
	Gas transportation, gathering, and processing equipment and other, net	12,972			11,721
	Other long-term assets	28			196
	Total assets held for sale	$	86,573		$	168,053
	Accounts payable	$	7,659		$	7,292
	Accrued liabilities and other liabilities	10,302			5,573
	Asset retirement obligations	6,975			8,678
	Other long-term liabilities	4,335			5,845
	Total liabilities held for sale	$	29,271		$	27,388
	Sale of Eagle Ford Hunter
	On April 24, 2013, the Company closed on the sale of all of its ownership interest in its wholly-owned subsidiary, Eagle Ford Hunter, Inc. ("Eagle Ford Hunter") to an affiliate of Penn Virginia Corporation for a total purchase price of approximately $422.1 million paid to the Company in the form of $379.8 million in cash (after estimated customary initial purchase price adjustments) and 10.0 million shares of common stock of Penn Virginia valued at approximately $42.3 million (based on the closing market price of the stock of $4.23 as of April 24, 2013). The effective date of the sale was January 1, 2013. At the date of closing, the Company initially recognized a preliminary gain on the sale of $172.5 million, net of tax, pending final working capital adjustments.
	In the months that followed closing, the Company and Penn Virginia were unable to agree upon the final settlement of the working capital adjustments as called for in the purchase and sale agreement and the disagreement was subsequently submitted to arbitration. The determination by the arbitrator was received by the Company on July 25, 2014 and resulted in a downward adjustment of the cash portion of the purchase price of $33.7 million plus accrued interest of $1.3 million. The Company had previously reserved and recognized substantially all of this obligation in its financial statements as of December 31, 2013. For the three and six months ended June 30, 2014, the Company recorded a downward adjustment to the gain on sale of Eagle Ford Hunter of $2.7 million and $7.0 million, respectively. See "Note 20 - Subsequent Events" for additional information.
	The Company included the results of operations of MHP for all periods presented, WHI Canada through May 12, 2014, and Eagle Ford Hunter through April 24, 2013, in discontinued operations as follows:
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
		(in thousands)
	Revenues	$	8,234		$	24,623		$	20,517		$	68,413
	Expenses	(4,345		)	(30,013		)	(13,178		)	(58,238		)
	Other income (expense)	—			1,893			(88		)	3,136
	Income tax expense	—			(4,187		)	—			(4,232		)
	Income (loss) from discontinued operations, net of tax	3,889			(7,684		)	7,251			9,079
	Income (loss) on sale of discontinued operations, net of taxes	(5,212		)	172,452			(32,374		)	172,452
	Income (loss) from discontinued operations, net of taxes	$	(1,323	)	$	164,768		$	(25,123	)	$	181,531
	Other Divestitures
	Sale of Certain Other Eagle Ford Shale Assets
	On January 28, 2014, the Company, through its wholly-owned subsidiary Shale Hunter LLC ("Shale Hunter") and certain other affiliates, closed on the sale of certain of its oil and natural gas properties and related assets located in the Eagle Ford Shale in South Texas to New Standard Energy Texas LLC ("NSE Texas"), a subsidiary of New Standard Energy Limited ("NSE"), an Australian Securities Exchange-listed Australian company.
	The assets sold consisted primarily of interests in leasehold acreage located in Atascosa County, Texas and working interests in five horizontal wells, of which four were operated by the Company. The effective date of the sale was December 1, 2013. As consideration for the assets sold, the Company received aggregate purchase price consideration of $15.5 million in cash, after customary purchase price adjustments, and 65,650,000 ordinary shares of NSE with a fair value of approximately $9.4 million at January 28, 2014 (based on the closing market price of $0.14 per share on January 28, 2014). These investment holdings represent approximately 17% of the total shares outstanding of NSE at January 28, 2014, and have been designated as available-for-sale securities, which are carried at fair value. The Company recognized a loss on the sale of the Shale Hunter assets of $4.5 million.
	In connection with the closing of the sale, Shale Hunter and NSE Texas entered into a transition services agreement which provides that, during a specified transition period ending on July 28, 2015 unless otherwise extended or modified, Shale Hunter will provide NSE Texas with certain transitional services relating to the assets sold for which it is receiving a monthly fee.
	Upon, and as a result of, the closing of the sale on January 28, 2014, the borrowing base under the Company’s asset-based, senior secured revolving credit facility was automatically reduced by $10.0 million to $232.5 million as of the closing date, but prior to the increase in the borrowing base discussed in "Note 10 - Debt".

OIL_NATURAL_GAS_SALES_Notes

OIL & NATURAL GAS SALES (Notes)	6 Months Ended
	Jun. 30, 2014
Other Income and Expenses [Abstract]	'
Oil & Natural Gas Sales	'
	NOTE 3 - OIL & NATURAL GAS SALES
	During the three and six months ended June 30, 2014 and 2013, the Company recognized sales from oil, natural gas, and natural gas liquids ("NGLs") as follows:
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
		(in thousands)
	Oil	$	39,839	$	33,122	$	74,111	$	58,694
	Natural gas	25,453		12,810		49,583		21,263
	NGLs	12,898		3,651		24,668		4,267
	Total oil and natural gas sales	$	78,190	$	49,583	$	148,362	$	84,224

PROPERTY_PLANT_EQUIPMENT_Notes

PROPERTY, PLANT, & EQUIPMENT (Notes)	6 Months Ended
	Jun. 30, 2014
Property, Plant and Equipment [Abstract]	'
Property, Plant, & Equipment	'
	NOTE 4 - 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:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Mineral interests in properties:
	Unproved leasehold costs	$	538,872		$	469,337
	Proved leasehold costs	334,918			336,357
	Wells and related equipment and facilities	615,998			536,023
	Advances to operators for wells in progress	20,740			13,571
	Total costs	1,510,528			1,355,288
	Less accumulated depletion, depreciation, and amortization	(181,827		)	(130,629		)
	Net capitalized costs	$	1,328,701		$	1,224,659
	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 property of $0.2 million and $10.0 million were recorded during each of the three and six months ended June 30, 2014 and 2013, respectively.
	Depletion, depreciation, and amortization expense for proved oil and natural gas properties was $30.1 million and $53.9 million for the three and six months ended June 30, 2014 and $21.5 million and $34.4 million for the three and six months ended June 30, 2013, respectively.
	Exploration
	Exploration expense consists primarily of abandonment charges and impairment expense for capitalized leasehold costs associated with unproved properties for which the Company has no further exploration or development plans, exploratory dry holes, and geological and geophysical costs.
	During the three and six months ended June 30, 2014 and 2013, the Company recognized exploration expense as follows:
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014		2013
		(in thousands)
	Leasehold impairments	$	8,834		$	3,272		$	22,489	$	32,625
	Geological and geophysical	353			274			727		654
	Total exploration expense	$	9,187		$	3,546		$	23,216	$	33,279
	Leasehold impairment expense recorded by the Company during the three and six months ended June 30, 2014 consisted of $8.8 million and $19.9 million, respectively, in the U.S. upstream segment related to leases in the Williston Basin and $2.6 million during the six months ended June 30, 2014 in the U.S. upstream segment related to leases in the Appalachian Basin. Leasehold impairment expense of $3.3 million and $32.6 million during the three and six months ended June 30, 2013 primarily related to leases in the Williston Basin. Impairments of leases in the Williston and Appalachian Basins for all periods presented related to leases that expired undrilled during the period or are expected to expire and that the Company does not plan to develop or extend.
	Capitalized Costs Greater Than a Year
	As of June 30, 2014, the Company had suspended exploratory well costs capitalized for periods greater than one year related to the Farley pad in Washington County, Ohio and the Farley #1305 H well. The Farley pad was constructed to drill multiple horizontal wells into a previously untested zone in the Utica formation. The Company spud the Farley #1305 H in April of 2013, and experienced well pressure instability during the fracture stimulation stage of completion. Further fracture stimulation and evaluation of this well will depend on the outcome of the drilling and completion of the Farley #1306 H and #1304 H wells, which were drilled in 2014 and are expected to be fracture stimulated and tested in early 2015 upon completion of a new natural gas pipeline. Aggregate cost incurred through June 30, 2014 for the Farley pad and the Farley #1305 H well were $1.1 million and $13.8 million, 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 June 30, 2014 and December 31, 2013 is summarized as follows:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Gas transportation, gathering and processing equipment and other	$	405,320		$	315,642
	Less accumulated depreciation	(35,996		)	(26,222		)
	Net capitalized costs	$	369,324		$	289,420
	Depreciation expense for gas transportation, gathering, and processing equipment and other property was $5.0 million and $9.6 million for the three and six months ended June 30, 2014, respectively, and $3.6 million and $6.8 million for the three and six months ended June 30, 2013, respectively.
	The Company sells and leases gas treating and processing equipment, classified as gas transportation, gathering, and processing equipment and other property and included in the table above, much of which is leased to third party operators for treating gas at the wellhead.  The leases generally have a term of three years or less.  The equipment under leases in place as of June 30, 2014 had a net carrying value of $11.9 million, and the terms of such leases provide for future lease payments to the Company extending up to August 2016.  As of June 30, 2014, primarily all the leases to third parties were non-cancelable, with future minimum aggregate base rentals payable to the Company of $3.4 million over the twelve months ending June 30, 2015 and $0.7 million, in the aggregate, thereafter.

INTANGIBLE_ASSETS_Notes

INTANGIBLE ASSETS (Notes)	6 Months Ended
	Jun. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Intangible Assets	'
	NOTE 5 - INTANGIBLE ASSETS
	Intangible assets consist primarily of gas gathering and processing contracts and customer relationships. The following table summarizes the Company's net intangible assets as of June 30, 2014 and December 31, 2013:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Customer relationships	$	5,434		$	5,434
	Trademark	859			859
	Existing contracts	4,199			4,199
	Total intangible assets	10,492			10,492
	Less: accumulated amortization	(4,965		)	(3,962		)
	Intangible assets, net of accumulated amortization	$	5,527		$	6,530
	Amortization expense for intangible assets was $502,000 and $1.0 million for the three and six months ended June 30, 2014 and $200,000 and $1.4 million for the three and six months ended June 30, 2013, respectively.
	The Company performed its annual impairment test of goodwill as of April 1, 2014. As a result of the Company's analysis no impairment of goodwill was indicated.

INVENTORY_Notes

INVENTORY (Notes)	6 Months Ended
	Jun. 30, 2014
Inventory Disclosure [Abstract]	'
Inventory	'
	NOTE 6 - INVENTORY
	The Company’s materials and supplies inventory is primarily comprised of frac sand used in the completion process of hydraulic fracturing. As of June 30, 2014 and December 31, 2013, the frac sand inventory is anticipated to be used in its entirety within the coming year, and is classified in current assets along with other inventory.
	The following table shows the composition of the Company's inventory as of:
		June 30,		December 31,
		2014		2013
		(in thousands)
	Materials and supplies	$	3,440	$	6,790
	Commodities	390		368
	Inventory	$	3,830	$	7,158

ASSET_RETIREMENT_OBLIGATIONS

ASSET RETIREMENT OBLIGATIONS	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
ASSET RETIREMENT OBLIGATIONS	'
	NOTE 7 - ASSET RETIREMENT OBLIGATIONS
	The following table summarizes the Company’s asset retirement obligation ("ARO") activities during the six-month period ended June 30, 2014 and for the year ended December 31, 2013:
		30-Jun-14			31-Dec-13
		(in thousands)
	Asset retirement obligation at beginning of period	$	16,216		$	30,680
	Assumed in acquisitions	—			17
	Liabilities incurred	216			253
	Liabilities settled	(21		)	(98		)
	Liabilities sold	(523		)	(7,614		)
	Accretion expense	751			2,264
	Revisions in estimated liabilities (1)	—			1,935
	Reclassified as liabilities associated with assets held for sale	—			(11,148		)
	Effect of foreign currency translation	—			(73		)
	Asset retirement obligation at end of period	16,639			16,216
	Less: current portion (included in other liabilities)	(71		)	(53		)
	Asset retirement obligation at end of period	$	16,568		$	16,163
	________________________________
	(1) $1.5 million of the revisions in estimated liabilities is related to change in assumptions used with respect to certain wells in the Williston Basin in North Dakota during 2013.

FAIR_VALUE_OF_FINANCIAL_INSTRU

FAIR VALUE OF FINANCIAL INSTRUMENTS	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
FAIR VALUE OF FINANCIAL INSTRUMENTS	'
	NOTE 8 - FAIR VALUE OF FINANCIAL INSTRUMENTS
	Accounting standards define 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.  The standards also establish 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 1 and 2 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 2014 and 2013. In January 2014, the Company acquired common shares of NSE in partial consideration of an asset sale. The significant inputs used in valuing the NSE common shares, which have a quoted market price in an active market, were designated as Level 1 as of June 30, 2014.
	The Company used the following fair value measurements for certain of the Company's assets and liabilities at June 30, 2014 and December 31, 2013:
	Level 1 Classification:
	Available for Sale Securities
	At June 30, 2014 and December 31, 2013, 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
	The Company does not designate its derivative instruments as hedges and therefore does not apply hedge accounting.  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. 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:
	Preferred Stock Embedded Derivative
	At June 30, 2014 and December 31, 2013, the Company had a preferred stock embedded derivative liability resulting from its Eureka Hunter Holdings Series A Preferred Units, which contain certain conversion features, redemption options, and other features.
	The fair value of the bifurcated conversion feature was valued using the "with and without" analysis in a simulation model based upon management's estimate of the expected life of the conversion feature. The key assumptions used in the model to determine fair value at June 30, 2014 were as follows:
		30-Jun-14
	Volatility	24		%
	Credit spread	10.5		%
	Expected term	1-2 years
	Total enterprise value (in millions)	$	608
	The selection of assumptions for expected term and total enterprise value were made based on a weighting of possible outcomes. The term of the conversion feature, which is linked to the terms of the Eureka Hunter Holdings Amended and Restated Limited Liability Company Agreement ("the Eureka Hunter Holdings LLC Agreement"), could range from zero to 6 years. The total enterprise value of Eureka Hunter Holdings is based upon a weighting of valuations ranging from $406 million to $1 billion based upon multiples of earnings before interest, taxes, depreciation, and amortization of comparable companies and precedent market transactions.
	The fair value calculation is sensitive to movements in volatility, estimated remaining term, and the total enterprise value of Eureka Hunter Holdings. A decrease in the estimated term of the conversion feature results in a higher fair value of the conversion feature. During the three-month period ended June 30, 2014, the Company changed the estimated term to 1-2 years due to changes in the Company's intention with respect to the Eureka Hunter Holdings Series A Preferred Units. As the implied volatility of the instruments increases so too does the fair value of the derivative liability arising from the conversion and redemption features. Similarly, as the total enterprise value of Eureka Hunter Holdings increases, the fair value of the derivative liability increases. Decreases in volatility and total enterprise value would result in a reduction to the fair value of the derivative liability associated with these instruments.
	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:
		30-Jun-14
	Life	2.6 years
	Risk-free interest rate	0.85		%
	Estimated volatility	40		%
	Dividend	—
	GreenHunter stock price at end of period	$	1.99
	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 the 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
		30-Jun-14
		(in thousands)
	Assets	Level 1				Level 2			Level 3
	Available for sale securities	$	10,661			$	—		$	—
	Commodity derivative assets	—				123			—
	Convertible security derivative assets	—				—			317
	Total assets at fair value	$	10,661			$	123		$	317
	Liabilities
	Commodity derivative liabilities	$	—			$	6,129		$	—
	Convertible preferred stock derivative liabilities	—				—			115,307
	Total liabilities at fair value	$	—			$	6,129		$	115,307
		Fair Value Measurements on a Recurring Basis
		31-Dec-13
		(in thousands)
	Assets	Level 1				Level 2			Level 3
	Available for sale securities	$	1,819			$	—		$	—
	Commodity derivative assets	—				554			—
	Convertible security derivative assets	—				—			79
	Total assets at fair value	$	1,819			$	554		$	79
	Liabilities
	Commodity derivative liabilities	$	—			$	2,279		$	—
	Convertible preferred stock derivative liabilities	—				—			75,934
	Total liabilities at fair value	$	—			$	2,279		$	75,934
	The following table presents a reconciliation of the financial derivative asset and liability measured at fair value using significant unobservable inputs (Level 3 inputs) for the six-month period ended June 30, 2014:
		Preferred Stock Embedded				Convertible Security Embedded
		Derivative Liability				Derivative Asset
		(in thousands)
Fair value as of December 31, 2013	$	(75,934	)		$	79
Issuance of redeemable preferred stock	(5,479		)		—
Increase in fair value recognized in gain (loss) on derivative contracts, net	(33,894		)		238
Fair value as of June 30, 2014	$	(115,307	)		$	317
As of June 30, 2014, the valuation of the conversion feature embedded in the Eureka Hunter Holdings Series A Preferred Units increased the fair value of the embedded derivative liability by approximately $33.9 million as a result of changes in the total enterprise value of Eureka Hunter Holdings and the Company's estimate of the expected remaining term of the conversion feature. Management's estimate of the expected remaining term of the conversion option as of June 30, 2014 shortened the time horizon previously estimated by management, resulting in higher fair value of the conversion feature. Management's estimates are based upon several factors, including an estimate of the likelihood of each of the possible settlement options, which include redemption through a call or put option, or a liquidity event that triggers conversion to Class A Common Units of Eureka Hunter Holdings.
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:
				30-Jun-14						31-Dec-13
		Fair Value Hierarchy		Carrying Amount			Estimated Fair Value			Carrying Amount		Estimated Fair Value
				(in thousands)
Senior Notes		Level 2		$	597,279		$	666,000		$	597,230	$	651,300
MHR Senior Revolving Credit Facility		Level 3		$	164,500		$	164,500		$	218,000	$	218,000
Eureka Hunter Pipeline second lien term loan		Level 3		$	—		$	—		$	50,000	$	58,921
Eureka Hunter Pipeline Credit Agreement		Level 3		$	65,000		$	65,000		$	—	$	—
Equipment Notes Payable		Level 3		$	24,395		$	24,303		$	18,615	$	17,676
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 similar assets in active markets).
The carrying values of the Company's senior revolving credit facility (the "MHR Senior Revolving Credit Facility") and the outstanding borrowings under the Eureka Hunter Pipeline Credit Agreement approximate fair value as they are subject to short-term floating interest rates that approximate the rates available to the Company for those periods.  The fair value hierarchy for the MHR Senior Revolving Credit Facility and the Eureka Hunter Pipeline Credit Agreement is Level 3.
The fair value of Eureka Hunter Pipeline's second lien term loan as of December 31, 2013 is the estimated cost to acquire the debt, including a credit spread for the difference between the issue rate and the period end market rate.  The credit spread is the Company’s default or repayment risk.  The credit spread (premium or discount) is determined by comparing the Company’s fixed-rate notes and credit facility to new issuances (secured and unsecured) and secondary trades of similar size and credit statistics for both public and private debt.
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. These 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.

FINANCIAL_INSTRUMENTS_AND_DERI

FINANCIAL INSTRUMENTS AND DERIVATIVES	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
FINANCIAL INSTRUMENTS AND DERIVATIVES	'
	NOTE 9 - FINANCIAL INSTRUMENTS AND DERIVATIVES
	Investment Holdings
	Below is a summary of changes in investments for the six months ended June 30, 2014:
		Available for Sale Securities (1)				Equity Method Investments (2)
		(in thousands)
	Carrying value as of December 31, 2013	$	1,819			$	940
	Securities received as consideration for assets sold	9,447				—
	Equity in net loss recognized in other income (expense)	—				(403		)
	Change in fair value recognized in other comprehensive loss	(605		)		—
	Carrying value as of June 30, 2014	$	10,661			$	537
	-1	Available for sale securities includes $123,000 that has been classified as held for sale associated with the classification of MHP as a discontinued operation.
	(2) Equity method investments includes $304,000 classified as long-term other assets.
	The Company's investments have been presented in the consolidated balance sheet as of June 30, 2014 as follows:
		Available for Sale Securities			Equity Method Investments			Total
	Investments - Current	$	10,538		$	233		$	10,771
	Investments - Long-Term	—			304			304
	Investments - Held for Sale	123			—			123
	Carrying value as of June 30,2014	$	10,661		$	537		$	11,198
	The cost for equity securities and their respective fair values as of June 30, 2014 and December 31, 2013 are as follows:
			June 30, 2014
			(in thousands)
			Cost				Gross Unrealized Gains				Gross Unrealized Losses				Fair Value
	Securities available for sale, carried at fair value:
	Equity securities		$	9,875			$	—			$	(1,404	)		$	8,471
	Equity securities - related party (see "Note 15 - Related Party Transactions")		2,200				—				(10		)		2,190
	Total Securities available for sale		$	12,075			$	—			$	(1,414	)		$	10,661
			December 31, 2013
			(in thousands)
			Cost				Gross Unrealized Gains				Gross Unrealized Losses				Fair Value
	Securities available for sale, carried at fair value:
	Equity securities		$	428			$	—			$	(281	)		$	147
	Equity securities - related party (see "Note 15 - Related Party Transactions")		2,200				—				(528		)		1,672
	Total Securities available for sale		$	2,628			$	—			$	(809	)		$	1,819
	The methods of determining the fair values of Magnum Hunter's investments in equity securities are described in "Note 8 - Fair Value of Financial Instruments".
	The Company's investment holdings 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. As of June 30, 2014 and December 31, 2013, 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 periods then ended.
	Commodity and Financial Derivative Instruments
	The Company periodically enters into certain commodity derivative instruments such as futures contracts, swaps, collars, and basis swap contracts, to mitigate commodity price risk associated with a portion of the Company's future monthly natural gas and crude oil production and related cash flows. The Company has not designated any commodity derivative instruments as hedges.
	In a commodities swap agreement, the Company trades the fluctuating market prices of oil or natural gas at specific delivery points over a specified period, for fixed prices. 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.  If the price of a commodity rises above what the Company has agreed to receive in the swap agreement, the amount that it agrees to pay the counterparty would theoretically be offset by the increased amount it received for its production.
	As of June 30, 2014, the Company had the following commodity derivative instruments:
					Weighted Average
	Natural Gas	Period	MMBtu/day		Price per MMBtu
	Collars (1)	July 2014- Dec 2014	15,000		$4.27 - $5.23
	Swaps	July 2014 - Dec 2014	31,000		$4.23
		Jan 2015 - Dec 2015	20,000		$4.18
	Ceilings purchased (call)	July 2014 - Dec 2014	16,000		$5.91
	Ceilings sold (call)	July 2014 - Dec 2014	16,000		$5.91
					Weighted Average
	Crude Oil	Period	Bbl/day		Price per Bbl
	Collars (1)	July 2014 - Dec 2014	663		$85.00 - $91.25
		Jan 2015 - Dec 2015	259		$85.00 - $91.25
	Traditional three-way collars (2)	July 2014 - Dec 2014	4,000		$64.94 - $85.00 - $102.50
	Ceilings sold (call)	Jan 2015 - Dec 2015	1,570		$120.00
	Floors sold (put)	July 2014 - Dec 2014	663		$65.00
		Jan 2015 - Dec 2015	259		$70.00
	________________________________
	(1) A collar is a sold call and a purchased put. Some collars are "costless" collars with the premiums netting to approximately zero.
	(2) These three-way collars are a combination of three options: a sold call, a purchased put and a sold put.
	Currently, Bank of America, Bank of Montreal, KeyBank National Association, Credit Suisse Energy, LLC, Citibank, N.A., ABN AMRO, the Royal Bank of Canada, and J. Aron & Company are the only counterparties to the Company's commodity derivatives positions.  The Company is exposed to credit losses in the event of nonperformance by the counterparties; however, it does not anticipate nonperformance by the counterparties over the term of the commodity derivatives positions.  All counterparties, or their affiliates, are participants in the MHR Senior Revolving Credit Facility, and the collateral for the outstanding borrowings under the MHR Senior Revolving Credit Facility is used as collateral for its commodity derivatives with those counterparties.
	At June 30, 2014, the Company had preferred stock derivative liabilities resulting from certain conversion features, redemption options, and other features of its Eureka Hunter Holdings Series A Preferred Units. See "Note 8 - Fair Value of Financial Instruments" and "Note 13 - Redeemable Preferred Stock".
	At June 30, 2014, 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 8 - Fair Value of Financial Instruments," "Note 2 - Divestitures and Discontinued Operations," and "Note 15 - Related Party Transactions".
	The following table summarizes the fair value of the Company's commodity and financial derivative contracts as of the dates indicated:
					Derivative Assets								Derivative Liabilities
Derivatives not designated as hedging instruments		Balance Sheet Classification		June 30, 2014				December 31, 2013				June 30, 2014				December 31, 2013
				(in thousands)
Commodity
		Derivative assets		$	—			$	529			$	—			$	—
		Derivative assets - long-term		123				25				—				—
		Derivative liabilities		—				—				(5,709		)		(1,903		)
		Derivative liabilities - long-term		—				—				(420		)		(376		)
Total commodity				$	123			$	554			$	(6,129	)		$	(2,279	)
Financial
		Derivative assets		$	317			$	79			$	—			$	—
		Derivative liabilities - long-term		—				—				(115,307		)		(75,934		)
Total financial				$	317			$	79			$	(115,307	)		$	(75,934	)
Total derivatives				$	440			$	633			$	(121,436	)		$	(78,213	)
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 in the Company's consolidated balance sheets as of:
	June 30, 2014
	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	$	565		565		$	—
Long-term assets:  Fair value of derivative contracts	239			116		123
Current liabilities:  Fair value of derivative contracts	(6,274		)	(565	)	(5,709		)
Long-term liabilities:  Fair value of derivative contracts	(536		)	(116	)	(420		)
	$	(6,006	)	—		$	(6,006	)
	December 31, 2013
	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	$	4,034		3,505		$	529
Long-term assets:  Fair value of derivative contracts	516			491		25
Current liabilities:  Fair value of derivative contracts	(5,408		)	(3,505	)	(1,903		)
Long-term liabilities:  Fair value of derivative contracts	(867		)	(491	)	(376		)
	$	(1,725	)	—		$	(1,725	)
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 six months ended June 30, 2014 and 2013:
	Three Months Ended June 30,								Six Months Ended
									June 30,
	2014				2013				2014				2013
	(in thousands)
Gain (loss) on settled transactions	$	(2,267	)		$	(1,261	)		$	(4,551	)		$	(305	)
Gain (loss) on open contracts	(40,569		)		7,661				(37,938		)		(786		)
Total gain (loss)	$	(42,836	)		$	6,400			$	(42,489	)		$	(1,091	)

LONGTERM_DEBT

LONG-TERM DEBT	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
LONG-TERM DEBT	'
	NOTE 10 - DEBT
	Long-term debt at June 30, 2014 and December 31, 2013 consisted of the following:
		June 30, 2014			December 31, 2013
		(in thousands)
	Senior Notes payable due May 15, 2020, interest rate of 9.75%, net of unamortized net discount of $2.7 million at June 30, 2014 and December 31, 2013	$	597,279		$	597,230
	Various equipment and real estate notes payable with maturity dates January 2015 - April 2021, interest rates of 4.25% - 7.94%(1)	24,395			18,615
	Eureka Hunter Pipeline Credit Agreement due March 28, 2018, interest rate of 3.66%	65,000			—
	Eureka Hunter Pipeline second lien term loan due August 16, 2018, interest rate of 12.5%	—			50,000
	MHR Senior Revolving Credit Facility due April 13, 2016, interest rate of 3.57% at June 30, 2014 and 3.56% at December 31, 2013	164,500			218,000
		851,174			883,845
	Less: current portion	(10,005		)	(3,967		)
	Total long-term debt obligations, net of current portion	$	841,169		$	879,878
	_________________________________
	(1)	Includes notes classified as liabilities associated with assets held for sale of which $4.6 million is current and $2.2 million is long-term at June 30, 2014, and $0.2 million is current and $3.8 million is long-term at December 31, 2013.
	The following table presents the scheduled or expected approximate annual maturities of debt, gross of unamortized discount of $2.7 million:
		(in thousands)
	2014	$	3,142
	2015	9,989
	2016	173,047
	2017	2,358
	2018	65,360
	Thereafter	600,000
	Total	$	853,896
	MHR Senior Revolving Credit Facility
	On December 13, 2013, the Company entered into a Third Amended and Restated Credit Agreement (the "Credit Agreement") by and among the Company, Bank of Montreal, as Administrative Agent, the lenders party thereto and the agents party thereto. The Credit Agreement amended and restated that certain Second Amended and Restated Credit Agreement, dated as of April 13, 2011, by and among such parties, as amended (the "Prior Credit Agreement"). The terms of the Credit Agreement are substantially similar to the Prior Credit Agreement.
	On May 6, 2014, the Company and the other parties to the Credit Agreement entered into the First Amendment to Third Amended and Restated Credit Agreement (the "Amendment"). The Amendment increased the borrowing base from $232.5 million to $325.0 million in connection with the regular semi-annual redetermination of the Company's borrowing base derived from the Company's proved crude oil and natural gas reserves. The borrowing base may be increased or decreased in connection with such redeterminations up to a maximum commitment level of $750.0 million. The Amendment provides that such increased borrowing base shall be reduced (i) by the lesser of $25.0 million or 50% of the net proceeds from issuances by the Company of common equity on or before July 1, 2014 (other than common equity issued pursuant to any stock incentive or stock option plan or any other compensatory arrangements); (ii) by certain specified reductions in connection with certain proposed asset dispositions; (iii) on July 1, 2014 by $25.0 million less any prior adjustment of the borrowing base due to an equity issuance as contemplated by clause (i); and (iv) by $0.25 for each $1.00 of any additional Senior Notes issued by the Company. The Amendment further provides that from May 6, 2014 through July 1, 2014 the Applicable Margin (as defined in the Credit Agreement) component of the interest charged on revolving borrowings under the Credit Agreement shall be 2.75% for ABR Loans (as defined in the Credit Agreement) and 3.75% for Eurodollar Loans (as defined in the Credit Agreement). From and after July 1, 2014 through the date of the Company’s delivery of a certificate for the quarter ended June 30, 2014, with respect to, among other things, the Company’s compliance with the covenants in the Credit Agreement (the "Compliance Certificate"), the Applicable Margin component of interest charged on revolving borrowings under the Credit Agreement will range from 1.50% to 2.25% for ABR Loans and from 2.50% to 3.25% for Eurodollar Loans. From and after the Company’s delivery of the Compliance Certificate, the Applicable Margin component of interest charged on revolving borrowings under the Credit Agreement will range from 1.00% to 1.75% for ABR Loans and from 2.00% to 2.75% for Eurodollar Loans.
	In addition, the Amendment modified certain of the Credit Agreement’s financial covenants, including:
	(i)	permitting the Company to take into account the borrowing base increase as though it occurred on March 31, 2014 for purposes of maintaining a ratio of consolidated current assets to consolidated current liabilities of not less than 1.0 to 1.0;
	(ii)	providing for a ratio of EBITDAX to Interest Expense of not less than (A) 2.00 to 1.0 for the fiscal quarter ended March 31, 2014, (B) 2.25 to 1.0 for the fiscal quarters ending June 30, 2014 and September 30, 2014, and (C) 2.50 to 1.0 for the fiscal quarter ending December 31, 2014 and for each fiscal quarter ending thereafter; and
	(iii)	beginning with the fiscal quarter ended June 30, 2014, providing for a ratio of total Debt to EBITDAX of not more than (A) 4.75 to 1.0 for the fiscal quarters ending June 30, 2014 and September 30, 2014, (B) 4.50 to 1.0 for the fiscal quarter ending December 31, 2014, and (C) 4.25 to 1.0 for the fiscal quarter ending March 31, 2015 and for each fiscal quarter ending thereafter.
	The Amendment also (i) amends the definition of EBITDAX and provides that certain acquisitions and dispositions be given pro forma effect in the calculation of EBITDAX; (ii) increases the letter of credit commitment from $10.0 million to $50.0 million and provides that outstanding letter of credit exposure not be included in certain determinations of Debt; (iii) requires the total value of the Company’s oil and gas properties included in the reserve reports for the borrowing base determinations in which the lenders under the Credit Agreement have perfected liens be increased from 80% to 90%; and (iv) modifies certain covenants in the Credit Agreement with respect to permitted investments by the Company to increase flexibility.
	The Company incurred direct financing costs associated with entering into the Amendment to the Credit Agreement in the amount of $3.1 million, which will be deferred and amortized over the remaining term of the Credit Agreement.
	As of June 30, 2014, the borrowing base under this facility was $272.5 million, and $164.5 million of borrowings were outstanding ($218.0 million outstanding as of December 31, 2013). The borrowing base as of June 30, 2014 reflects reductions in the borrowing base of $25 million and $27.5 million related to the issuance of equity and the sale of our 100% equity interest in WHI Canada, respectively, both of which closed in May 2014. The borrowing base is subject to further automatic reductions upon the issuance of additional Senior Notes and in certain other circumstances.
	At June 30, 2014, the Company was in compliance with all of its covenants, as amended, contained in the MHR Senior Revolving Credit Facility.
	Eureka Hunter Pipeline Credit Agreement
	On March 28, 2014, Eureka Hunter Pipeline entered into a credit agreement (the "Eureka Hunter Pipeline Credit Agreement"), by and among Eureka Hunter Pipeline, as borrower, ABN AMRO Capital USA, LLC, as a lender and as administrative agent, and the other lenders party thereto.
	The credit agreement, which has a maturity date of March 28, 2018, provides for a revolving credit facility in an aggregate principal amount of up to $117.0 million (with the potential to increase the aggregate commitment under the credit agreement to an aggregate principal amount of up to $150.0 million, subject to the consent of the lender parties and the satisfaction of certain conditions), secured by a first lien on substantially all of the assets of Eureka Hunter Pipeline and its subsidiaries, which include TransTex Hunter, LLC, as well as by Eureka Hunter Pipeline’s pledge of the equity in its subsidiaries. The subsidiaries of Eureka Hunter Pipeline also guarantee Eureka Hunter Pipeline’s obligations under the credit agreement. The credit agreement is non-recourse to Magnum Hunter. The Company incurred deferred financing costs directly associated with entering into the Eureka Hunter Pipeline Credit Agreement in the amount of $1.2 million which will be amortized straight-line over the term of the revolving credit facility. The straight-line method of amortization results in substantially the same periodic amortization as the effective interest method.
	The terms of the credit agreement provide that the borrowings thereunder may be used, among other specified purposes, (1) to refinance existing indebtedness of Eureka Hunter Pipeline outstanding on the credit agreement closing date, including the term loan of $50.0 million in principal amount owed under the Second Lien Term Loan Agreement, dated August 16, 2011, by and among Eureka Hunter Pipeline and Pennant Park Investment Corporation, as a lender, the other lenders party thereto and U.S. Bank National Association, as collateral agent, (2) to finance future expansion activities related to Eureka Hunter Pipeline’s gathering system in West Virginia and Ohio, (3) to finance acquisitions by Eureka Hunter Pipeline and its subsidiaries permitted under the terms of the credit agreement, (4) to refinance from time to time certain letters of credit of Eureka Hunter Pipeline and its subsidiaries, (5) to provide working capital for their operations, and (6) for their other general business purposes.
	The Eureka Hunter Pipeline Credit Agreement provides for a commitment fee based on the unused portion of the commitment under the credit agreement of 0.50% per annum when the consolidated leverage ratio is greater than or equal to 3.0 to 1.0 and a commitment fee of 0.375% when the consolidated leverage ratio is less than 3.0 to 1.0.
	In general terms, borrowings under the credit agreement will, at Eureka Hunter Pipeline’s election, bear interest:
	•	on base rate loans, at the per annum rate equal to the sum of (A) the base rate (defined as the highest of (i) the per annum rate of interest established by JPMorgan Chase Bank, N.A. as its prime rate for U.S. dollar loans, (ii) the Adjusted Eurodollar Rate (as defined in the credit agreement) for an interest period of one-month, plus 1.0%, or (iii) the federal funds rate, plus 0.50% per annum), and (B) a margin of 1.0% to 2.50% per annum; or
	•	on Eurodollar Loans, at the per annum rate equal to the sum of (A) the Eurodollar Rate (as defined in the credit agreement) adjusted for certain statutory reserve requirements for Eurocurrency liabilities, and (B) a margin of 2.0% to 3.50% per annum.
	If an event of default occurs under the credit agreement, generally, the applicable lenders may increase the interest rate then in effect by an additional 2.0% per annum for the period that the default exists.
	The credit agreement contains customary affirmative covenants and negative covenants that, among other things, restrict the ability of each of Eureka Hunter Pipeline and its subsidiaries to, with certain exceptions: (1) incur indebtedness; (2) grant liens; (3) enter into hedging transactions; (4) enter into a merger or consolidation or sell, lease, transfer or otherwise dispose of all or substantially all of its assets or the stock of any of its subsidiaries; (5) issue equity; (6) dispose of any material assets or properties; (7) pay or declare dividends or make certain distributions; (8) invest in, extend credit to or make advances or loans to any person or entity; (9) engage in material transactions with any affiliate; (10) enter into any agreement that restricts or imposes any condition upon the ability of (a) any of Eureka Hunter Pipeline or its subsidiaries to create, incur or permit any lien upon any of its assets or properties, or (b) any such subsidiary to pay dividends or other distributions, to make or repay loans or advances, to guarantee indebtedness or to transfer any of its property or assets to Eureka Hunter Pipeline or its subsidiaries; (11) change the nature of its business; (12) amend its organizational documents or material agreements; (13) change its fiscal year; (14) enter into sale and leaseback transactions; (15) make acquisitions; (16) make certain capital expenditures; or (17) take any action that could result in regulation as a utility.
	The credit agreement requires Eureka Hunter Pipeline to satisfy certain financial covenants, including maintaining:
	•	a maximum leverage ratio (defined as the ratio of (i) consolidated funded debt to (ii) annualized consolidated EBITDA), as of the end of each fiscal quarter, not greater than (A) 4.75 to 1.00 for the fiscal quarters ending March 31, 2014 through September 30, 2014, and (B) 4.50 to 1.00 for the fiscal quarter ending December 31, 2014 and each fiscal quarter ending thereafter; and
	•	a minimum interest coverage ratio (defined as the ratio of (i) annualized consolidated EBITDA to (ii) annualized consolidated interest charges for such period), as of the end of each fiscal quarter, not less than (A) 2.75 to 1.00 for the fiscal quarters ending March 31, 2014 through September 30, 2014, and (B) 2.50 to 1.00 for the fiscal quarter ending December 31, 2014 and each fiscal quarter ending thereafter.
	The obligations of Eureka Hunter Pipeline under the credit agreement may be accelerated upon the occurrence of an event of default. Events of default include customary events for these types of financings, including, among other things, payment defaults, defaults in the performance of affirmative or negative covenants, the inaccuracy of representations or warranties, material defaults under or termination of certain material contracts, defaults relating to judgments, certain bankruptcy proceedings, a change in control and any material adverse change.
	As of June 30, 2014 the maximum amount available under the credit agreement was $72.2 million, and the Company had $65.0 million in borrowings outstanding. The borrowing capacity is subject to certain upward or downward reductions during the term of the credit agreement.
	As of June 30, 2014, Eureka Hunter Pipeline was in compliance with all of its covenants contained in the Eureka Hunter Pipeline Credit Agreement.
	Eureka Hunter Pipeline Credit Facilities
	Upon executing the new Eureka Hunter Pipeline Credit Agreement on March 28, 2014, Eureka Hunter Pipeline terminated its revolving credit agreement with SunTrust Bank and the term loan agreement with Pennant Park (the "Original Eureka Hunter Credit Facilities"). Eureka Hunter Pipeline used proceeds from the Eureka Hunter Pipeline Credit Agreement to pay in full all outstanding obligations related to the termination of the Original Eureka Hunter Credit Facilities, which included the principal outstanding amount of $50.0 million, a prepayment penalty of $2.2 million, and accrued, unpaid interest of $1.5 million.
	Equipment Note Payable
	On January 21, 2014, the Company's wholly owned subsidiary, Alpha Hunter Drilling, LLC, entered into a master loan and security agreement with CIT Finance LLC to borrow $5.6 million at an interest rate of 7.94% over a term of forty-eight months. The note is collateralized by field equipment, and the Company is a guarantor on the note.
	Interest Expense
	The following table sets forth interest expense for the three and six month periods ended June 30, 2014 and 2013, respectively:
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014		2013
		(in thousands)
	Interest expense incurred on debt, net of amounts capitalized	$	16,412		$	17,100		$	36,640	$	34,944
	Amortization and write-off of deferred financing costs	4,022			1,693			7,643		2,550
	Total Interest Expense	$	20,434		$	18,793		$	44,283	$	37,494
The Company capitalizes interest on expenditures for significant construction projects that last more than six months while activities are in progress to bring the assets to their intended use. The Company capitalized interest on its Eureka Hunter Gas Gathering System of $219,000 and $830,000 during the three and six months ended June 30, 2014, respectively, and $573,000 and $1.4 million during the three and six months ended June 30, 2013, respectively.
For the six-month period ended June 30, 2014, interest expense incurred on debt includes a $2.2 million prepayment penalty incurred by Eureka Hunter Pipeline as a result of its early termination of the Original Eureka Hunter Credit Facilities on March 28, 2014, which penalty represents an additional cost of borrowing for a period shorter than contractual maturity. In addition, amortization and write-off of deferred financing costs for the six-month period ended June 30, 2014 includes the write-off of $2.7 million in unamortized deferred financing costs related to those terminated agreements, which costs were expensed at the time of early extinguishment and $1.7 million in unamortized deferred financing costs related to the Amendment of the MHR Senior Revolving Credit Facility.

SHAREBASED_COMPENSATION

SHARE-BASED COMPENSATION	6 Months Ended
	Jun. 30, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]	'
SHARE-BASED COMPENSATION	'
	NOTE 11 - SHARE-BASED COMPENSATION
	Under the Company's Amended and Restated Stock Incentive Plan, the Company may grant unrestricted common stock, restricted common stock, common stock options, and stock appreciation rights to directors, officers, employees and other persons who contribute to the success of Magnum Hunter.  Currently, 27,500,000 shares of the Company's common stock are authorized to be issued under the plan, and 9,610,873 shares had been issued under the plan as of June 30, 2014.
	The Company recognized share-based compensation expense of $2.3 million and $3.4 million for the three and six months ended June 30, 2014, respectively, and $2.4 million and $8.7 million for the three and six months ended June 30, 2013, respectively.
	A summary of common stock option activity for the six months ended June 30, 2014 and 2013 is presented below:
		Six Months Ended June 30,
		2014		2013		2014		2013
		(in thousands of shares)				Weighted Average Exercise Price per Share
	Outstanding at beginning of period	16,891		14,847		$	5.69	$	6.01
	Granted	—		4,363		$	—	$	4.16
	Exercised	(2,115	)	—		$	4.14	$	—
	Forfeited	(932	)	(413	)	$	6.32	$	6.61
	Outstanding at end of period	13,844		18,797		$	5.88	$	5.56
	Exercisable at end of period	9,478		11,139		$	6.2	$	5.72
	A summary of the Company’s non-vested common stock options and stock appreciation rights for the six months ended June 30, 2014 and 2013 is presented below:
		Six Months Ended June 30,
		2014		2013
		(in thousands of shares)
	Non-vested at beginning of period	6,908		6,163
	Granted	—		4,363
	Vested	(1,801	)	(2,677	)
	Forfeited	(741	)	(191	)
	Non-vested at end of period	4,366		7,658
	Total unrecognized compensation cost related to the non-vested common stock options was $6.3 million and $14.3 million as of June 30, 2014 and 2013, respectively.  The unrecognized compensation cost at June 30, 2014 is expected to be recognized over a weighted-average period of 1.3 years. At June 30, 2014, the weighted average remaining contract life of outstanding options was 5.8 years.
	During the six months ended June 30, 2014, the Company granted 1,352,575 restricted shares of common stock to officers, executives, and employees of the Company which vest over a 3-year period with 33% of the restricted shares vesting one year from the date of the grant. The Company also granted 123,798 restricted shares to the directors of the Company which vest 100% one year from the date of the grant. The shares had a fair value at the time of grant of $10.8 million based on the stock price on grant date and estimated forfeiture rate of 3.4%.
	Total unrecognized compensation cost related to non-vested, restricted shares amounted to $8.3 million and $165,000 as of June 30, 2014 and 2013, respectively.  The unrecognized cost at June 30, 2014, is expected to be recognized over a weighted-average period of 2.4 years.
	Eureka Hunter Holdings, LLC Management Incentive Compensation Plan
	On May 12, 2014, the Board of Directors of Eureka Hunter Holdings approved the Eureka Hunter Holdings, LLC Management Incentive Compensation Plan ("Eureka Hunter Holdings Plan") to provide long-term incentive compensation to attract and retain officers and employees of Eureka Hunter Holdings and its subsidiaries and allow such individuals to participate in the economic success of Eureka Hunter Holdings and its subsidiaries.
	The Eureka Hunter Holdings Plan consists of (i) 2,336,905 Class B Common Units representing membership interests in Eureka Hunter Holdings ("Class B Common Units"), and (ii) 2,336,905 Incentive Plan Units issuable pursuant to a management incentive compensation plan, which represent the right to receive a dollar value up to the baseline value of a corresponding Class B Common Unit ("Incentive Plan Units"). The Eureka Hunter Holdings Plan is administered by the Board of Directors of Eureka Hunter Holdings, and, as administrator of the Eureka Hunter Holdings Plan, the board will from time to time make awards under the Eureka Hunter Holdings Plan to selected officers and employees of Eureka Hunter Holdings or its affiliates ("Award Recipients").
	The Class B Common Units are profits interest awards that carry the right to share in the appreciation in the value of the aggregate common equity in Eureka Hunter Holdings over and above a baseline value that is determined on the date of grant of the Class B Common Units. The Class B Common Units vest in five substantially equal annual installments on each of the first five anniversaries of the date of grant, subject to the Award Recipient's continued employment, and automatically vest in full upon the occurrence of a liquidity event (as defined in the Eureka Hunter Holdings Plan) (including if the Award Recipient's employment is terminated by Eureka Hunter Holdings or an affiliate without cause or due to the Award Recipient's death or disability, in each case, within six months prior to the occurrence of a liquidity event). Subject to the Award Recipient's continued employment, the Incentive Plan Units become fully vested upon the occurrence of a liquidity event (including if the Award Recipient's employment is terminated by Eureka Hunter Holdings or an affiliate without cause or due to the Award Recipient's death or disability, in each case, within six months prior to the occurrence of a liquidity event).
	If an Award Recipient’s employment is terminated under any other circumstances, all unvested Class B Common Units and Incentive Plan Units will be forfeited immediately upon the Award Recipient’s termination of employment. In addition, vested Class B Common Units will be forfeited if an Award Recipient’s employment is terminated prior to the occurrence of a liquidity event by Eureka Hunter Holdings or an affiliate for cause or due to the Award Recipient’s resignation. If, following a termination of his or her employment by Eureka Hunter Holdings or an affiliate without cause or due to the Award Recipient’s death or disability, an Award Recipient retains vested Class B Common Units, Eureka Hunter Holdings will have the right, but not the obligation, to repurchase such vested Class B Common Units at fair market value.
	Distributions, if any, with respect to the Class B Common Units issued pursuant to the Class B Common Unit Agreement will be made in accordance with, and subject to, the Eureka Hunter Holdings LLC Agreement, provided, that, no distributions shall be made with respect to any vested or unvested Class B Common Units unless and until a liquidity event has occurred (other than tax distributions that may be made in accordance with the Eureka Hunter Holdings LLC Agreement). Payment in respect of vested Class B Common Units and Incentive Plan Units will become due upon the occurrence of a liquidity event and are expected to be settled in cash upon the occurrence of a liquidity event, except in the case of a qualified public offering (as defined in the Eureka Hunter Holdings Plan), in which case settlement will occur partially in cash and partially in shares of the resulting public entity, with the cash portion not to exceed the amount necessary to cover minimum statutory tax withholdings.
	Upon approval of the plan on May 12, 2014, the Board of Directors of Eureka Hunter Holdings granted 894,102 Class B Common Units and 894,102 Incentive Plan Units to key employees of Eureka Hunter Holdings and its subsidiaries. The Class B Common Units and Incentive Plan Units are accounted for in accordance with ASC 718, Compensation - Stock Compensation. In accordance with ASC 718, compensation cost is accrued when the performance condition (i.e. the liquidity event) is probable of being achieved. As of June 30, 2014, a liquidity event, as defined, was not probable, and therefore, no compensation cost had been recognized.

SHAREHOLDERS_EQUITY

SHAREHOLDERS’ EQUITY	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
SHAREHOLDERS’ EQUITY	'
	NOTE 12 - SHAREHOLDERS' EQUITY
	Common Stock
	During the six months ended June 30, 2014, the Company:
	i)	issued 47,426 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;
	ii)	issued 2,115,000 shares of the Company’s common stock upon exercise of fully vested stock options.
	iii)	issued 4,300,000 shares of the Company's common stock in March 2014 in a private placement at a price of $7.00 per share, with net proceeds to the Company of $28.9 million after deducting sales agent commissions and other issuance costs. The Company subsequently filed a Form S-1 Registration Statement with the Securities and Exchange Commission (the "SEC") which was declared effective on July 23, 2014 to register the resale of these shares by the holders thereof to satisfy the Company's registration obligations under the private placement.
	iv)	issued 21,428,580 shares of the Company's common stock in May 2014 in a private placement at a price of $7.00 per share, with net proceeds to the Company of $149.7 million after deducting issuance costs. The Company subsequently filed a Form S-1 Registration Statement with the SEC to register the resale of these shares by the holders thereof to satisfy the Company's registration obligations under the private placement.
	Common Stock Warrants
	The Company issued 2,142,858 warrants to purchase common stock with an exercise price of $8.50 per share, subject to certain anti-dilution adjustments, in conjunction with the May 2014 private placement sales of common stock. The warrants became exercisable beginning on May 29, 2014, and will expire on April 15, 2016. The warrants are subject to redemption at the option of the Company at $0.001 per warrant upon not less than thirty days' notice to the holders, only if the Company also redeems the warrants it previously issued pursuant to that certain Warrants Agreement, dated October 15, 2013, by and between the Company and American Stock Transfer & Trust Company, Inc. The warrants were issued in connection with the May 2014 sale of 21,428,580 common shares, and the proceeds for the sale of the common shares and the warrants have been reflected in the Company's capital accounts as increases to common stock and additional paid in capital.
	Preferred Dividends Incurred
	A summary of the Company's preferred dividends for the three and six months ended June 30, 2014 and 2013 is presented below:
		Three Months Ended June 30,					Six Months Ended June 30,
		2014			2013		2014		2013
		(in thousands)					(in thousands)
	Dividend on Eureka Hunter Holdings Series A Preferred Units	$	4,253		$	3,556	$	8,281	$	6,670
	Accretion of the carrying value of the Eureka Hunter Holdings Series A Preferred Units	2,229			1,696		4,277		3,164
	Dividend on Series C Preferred Stock	2,562			2,562		5,124		5,124
	Dividend on Series D Preferred Stock	4,425			4,425		8,849		8,807
	Dividend on Series E Preferred Stock	1,861			1,890		3,695		3,852
	Total dividends on Preferred Stock	$	15,330		$	14,129	$	30,226	$	27,617
	Net Income or 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 June 30, 2014 and 2013:
		June 30,
		2014		2013
		(in thousands of shares)
	Series E Preferred Stock	10,946		11,169
	Warrants	19,214		13,376
	Unvested restricted shares	1,475		—
	Common stock options and stock appreciation rights	13,844		18,797
	Total	45,479		43,342

REDEEMABLE_PREFERRED_STOCK

REDEEMABLE PREFERRED STOCK	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
REDEEMABLE PREFERRED STOCK	'
	NOTE 13 - 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"), an affiliate of ArcLight Capital Partners, LLC ("ArcLight"). Pursuant to this Unit Purchase Agreement, Ridgeline committed, subject to certain conditions, to purchase up to $200.0 million of Eureka Hunter Holdings Series A Preferred Units, representing membership interests of Eureka Hunter Holdings, of which $200.0 million had been purchased as of June 30, 2014.
	During the six months ended June 30, 2014, Eureka Hunter Holdings issued 610,000 Eureka Hunter Holdings Series A Preferred Units to Ridgeline for net proceeds of $12.0 million, net of transaction costs. The Eureka Hunter Holdings Series A Preferred Units outstanding at June 30, 2014 represented 41.8% of the ownership of Eureka Hunter Holdings on a basis as converted to Class A Common Units of Eureka Hunter Holdings.
	During the six months ended June 30, 2014, Eureka Hunter Holdings issued 97,492 Eureka Hunter Holdings Series A Preferred Units as payment of $1.9 million in distributions paid-in-kind to holders of the Series A Preferred Units. The fair value of the embedded derivative feature of the outstanding Eureka Hunter Holdings Series A Preferred Units was determined to be $115.3 million at June 30, 2014.
	Dividend expense included accretion of the Eureka Hunter Holdings Series A Preferred Units of $2.2 million and $4.3 million for the three and six months ended June 30, 2014, and $1.7 million and $3.2 million for the three and six months ended June 30, 2013, respectively.

TAXES

TAXES	6 Months Ended
	Jun. 30, 2014
Income Tax Disclosure [Abstract]	'
Taxes	'
	NOTE 14 - TAXES
	The Company's income tax benefit from continuing operations for the three and six months ended June 30, 2014 and 2013 was:
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
		(in thousands)
	Deferred	$	—	$	39,300	$	—	$	44,199
	Income tax benefit	$	—	$	39,300	$	—	$	44,199
	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 carryforwards. 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 June 30, 2014, 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	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
RELATED PARTY TRANSACTIONS	'
	NOTE 15 - RELATED PARTY TRANSACTIONS
	The following table sets forth the related party balances as of June 30, 2014 and December 31, 2013:
		June 30, 2014			December 31, 2013
		(in thousands)
	Green Hunter (1)
	Accounts payable - net	$	690		$	23
	Derivative assets (2)	$	317		$	79
	Investments (2)	$	2,423		$	2,262
	Notes receivable (2)	$	1,496		$	1,768
	Prepaid expenses	$	—		$	9
	The Company holds investments in a related party consisting of 1,846,722 shares of common stock of GreenHunter with a carrying value of $232,896 as of June 30, 2014 and 88,000 shares of Series C preferred stock of GreenHunter with a carrying value of $2.2 million as of June 30, 2014.
	The following table sets forth the related party transaction activities for the three and six months ended June 30, 2014 and 2013, respectively:
			Three Months Ended						Six Months Ended
			June 30,						June 30,
			2014			2013			2014		2013
			(in thousands)
	GreenHunter
		Salt water disposal (1)	$	613		$	590		$	935	$	1,446
		Equipment rental (1)	19			98			141		73
		Gas gathering-trucking (1)	400			—			400		—
		MAG tank panels (1)	800			—			800		—
		Office space rental	13			—			36		—
		Interest income from note receivable (2)	38			53			83		108
		Dividends earned from Series C shares	55			37			110		92
		Unrealized gain/(loss) on investments (2)	396			(151		)	161		(677		)
	Pilatus Hunter, LLC
		Airplane rental expenses (3)	88			20			158		67
	_________________________________
	-1	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman, a major shareholder and interim CEO. Eagle Ford Hunter received, and 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 its affiliated companies, White Top Oilfield Construction, LLC and Black Water Services, LLC. 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 8 - 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 other long-term assets and an available for sale investment in GreenHunter included in investments.
	-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.
	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.
	Mr. Evans, the Company's Chairman and Chief Executive Officer, holds 27,641 Class A Common Units of Eureka Hunter Holdings.

COMMITMENTS_AND_CONTINGENCIES

COMMITMENTS AND CONTINGENCIES	6 Months Ended
	Jun. 30, 2014
Commitments and Contingencies Disclosure [Abstract]	'
COMMITMENTS AND CONTINGENCIES	'
	NOTE 16 - COMMITMENTS AND CONTINGENCIES
	Agreement to Purchase Utica Shale Acreage
	On August 12, 2013, Triad Hunter entered into an asset 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 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 December 30, 2013, a lawsuit was filed against the Company, Triad Hunter, MNW and others by Dux Petroleum, LLC ("Dux")asserting certain claims relating to the acreage covered by the asset purchase agreement with MNW. As a result of the litigation, no purchases were made during the first quarter of 2014. On May 28, 2014, the litigation was settled. As part of the settlement, the Company and Triad Hunter agreed to collectively pay Dux the aggregate amount of $500,000. Subsequent to the settlement of the lawsuit, Triad Hunter resumed closings of lease acquisitions from MNW. On June 5, 2014, Triad Hunter closed on the acquisition of 11,128 net leasehold acres for $45.9 million from MNW. To date, under the asset purchase agreement, Triad Hunter has now acquired a total of approximately 17,000 net leasehold acres from MNW, or approximately 53% of the approximately 32,000 total net leasehold acres anticipated under the asset purchase agreement.
	Ormet Asset Acquisition
	On June 18, 2014, the Company entered into an Asset Purchase Agreement ("Ormet Asset Purchase Agreement) with Ormet Corporation for the purchase of certain mineral interests in approximately 1,700 net acres, consisting of 1,375 net acres in Monroe County, Ohio and 325 net acres in Wetzel County, West Virginia. Prior to the execution of the Ormet Asset Purchase Agreement, the Company held leasehold interests in a portion of the subject acreage, which only included leasehold rights to the Marcellus zone, and carried a 12.5% royalty on production to Ormet Corporation. On July 24, 2014, the Company closed on the purchase of the sub-surface mineral interests, including any royalty interests, in the underlying acreage, giving the Company 100% ownership of and rights to oil, natural gas, and other minerals located in or under and that may be produced from the property, at any depth. The total purchase price for this transaction was approximately $22.7 million, for which the Company had previously made a deposit of $2.5 million as of June 30, 2014.
	Takeover Bid
	On June 20, 2014, the Company lodged a Bidder’s Statement with the Australian Securities and Investments Commission, through its wholly owned subsidiary, Outback Shale Hunter Pty Ltd, an Australian company, to commence an off-market takeover offer (the "Offer") for Ambassador Oil and Gas Limited, an Australian company listed on the Australian Securities Exchange ("ASX") (ASX: AQO) ("Ambassador").  Pursuant to the Offer, the Company is offering one share of its common stock, par value $0.01 per share, for every 23.6 ordinary (or common) shares of Ambassador. Based on the closing price of the Company’s common stock on the New York Stock Exchange of $8.20 on June 30, 2014 (and the Australian dollar/U.S. dollar exchange rate on that date), the implied value under the Offer was A$0.369 per Ambassador ordinary share.  If the Company acquires all of the Ambassador ordinary shares under the Offer, and if all of the Ambassador shareholders elect to receive shares of Company common stock, the Company will issue approximately 6,019,427 shares of its common stock at an aggregate implied value of approximately $49.4 million based on the closing price of the Company’s common stock on June 30, 2014. The Company's Offer is subject to a competing offer for Ambassador made by an Australian company listed on ASX.
	Settlement Agreement with Seminole Energy Services
	On January 10, 2014, the Company and certain of its subsidiaries entered into an Omnibus Settlement Agreement and Release (the "Settlement Agreement") dated January 9, 2014 with Seminole Energy Services, LLC and certain of its affiliates (collectively, "Seminole"). In connection with and pursuant to the terms of the Settlement Agreement, the Company and Seminole agreed to release and discharge each other from all claims and causes of action alleged in, arising from or related to certain legal proceedings and to terminate, amend and enter into certain new, related agreements effective immediately prior to year-end on December 31, 2013 (the "New Agreements").
	By entering into the New Agreements, the Company and Seminole restructured their existing agreements. The Company obtained a reduction in gas gathering rates it pays for natural gas owned or controlled by the Company that is gathered on the Stone Mountain Gathering System. The Company and Seminole collectively agreed to construct an enhancement of the Rogersville Plant designed to recover less ethane and more propane from the natural gas processed at the Rogersville Plant. The parties also agreed to reduce and extend the Company's contractual horizontal well drilling obligations owed to Seminole. The Company's drilling obligation to Seminole, which required the Company to drill and complete four wells in southern Appalachia, expired on June 30, 2014, and, pursuant to the Settlement Agreement, the Company paid Seminole $450,000 as a result of the Company's decision not to drill two out of the required four wells.
	The Company and Seminole also agreed to modify the natural gas processing rates the Company will pay for processing at the Rogersville Plant, the Company's allocation of natural gas liquids ("NGL") recovered from gas processed and the costs of blend stock necessary to blend with the NGL produced from the Rogersville Plant, and certain deductions to the NGL purchase price the Company will pay Seminole for the Company's NGL produced from the Rogersville Plant. Seminole sold to the Company Seminole's 50% interest in a natural gas gathering trunk line and treatment facility located in southwestern Muhlenberg County, Kentucky, which had previously been owned equally by Seminole and the Company.
	Drilling Rig Purchase
	During June 2014, the Company, through its 100% owned subsidiary, Alpha Hunter Drilling, LLC, signed 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 on January 15, 2015.
	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 have appealed the decision to the U.S. Court of Appeals for the Second Circuit, which the Company intends to vigorously defend. 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. All of the Derivative Cases have now been dismissed, except the Derivative Case filed by Richard Harveth, for which the Company is presently seeking dismissal. It is possible that additional stockholder derivative suits could be filed over these events.
	In addition, the Company has 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 Delaware General Corporation Law. 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 (the "Scavo Action"). The Scavo Action seeks 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 has filed an answer in the Scavo Action. It is possible that additional similar actions may be filed and that similar stockholder demands could be made.
	In April 2013, the Company also received a letter from the SEC stating that the SEC's Division of Enforcement 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, and the SEC has also issued subpoenas for testimony and has taken testimony from certain individuals. The Company intends to cooperate with the subpoenas.
	Any potential liability from these claims cannot currently be estimated.
	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 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 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 April 2014, the estate of the other deceased third-party contractor employee sued the Company, Eureka Hunter Pipeline and certain other parties in 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 allege 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 have demanded judgment for an unspecified amount of compensatory, general and punitive damages. Various cross-claims have been asserted. In May 2014, the injured third-party contractor employee sued Magnum Hunter Resources Corporation and certain other parties in Jonathan Wisenhunt v. Magnum Hunter Resources Corporation et al, Civil Action No. 14-C-135, in the Circuit Court of Ohio County, West Virginia. Investigation regarding the incident is ongoing. It is not possible to predict at this juncture the extent to which, if at all, Eureka Hunter Pipeline or any related entities will incur liability or damages because of this incident. However, the Company believes that its insurance coverage will be sufficient to cover any losses or liabilities it may incur as a result of this incident.
	PRC Williston Matter
	On December 16, 2013, Drawbridge Special Opportunities Fund LP and Fortress Value Recovery Fund I LLC f/k/a D.B. Zwirn Special Opportunities Fund, L.P. (together, the "Plaintiffs") filed suit against PRC Williston in the Court of Chancery of the State of Delaware. PRC Williston and the Plaintiffs entered into Participation Agreements in February 2007 in connection with the Plaintiffs extending credit to PRC Williston pursuant to a credit agreement entitling the Plaintiffs to a 12.5% collective interest in any distributions in respect of the equity interests of the members of PRC Williston. Plaintiffs claim that they are entitled to compensation for 12.5% of alleged past distributions on equity from PRC Williston to Magnum Hunter and 12.5% of any transfers of funds to Magnum Hunter from the proceeds of the December 30, 2013 sale of PRC Williston’s assets. On December 23, 2013, the Chancery Court entered a temporary restraining order prohibiting PRC Williston from transferring, assigning, removing, distributing or otherwise displacing to Magnum Hunter, Magnum Hunter’s creditors, or any other person or entity, $5.0 million of the proceeds received by PRC Williston in connection with the sale of its assets. On March 18, 2014, the Court granted Plaintiffs’ motion for a preliminary injunction, extending the relief granted by the temporary restraining order until after a full trial on the merits. On July 24, 2014, the Company, PRC Williston, and the Plaintiffs settled this lawsuit. Pursuant to the settlement, PRC Williston paid approximately $2.9 million to the Plaintiffs. See "Note 20 - Subsequent Events" for additional information.
	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.

SUPPLEMENTAL_CASH_FLOW_INFORMA

SUPPLEMENTAL CASH FLOW INFORMATION (Notes)	6 Months Ended
	Jun. 30, 2014
Supplemental Cash Flow Elements [Abstract]	'
SUPPLEMENTAL CASH FLOW INFORMATION	'
	NOTE 17 - SUPPLEMENTAL CASH FLOW INFORMATION
	The following table summarizes cash paid (received) for interest and income taxes, as well as non-cash investing transactions:
		Six Months Ended June 30,
		2014		2013
		(in thousands)
	Cash paid for interest	$	35,679	$	34,448
	Non-cash transactions
	Non-cash consideration received from sale of assets	$	9,447	$	42,300
	Change in accrued capital expenditures	$	41,270	$	42,774
	Non-cash additions to asset retirement obligation	$	13	$	1,896
	Eureka Hunter Holdings Series A Preferred Unit dividends paid in kind	$	1,950	$	2,253

SEGMENT_REPORTING

SEGMENT REPORTING	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
SEGMENT REPORTING	'
	NOTE 18 - SEGMENT REPORTING
	Magnum Hunter has three reportable current operating segments: U.S. upstream, midstream and oilfield services represent the current operating segments of the Company.  Beginning September 30, 2013, the Canadian upstream segment, comprised of the WHI Canada operations, was classified as held for sale on the consolidated balance sheet and as a discontinued operation on the consolidated statement of operations. The Company sold 100% of the equity in WHI Canada in May 2014.
	The following tables set forth operating activities by segment for the three and six months ended June 30, 2014 and 2013, respectively.
		As of and for the Three Months Ended June 30, 2014
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	78,191		$	—		$	52,117		$	7,795		$	—		$	(5,587	)	$	132,516
	Depletion, depreciation, amortization and accretion	31,187			—			3,929			837			—			—			35,953
	Loss on sale of assets, net	(316		)	—			—			(371		)	—			—			(687		)
	Other operating expenses	37,692			—			46,700			6,361			13,054			(5,418		)	98,389
	Other income (expense)	201			—			(40,457		)	(211		)	(22,498		)	—			(62,965		)
	Income (loss) from continuing operations before income tax	9,829			—			(38,969		)	757			(35,552		)	(169		)	(64,104		)
	Total income (loss) from discontinued operations, net of tax 1	(177		)	11,461			—			—			(12,776		)	169			(1,323		)
	Net income (loss)	$	9,652		$	11,461		$	(38,969	)	$	757		$	(48,328	)	$	—		$	(65,427	)
	Total assets	$	1,485,120		$	—		$	380,108		$	44,682		$	61,180		$	(7,733	)	$	1,963,357
	Total capital expenditures	$	150,143		$	(3	)	$	51,993		$	2,257		$	83		$	—		$	204,473
	_________________________________
	-1	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.
		As of and for the Three Months Ended June 30, 2013
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	50,321		$	—		$	16,151		$	3,694		$	—		$	(2,258	)	$	67,908
	Depletion, depreciation, amortization and accretion	22,573			—			3,281			521			—			—			26,375
	(Gain) loss on sale of assets, net	1,179			—			—			4			—			—			1,183
	Other operating expenses	37,638			—			15,468			4,254			11,485			(2,258		)	66,587
	Other income (expense)	(2,589		)	—			(6,594		)	(142		)	(3,390		)	(62		)	(12,777		)
	Loss from continuing operations before income tax	(13,658		)	—			(9,192		)	(1,227		)	(14,875		)	(62		)	(39,014		)
	Income tax benefit (expense)	(1,674		)	(926		)	—			—			41,900			—			39,300
	Total income (loss) from discontinued operations, net of tax	174,724			(1,565		)	—			—			(8,453		)	62			164,768
	Net income (loss)	$	159,392		$	(2,491	)	$	(9,192	)	$	(1,227	)	$	18,572		$	—		$	165,054
	Total assets	$	1,413,298		$	248,908		$	248,965		$	34,287		$	98,469		$	(8,007	)	$	2,035,920
	Total capital expenditures	$	60,847		$	1,880		$	12,790		$	6,165		$	252		$	—		$	81,934
		As of and for the Six Months Ended June 30, 2014
		U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
		Upstream			Upstream						Services			Unallocated			Eliminations
		(in thousands)
	Total revenue	$	148,365		$	—		$	86,852		$	15,706		$	—		$	(10,963	)	$	239,960
	Depletion, depreciation, amortization and accretion	56,126			—			7,607			1,628			—			—			65,361
	Loss on sale of assets, net	3,141			—			—			(369		)	—			—			2,772
	Other operating expenses	82,421			—			78,770			13,074			23,542			(10,641		)	187,166
	Other income (expense)	(77		)	—			(40,427		)	(420		)	(45,742		)	—			(86,666		)
	Income (loss) from continuing operations before income tax	6,600			—			(39,952		)	953			(69,284		)	(322		)	(102,005		)
	Total income (loss) from discontinued operations, net of tax 1	(23,305		)	10,636			—			—			(12,776		)	322			(25,123		)
	Net income (loss)	$	(16,705	)	$	10,636		$	(39,952	)	$	953		$	(82,060	)	$	—		$	(127,128	)
	Total assets	$	1,485,120		$	—		$	380,108		$	44,682		$	61,180		$	(7,733	)	$	1,963,357
	Total capital expenditures	$	216,454		$	305		$	82,627		$	2,947		$	106		$	—		$	302,439
	_________________________________
	-1	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.
		As of and for the Six Months Ended June 30, 2013
		U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
		Upstream			Upstream						Services			Unallocated			Eliminations
		(in thousands)
	Total revenue	$	84,966		$	—		$	33,453		$	7,425		$	—		$	(3,702	)	$	122,142
	Depletion, depreciation, amortization and accretion	36,836			—			5,968			859			—			—			43,663
	(Gain) loss on sale of assets, net	1,160			—			—			4			—			—			1,164
	Other operating expenses	81,701			—			30,136			7,953			27,475			(3,702		)	143,563
	Other income (expense)	(4,712		)	—			(7,689		)	(231		)	(26,516		)	20			(39,128		)
	Loss from continuing operations before income tax	(39,443		)	—			(10,340		)	(1,622		)	(53,991		)	20			(105,376		)
	Income tax benefit	3,180			(926		)	—			—			41,945			—			44,199
	Total income from discontinued operations, net of tax	191,213			(1,209		)	—			—			(8,453		)	(20		)	181,531
	Net income (loss)	$	154,950		$	(2,135	)	$	(10,340	)	$	(1,622	)	$	(20,499	)	$	—		$	120,354
	Total assets	$	1,413,298		$	248,908		$	248,965		$	34,287		$	98,469		$	(8,007	)	$	2,035,920
	Total capital expenditures	$	173,191		$	14,136		$	35,085		$	14,121		$	423		$	—		$	236,956

CONDENSED_CONSOLIDATING_GUARAN

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	6 Months Ended
	Jun. 30, 2014
Guarantees [Abstract]	'
CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS	'
	NOTE 19 - CONDENSED CONSOLIDATED GUARANTOR FINANCIAL STATEMENTS
	Guarantor Subsidiaries
	Certain of the Company’s subsidiaries, including Alpha Hunter Drilling, LLC, Bakken Hunter, LLC, Shale Hunter, Magnum Hunter Marketing, LLC, Magnum Hunter Production, Inc., NGAS Hunter, LLC, Triad Hunter, and Viking International Resources, Co., 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 also may guarantee any debt of the Company issued pursuant to the Form S-3 Registration Statement filed by the Company with the SEC on August 5, 2014 (see "Note 20 - Subsequent Events").
	These condensed consolidating guarantor financial statements have been revised to reflect Eagle Ford Hunter and PRC Williston as non-guarantors as the subsidiaries are no longer guarantors of the Company's Senior Notes.
	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 June 30, 2014 and December 31, 2013, and for the three and six months ended June 30, 2014 and 2013, are as follows:
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
		As of June 30, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	ASSETS
	Current assets	$	37,995		$	75,812		$	15,539		$	(7,733	)	$	121,613
	Intercompany accounts receivable	1,083,102			—			—			(1,083,102		)	—
	Property and equipment (using successful efforts method of accounting)	5,939			1,381,891			310,195			—			1,698,025
	Investment in subsidiaries	279,116			101,485			—			(380,601		)	—
	Assets held for sale and other	17,246			88,394			38,079			—			143,719
	Total Assets	$	1,423,398		$	1,647,582		$	363,813		$	(1,471,436	)	$	1,963,357
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	63,583		$	118,934		$	51,453		$	(7,774	)	$	226,196
	Intercompany accounts payable	—			1,036,163			46,901			(1,083,064		)	—
	Long-term liabilities	765,072			39,346			180,359			—			984,777
	Redeemable preferred stock	100,000			—			149,379			—			249,379
	Shareholders' equity (deficit)	494,743			453,139			(64,279		)	(380,598		)	503,005
	Total Liabilities and Shareholders' Equity	$	1,423,398		$	1,647,582		$	363,813		$	(1,471,436	)	$	1,963,357
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
		As of December 31, 2013
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	ASSETS
	Current assets	$	53,161		$	43,841		$	27,096		$	(3,372	)	$	120,726
	Intercompany accounts receivable	965,138			—			—			(965,138		)	—
	Property and equipment (using successful efforts method of accounting)	7,214			1,272,027			234,838			—			1,514,079
	Investment in subsidiaries	372,236			102,314			—			(474,550		)	—
	Other assets	17,308			100,894			103,644			—			221,846
	Total Assets	$	1,415,057		$	1,519,076		$	365,578		$	(1,443,060	)	$	1,856,651
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	54,826		$	97,520		$	34,929		$	(3,410	)	$	183,865
	Intercompany accounts payable	—			921,237			43,866			(965,103		)	—
	Long-term liabilities	818,651			39,067			127,663			—			985,381
	Redeemable preferred stock	100,000			—			136,675			—			236,675
	Shareholders' equity (deficit)	441,580			461,252			22,445			(474,547		)	450,730
	Total Liabilities and Shareholders' Equity	$	1,415,057		$	1,519,076		$	365,578		$	(1,443,060	)	$	1,856,651
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
		Three Months Ended June 30, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Revenues	$	6		$	125,536		$	12,560		$	(5,586	)	$	132,516
	Expenses	36,512			112,757			52,768			(5,417		)	196,620
	Income (loss) from continuing operations before equity in net income of subsidiaries	(36,506		)	12,779			(40,208		)	(169		)	(64,104		)
	Equity in net income of subsidiaries	(19,314		)	(984		)	—			20,298			—
	Income (loss) from continuing operations before income tax	(55,820		)	11,795			(40,208		)	20,129			(64,104		)
	Income tax benefit (expense)	—			—			—			—			—
Income (loss) from continuing operations	(55,820		)	11,795			(40,208		)	20,129			(64,104		)
Income from discontinued operations, net of tax	—			2,376			1,342			171			3,889
Gain on sale of discontinued operations, net of tax	(15,480		)	—			10,268			—			(5,212		)
Net income (loss)	(71,300		)	14,171			(28,598		)	20,300			(65,427		)
Net income attributable to non-controlling interest	—			—			—			780			780
Net income (loss) attributable to Magnum Hunter Resources Corporation	(71,300		)	14,171			(28,598		)	21,080			(64,647		)
Dividends on preferred stock	(8,848		)	—			(6,482		)	—			(15,330		)
Net income (loss) attributable to common shareholders	$	(80,148	)	$	14,171		$	(35,080	)	$	21,080		$	(79,977	)
	Three Months Ended June 30, 2013
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Revenues	$	12		$	62,065		$	8,090		$	(2,259	)	$	67,908
Expenses	16,577			74,612			17,930			(2,197		)	106,922
Income (loss) from continuing operations before equity in net income of subsidiaries	(16,565		)	(12,547		)	(9,840		)	(62		)	(39,014		)
Equity in net income of subsidiaries	(29,060		)	(113		)	(1,582		)	30,755			—
Income (loss) from continuing operations before income tax	(45,625		)	(12,660		)	(11,422		)	30,693			(39,014		)
Income tax benefit (expense)	41,900			(1,654		)	(946		)	—			39,300
Income (loss) from continuing operations	(3,725		)	(14,314		)	(12,368		)	30,693			286
Income (loss) from discontinued operations, net of tax	(8,453		)	18,903			(18,196		)	62			(7,684		)
Gain on sale of discontinued operations, net of tax	172,452			—			—			—			172,452
Net income (loss)	160,274			4,589			(30,564		)	30,755			165,054
Net income attributable to non-controlling interest	—			—			—			386			386
Net income (loss) attributable to Magnum Hunter Resources Corporation	160,274			4,589			(30,564		)	31,141			165,440
Dividends on preferred stock	(8,877		)	—			(5,252		)	—			(14,129		)
Net income (loss) attributable to common shareholders	$	151,397		$	4,589		$	(35,816	)	$	31,141		$	151,311
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Operations
(in thousands)
	Six Months Ended June 30, 2014
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Revenues	$	114		$	229,550		$	21,258		$	(10,962	)	$	239,960
Expenses	71,305			219,841			61,460			(10,641		)	341,965
Income (loss) from continuing operations before equity in net income of subsidiaries	(71,191		)	9,709			(40,202		)	(321		)	(102,005		)
Equity in net income of subsidiaries	(48,129		)	(829		)	—			48,958			—
Income (loss) from continuing operations before income tax	(119,320		)	8,880			(40,202		)	48,637			(102,005		)
Income tax benefit (expense)	—			—			—			—			—
Income (loss) from continuing operations	(119,320		)	8,880			(40,202		)	48,637			(102,005		)
Income from discontinued operations, net of tax	—			2,259			4,669			323			7,251
Gain (loss) on sale of discontinued operations, net of tax	(19,799		)	(18,649		)	6,074			—			(32,374		)
Net income (loss)	(139,119		)	(7,510		)	(29,459		)	48,960			(127,128		)
Net income attributable to non-controlling interest	—			—			—			889			889
Net income (loss) attributable to Magnum Hunter Resources Corporation	(139,119		)	(7,510		)	(29,459		)	49,849			(126,239		)
Dividends on preferred stock	(17,668		)	—			(12,558		)	—			(30,226		)
Net income (loss) attributable to common shareholders	$	(156,787	)	$	(7,510	)	$	(42,017	)	$	49,849		$	(156,465	)
	Six Months Ended June 30, 2013
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Revenues	$	(163	)	$	109,427		$	16,581		$	(3,703	)	$	122,142
Expenses	56,209			146,285			28,747			(3,723		)	227,518
Income (loss) from continuing operations before equity in net income of subsidiaries	(56,372		)	(36,858		)	(12,166		)	20			(105,376		)
Equity in net income of subsidiaries	(38,143		)	(642		)	(9,387		)	48,172			—
Income (loss) from continuing operations before income tax	(94,515		)	(37,500		)	(21,553		)	48,192			(105,376		)
Income tax benefit (expense)	41,945			3,200			(946		)	—			44,199
Income (loss) from continuing operations	(52,570		)	(34,300		)	(22,499		)	48,192			(61,177		)
Income (loss) from discontinued operations, net of tax	(8,453		)	18,794			(1,242		)	(20		)	9,079
Gain on sale of discontinued operations, net of tax	172,452			—			—			—			172,452
Net income (loss)	111,429			(15,506		)	(23,741		)	48,172			120,354
Net income attributable to non-controlling interest	—			—			—			889			889
Net income (loss) attributable to Magnum Hunter Resources Corporation	111,429			(15,506		)	(23,741		)	49,061			121,243
Dividends on preferred stock	(17,783		)	—			(9,834		)	—			(27,617		)
Net income (loss) attributable to common shareholders	$	93,646		$	(15,506	)	$	(33,575	)	$	49,061		$	93,626
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Comprehensive Income (Loss)
(in thousands)
	Three Months Ended June 30, 2014
	Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Net income (loss)	$	(71,300	)	$	14,171		$	(28,598	)	$	20,300		$	(65,427	)
Foreign currency translation gain	—			—			1,130			—			1,130
Unrealized loss on available for sale securities	—			(549		)	—			—			(549		)
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	20,741			—			—			—			20,741
Comprehensive income (loss)	(50,559		)	13,622			(27,468		)	20,300			(44,105		)
Comprehensive income attributable to non-controlling interest	—			—			—			780			780
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(50,559	)	$	13,622		$	(27,468	)	$	21,080		$	(43,325	)
	Three Months Ended June 30, 2013
	Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Net income (loss)	$	160,274		$	4,589		$	(30,564	)	$	30,755		$	165,054
Foreign currency translation loss	—			—			(7,070		)	—			(7,070		)
Unrealized gain (loss) on available for sale securities	4,700			(234		)	—			—			4,466
Comprehensive income (loss)	164,974			4,355			(37,634		)	30,755			162,450
Comprehensive income attributable to non-controlling interest	—			—			—			386			386
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	164,974		$	4,355		$	(37,634	)	$	31,141		$	162,836
	Six Months Ended June 30, 2014
	Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Net income (loss)	$	(139,119	)	$	(7,510	)	$	(29,459	)	$	48,960		$	(127,128	)
Foreign currency translation loss	—			—			(1,218		)	—			(1,218		)
Unrealized loss on available for sale securities	—			(605		)	—			—			(605		)
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	20,741			—			—			—			20,741
Comprehensive income (loss)	(118,378		)	(8,115		)	(30,677		)	48,960			(108,210		)
Comprehensive income attributable to non-controlling interest	—			—			—			889			889
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(118,378	)	$	(8,115	)	$	(30,677	)	$	49,849		$	(107,321	)
	Six Months Ended June 30, 2013
	Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Net income (loss)	$	111,429		$	(15,506	)	$	(23,741	)	$	48,172		$	120,354
Foreign currency translation loss	—			—			(11,799		)	—			(11,799		)
Unrealized gain (loss) on available for sale securities	4,700			(251		)	—			—			4,449
Comprehensive income (loss)	116,129			(15,757		)	(35,540		)	48,172			113,004
Comprehensive income attributable to non-controlling interest	—			—			—			889			889
Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	116,129		$	(15,757	)	$	(35,540	)	$	49,061		$	113,893
Magnum Hunter Resources Corporation and Subsidiaries
Condensed Consolidating Statements of Cash Flows
(in thousands)
	Six Months Ended June 30, 2014
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Cash flow from operating activities	$	(192,121	)	$	182,620		$	28,248		$	—		$	18,747
Cash flow from investing activities	49,572			(177,365		)	(57,579		)	—			(185,372		)
Cash flow from financing activities	111,324			3,038			19,629			—			133,991
Effect of exchange rate changes on cash	—			—			41			—			41
Net increase (decrease) in cash	(31,225		)	8,293			(9,661		)	—			(32,593		)
Cash at beginning of period	47,895			(17,651		)	11,469			—			41,713
Cash at end of period	$	16,670		$	(9,358	)	$	1,808		$	—		$	9,120
	Six Months Ended June 30, 2013
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Cash flow from operating activities	$	(156,721	)	$	146,932		$	83,657		$	—		$	73,868
Cash flow from investing activities	371,970			(152,127		)	(115,645		)	—			104,198
Cash flow from financing activities	(224,493		)	4,051			17,852			—			(202,590		)
Effect of exchange rate changes on cash	—			—			(357		)	—			(357		)
Net increase (decrease) in cash	(9,244		)	(1,144		)	(14,493		)	—			(24,881		)
Cash at beginning of period	26,871			(4,186		)	34,938			—			57,623
Cash at end of period	$	17,627		$	(5,330	)	$	20,445		$	—		$	32,742

SUBSEQUENT_EVENTS

SUBSEQUENT EVENTS	6 Months Ended
	Jun. 30, 2014
Subsequent Events [Abstract]	'
SUBSEQUENT EVENTS	'
	NOTE 20 - SUBSEQUENT EVENTS
	Sale of Class A Common Units of Eureka Hunter Holdings
	On July 1, 2014, the Company funded and closed on the purchase of 537,209 additional Class A Common Units in Eureka Hunter Holdings for cash of $10.7 million, increasing the Company’s ownership in Eureka Hunter Holdings to 59.1%. On July 14, 2014, the board of directors of Eureka Hunter Holdings approved the sale of up to 1.0 million additional Class A Common Units of Eureka Hunter Holdings to the Company and Ridgeline Midstream Holdings, LLC ("Ridgeline") in proportion to their ownership interests, at $20.00 par, for total aggregate proceeds of $20 million. On July 18, 2014, the Company funded and closed on the purchase of its pro rata share, 590,976 Class A Common Units, for cash of $11.8 million. On July 29, 2014, Ridgeline exercised its pre-emptive right to purchase its proportionate share, 409,024 Class A Common Units, for total gross cash proceeds of $8.2 million. Ridgeline funded and closed on the purchase of its units on August 1, 2014.
	PVA Arbitration Decision
	On July 25, 2014, the Company received the final determination from the arbitrator in the disagreement related to the final working capital adjustments pertaining to the sale of Eagle Ford Hunter to Penn Virginia in 2013. In accordance with ASC 855, the Company took this final determination into account in estimating its liability as of June 30, 2014. As a result, the Company has recorded a total liability of $33.7 million, plus accrued interest of $1.3 million, as of June 30, 2014 based upon the final determination made by the arbitrator. This liability was settled in cash on July 31, 2014. The arbitrator declined to rule, on the basis of lack of authority, on two claims made by Penn Virginia related to working capital adjustments governed by a transition services agreement in the amount of $7.8 million. Any potential liability from these claims cannot currently be estimated.
	PRC Settlement
	On July 24, 2014 the Company and PRC Williston executed a Settlement and Release Agreement ("the Settlement Agreement"). Per the terms of the Settlement Agreement, PRC Williston agreed to pay approximately $2.9 million in cash to Drawbridge Special Opportunities Fund LP. As a result of the Settlement Agreement, the Company, PRC Williston, and the Plaintiffs agreed to release each other from all claims, past, present or future, related to the dispute. In addition, with the execution of the Settlement Agreement, the parties agreed to terminate, in all respects, the Participation Agreements and that none of the parties would have any further rights or obligations thereunder. With the cash settlement payment and the termination of the Participation Agreements, the Company now has rights and claims to 100% of the equity interests in PRC Williston and its remaining assets and liabilities. The Company will record this transaction as a reduction to cash and shareholder's equity in the third quarter of 2014. Consequently, there will no longer be any non-controlling interest in PRC Williston's equity reflected in our consolidated financial statements.
	Ormet Asset Acquisition
	On July 24, 2014, our wholly owned subsidiary, Triad Hunter LLC, closed on the acquisition of mineral interests from the Ormet Corporation for total cash consideration of approximately $22.7 million, for which Triad Hunter LLC received a credit of $2.5 million for funds previously deposited in escrow in June 2014.
	Form S-3 Registration Statement
	On August 5, 2014, the Company filed a universal shelf Form S-3 Registration Statement to register the sale by the Company of an unlimited amount of debt and equity securities, and such registration statement became effective automatically upon filing. The guarantor financial information as of and for the three and six months ended June 30, 2014, included in Note 19 - Condensed Consolidated Guarantor Financial Statements, is applicable to any Guarantor Subsidiaries that may guarantee any debt issued by the Company pursuant to the Form S-3 Registration Statement.

GENERAL_Policies

GENERAL (Policies)	6 Months Ended
	Jun. 30, 2014
Accounting Policies [Abstract]	'
Principles of Consolidation and Presentation	'
	Presentation of Consolidated Financial Statements
	The accompanying unaudited interim consolidated financial statements of Magnum Hunter are presented in U.S. Dollars and have been prepared in accordance with accounting principles generally accepted in the United States ("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, 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.
Non-controlling Interest in Consolidated Subsidiaries	'
	Non-Controlling Interest in Consolidated Subsidiaries
	The Company has consolidated Eureka Hunter Holdings, LLC ("Eureka Hunter Holdings") in which it owned 56.5% as of June 30, 2014 and 56.4% as of December 31, 2013. Eureka Hunter Holdings owns, directly or indirectly, 100% of the equity interests of Eureka Hunter Pipeline, LLC ("Eureka Hunter Pipeline"), TransTex Hunter, LLC ("TransTex Hunter"), and Eureka Hunter Land, LLC.
Reclassification of Prior-Year Balances	'
	Reclassification of Prior-Year Balances
	Certain prior period balances have been reclassified to correspond with current-year presentation.  As a result of the Company's adoption of a plan in September 2013 to dispose of certain of its U.S. and Canadian properties, operating income and expenses related to these operations have been classified as discontinued operations for all periods presented.
Regulated Activities	'
	Regulated Activities
	Energy Hunter Securities, Inc. is a 100%-owned subsidiary and is a registered broker-dealer and member of the Financial Industry Regulatory Authority. Among other regulatory requirements, it is subject to the net capital provisions of Rule 15c3-1 under the Securities Exchange Act of 1934, as amended. Because it does not hold customer funds or securities or owe money or securities to customers, Energy Hunter Securities, Inc. is required to maintain minimum net capital equal to the greater of $5,000 or 6.67% of its aggregate indebtedness.
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 March 2013, the FASB issued ASU 2013-05, Parent’s Accounting for the Cumulative Translation Adjustment upon Derecognition of Certain Subsidiaries or Groups of Assets within a Foreign Entity or of an Investment in a Foreign Entity, to provide guidance on whether to release cumulative translation adjustments ("CTA") upon certain derecognition events. ASU 2013-05 requires a parent company to apply the guidance in ASC Subtopic 830-30 when an entity ceases to have a controlling financial interest in a subsidiary or group of assets that is a business within a foreign entity. Consequently, the CTA related to a foreign entity is released into net income only if the transaction results in complete or substantially complete liquidation of the foreign entity in which the subsidiary or group of assets resided; otherwise, no portion of the CTA is released.  The Company adopted this pronouncement prospectively on January 1, 2014. The adoption of this updated standard did not have a material impact on the Company’s consolidated financial statements.
	In July 2013, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2013-11, Presentation of Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists, an amendment to FASB Accounting Standards Codification ("ASC") Topic 740, Income Taxes ("FASB ASC Topic 740"). This update clarified that an unrecognized tax benefit, or a portion of an unrecognized tax benefit, should be presented in the financial statements as a reduction to a deferred tax asset for a net operating loss carryforward, a similar tax loss, or a tax credit carryforward if such settlement is required or expected in the event the uncertain tax position is disallowed. In situations where a net operating loss carryforward, a similar tax loss, or a tax credit carryforward is not available at the reporting date under the tax law of the applicable jurisdiction or the tax law of the jurisdiction does not require, and the entity does not intend to use, the deferred tax asset for such purpose, the unrecognized tax benefit should be presented in the financial statements as a liability and should not be combined with deferred tax assets. The Company adopted this ASU prospectively on January 1, 2014. The adoption of this accounting standard update did not have a material impact on the Company's consolidated financial statements or its financial statement disclosures.
	In April 2014, the FASB issued ASU 2014-08 , Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity. ASU 2014-08 updates 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 or a group of components of an entity 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 or group of components of an entity 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). The amendments in this update expand the disclosure requirements related to discontinued operations and disposals of individually significant components that do not qualify for discontinued operations presentation in the financial statements. This ASU is 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. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.
	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: identify the contract(s) with a customer, identify the performance obligations in the contract, determine the transaction price, allocate the transaction price to the performance obligations in the contract, and 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. This amendment is effective for annual reporting periods beginning after December 15, 2016, including interim periods within that reporting period. Early application is not permitted. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.
	In June 2014, the FASB issued ASU 2014-12, Compensation - Stock Compensation: Accounting for Share Based Payments When the Terms of an Award Provide That a Performance Target Could Be Achieved after the Requisite Service Period. ASU 2014-12 clarifies that a performance target that affects vesting and that could be achieved after the requisite service period should be treated as a performance condition. An entity should apply existing guidance in ASC Topic 718 as it relates to awards with performance conditions that affect vesting to account for such awards. As such, the performance target should not be reflected in estimating the grant-date fair value of the award. This amendment is effective for annual periods and interim periods within those annual periods beginning after December 15, 2015. Early adoption is permitted. The Company is currently evaluating the impact of this ASU on its consolidated financial statements and financial statement disclosures.

DIVESTITURES_AND_DISCONTINUED_1

DIVESTITURES AND DISCONTINUED OPERATIONS (Tables)	6 Months Ended
	Jun. 30, 2014
Discontinued Operations and Disposal Groups [Abstract]	'
Schedule of Assets and Liabilities Held for Sale	'
	The following shows the Company's assets and liabilities held for sale at June 30, 2014 and December 31, 2013:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Accounts receivable	$	927		$	4,362
	Other current assets	711			1,004
	Oil and natural gas properties, net	71,935			150,770
	Gas transportation, gathering, and processing equipment and other, net	12,972			11,721
	Other long-term assets	28			196
	Total assets held for sale	$	86,573		$	168,053
	Accounts payable	$	7,659		$	7,292
	Accrued liabilities and other liabilities	10,302			5,573
	Asset retirement obligations	6,975			8,678
	Other long-term liabilities	4,335			5,845
	Total liabilities held for sale	$	29,271		$	27,388
Schedule of discontinued operations	'
	The Company included the results of operations of MHP for all periods presented, WHI Canada through May 12, 2014, and Eagle Ford Hunter through April 24, 2013, in discontinued operations as follows:
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014			2013
		(in thousands)
	Revenues	$	8,234		$	24,623		$	20,517		$	68,413
	Expenses	(4,345		)	(30,013		)	(13,178		)	(58,238		)
	Other income (expense)	—			1,893			(88		)	3,136
	Income tax expense	—			(4,187		)	—			(4,232		)
	Income (loss) from discontinued operations, net of tax	3,889			(7,684		)	7,251			9,079
	Income (loss) on sale of discontinued operations, net of taxes	(5,212		)	172,452			(32,374		)	172,452
	Income (loss) from discontinued operations, net of taxes	$	(1,323	)	$	164,768		$	(25,123	)	$	181,531

OIL_NATURAL_GAS_SALES_Tables

OIL & NATURAL GAS SALES (Tables)	6 Months Ended
	Jun. 30, 2014
Other Income and Expenses [Abstract]	'
Schedule of Oil Natural Gas And NGL Revenue	'
	During the three and six months ended June 30, 2014 and 2013, the Company recognized sales from oil, natural gas, and natural gas liquids ("NGLs") as follows:
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
		(in thousands)
	Oil	$	39,839	$	33,122	$	74,111	$	58,694
	Natural gas	25,453		12,810		49,583		21,263
	NGLs	12,898		3,651		24,668		4,267
	Total oil and natural gas sales	$	78,190	$	49,583	$	148,362	$	84,224

PROPERTY_PLANT_EQUIPMENT_Table

PROPERTY, PLANT, & EQUIPMENT (Tables)	6 Months Ended
	Jun. 30, 2014
Property, Plant and Equipment [Abstract]	'
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:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Mineral interests in properties:
	Unproved leasehold costs	$	538,872		$	469,337
	Proved leasehold costs	334,918			336,357
	Wells and related equipment and facilities	615,998			536,023
	Advances to operators for wells in progress	20,740			13,571
	Total costs	1,510,528			1,355,288
	Less accumulated depletion, depreciation, and amortization	(181,827		)	(130,629		)
	Net capitalized costs	$	1,328,701		$	1,224,659
	The historical cost of gas transportation, gathering, and processing equipment and other property, presented on a gross basis with accumulated depreciation, as of June 30, 2014 and December 31, 2013 is summarized as follows:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Gas transportation, gathering and processing equipment and other	$	405,320		$	315,642
	Less accumulated depreciation	(35,996		)	(26,222		)
	Net capitalized costs	$	369,324		$	289,420
Schedule of the Company's geological and geophysical costs and leasehold abandonments expense	'
	During the three and six months ended June 30, 2014 and 2013, the Company recognized exploration expense as follows:
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014		2013
		(in thousands)
	Leasehold impairments	$	8,834		$	3,272		$	22,489	$	32,625
	Geological and geophysical	353			274			727		654
	Total exploration expense	$	9,187		$	3,546		$	23,216	$	33,279

INTANGIBLE_ASSETS_Tables

INTANGIBLE ASSETS (Tables)	6 Months Ended
	Jun. 30, 2014
Goodwill and Intangible Assets Disclosure [Abstract]	'
Schedule of Finite-Lived Intangible Assets [Table Text Block]	'
	Intangible assets consist primarily of gas gathering and processing contracts and customer relationships. The following table summarizes the Company's net intangible assets as of June 30, 2014 and December 31, 2013:
		June 30,			December 31,
		2014			2013
		(in thousands)
	Customer relationships	$	5,434		$	5,434
	Trademark	859			859
	Existing contracts	4,199			4,199
	Total intangible assets	10,492			10,492
	Less: accumulated amortization	(4,965		)	(3,962		)
	Intangible assets, net of accumulated amortization	$	5,527		$	6,530

INVENTORY_Tables

INVENTORY (Tables)	6 Months Ended
	Jun. 30, 2014
Inventory Disclosure [Abstract]	'
Schedule of Inventory	'
	The following table shows the composition of the Company's inventory as of:
		June 30,		December 31,
		2014		2013
		(in thousands)
	Materials and supplies	$	3,440	$	6,790
	Commodities	390		368
	Inventory	$	3,830	$	7,158

ASSET_RETIREMENT_OBLIGATIONS_T

ASSET RETIREMENT OBLIGATIONS (Tables)	6 Months Ended
	Jun. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]	'
Summary of asset retirement obligation	'
	The following table summarizes the Company’s asset retirement obligation ("ARO") activities during the six-month period ended June 30, 2014 and for the year ended December 31, 2013:
		30-Jun-14			31-Dec-13
		(in thousands)
	Asset retirement obligation at beginning of period	$	16,216		$	30,680
	Assumed in acquisitions	—			17
	Liabilities incurred	216			253
	Liabilities settled	(21		)	(98		)
	Liabilities sold	(523		)	(7,614		)
	Accretion expense	751			2,264
	Revisions in estimated liabilities (1)	—			1,935
	Reclassified as liabilities associated with assets held for sale	—			(11,148		)
	Effect of foreign currency translation	—			(73		)
	Asset retirement obligation at end of period	16,639			16,216
	Less: current portion (included in other liabilities)	(71		)	(53		)
	Asset retirement obligation at end of period	$	16,568		$	16,163
	________________________________
	(1) $1.5 million of the revisions in estimated liabilities is related to change in assumptions used with respect to certain wells in the Williston Basin in North Dakota during 2013.

FAIR_VALUE_OF_FINANCIAL_INSTRU1

FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)	6 Months Ended
	Jun. 30, 2014
Fair Value Disclosures [Abstract]	'
Schedule of inputs used to calculated fair value of convertible security embedded derivative	'
	The fair value of the bifurcated conversion feature was valued using the "with and without" analysis in a simulation model based upon management's estimate of the expected life of the conversion feature. The key assumptions used in the model to determine fair value at June 30, 2014 were as follows:
		30-Jun-14
	Volatility	24		%
	Credit spread	10.5		%
	Expected term	1-2 years
	Total enterprise value (in millions)	$	608
	The key inputs used in the Black-Scholes option pricing model were as follows:
		30-Jun-14
	Life	2.6 years
	Risk-free interest rate	0.85		%
	Estimated volatility	40		%
	Dividend	—
	GreenHunter stock price at end of period	$	1.99
Schedule of reconciliation of derivative assets and (liabilities) measured at fair value using significant unobservable inputs	'
	The following table presents a reconciliation of the financial derivative asset and liability measured at fair value using significant unobservable inputs (Level 3 inputs) for the six-month period ended June 30, 2014:
		Preferred Stock Embedded				Convertible Security Embedded
		Derivative Liability				Derivative Asset
		(in thousands)
	Fair value as of December 31, 2013	$	(75,934	)		$	79
	Issuance of redeemable preferred stock	(5,479		)		—
	Increase in fair value recognized in gain (loss) on derivative contracts, net	(33,894		)		238
	Fair value as of June 30, 2014	$	(115,307	)		$	317
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
		30-Jun-14
		(in thousands)
	Assets	Level 1				Level 2			Level 3
	Available for sale securities	$	10,661			$	—		$	—
	Commodity derivative assets	—				123			—
	Convertible security derivative assets	—				—			317
	Total assets at fair value	$	10,661			$	123		$	317
	Liabilities
	Commodity derivative liabilities	$	—			$	6,129		$	—
	Convertible preferred stock derivative liabilities	—				—			115,307
	Total liabilities at fair value	$	—			$	6,129		$	115,307
		Fair Value Measurements on a Recurring Basis
		31-Dec-13
		(in thousands)
	Assets	Level 1				Level 2			Level 3
	Available for sale securities	$	1,819			$	—		$	—
	Commodity derivative assets	—				554			—
	Convertible security derivative assets	—				—			79
	Total assets at fair value	$	1,819			$	554		$	79
	Liabilities
	Commodity derivative liabilities	$	—			$	2,279		$	—
	Convertible preferred stock derivative liabilities	—				—			75,934
	Total liabilities at fair value	$	—			$	2,279		$	75,934
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:
					30-Jun-14						31-Dec-13
			Fair Value Hierarchy		Carrying Amount			Estimated Fair Value			Carrying Amount		Estimated Fair Value
					(in thousands)
	Senior Notes		Level 2		$	597,279		$	666,000		$	597,230	$	651,300
	MHR Senior Revolving Credit Facility		Level 3		$	164,500		$	164,500		$	218,000	$	218,000
	Eureka Hunter Pipeline second lien term loan		Level 3		$	—		$	—		$	50,000	$	58,921
	Eureka Hunter Pipeline Credit Agreement		Level 3		$	65,000		$	65,000		$	—	$	—
	Equipment Notes Payable		Level 3		$	24,395		$	24,303		$	18,615	$	17,676

FINANCIAL_INSTRUMENTS_AND_DERI1

FINANCIAL INSTRUMENTS AND DERIVATIVES (Tables)	6 Months Ended
	Jun. 30, 2014
Derivative Instruments and Hedging Activities Disclosure [Abstract]	'
Summary of changes in investments	'
	Below is a summary of changes in investments for the six months ended June 30, 2014:
		Available for Sale Securities (1)				Equity Method Investments (2)
		(in thousands)
	Carrying value as of December 31, 2013	$	1,819			$	940
	Securities received as consideration for assets sold	9,447				—
	Equity in net loss recognized in other income (expense)	—				(403		)
	Change in fair value recognized in other comprehensive loss	(605		)		—
	Carrying value as of June 30, 2014	$	10,661			$	537
	-1	Available for sale securities includes $123,000 that has been classified as held for sale associated with the classification of MHP as a discontinued operation.
	(2) Equity method investments includes $304,000 classified as long-term other assets.
Schedule of investments by balance sheet grouping	'
	The Company's investments have been presented in the consolidated balance sheet as of June 30, 2014 as follows:
		Available for Sale Securities			Equity Method Investments			Total
	Investments - Current	$	10,538		$	233		$	10,771
	Investments - Long-Term	—			304			304
	Investments - Held for Sale	123			—			123
	Carrying value as of June 30,2014	$	10,661		$	537		$	11,198
Summary of cost for equity securities and fair value	'
	The cost for equity securities and their respective fair values as of June 30, 2014 and December 31, 2013 are as follows:
			June 30, 2014
			(in thousands)
			Cost				Gross Unrealized Gains				Gross Unrealized Losses				Fair Value
	Securities available for sale, carried at fair value:
	Equity securities		$	9,875			$	—			$	(1,404	)		$	8,471
	Equity securities - related party (see "Note 15 - Related Party Transactions")		2,200				—				(10		)		2,190
	Total Securities available for sale		$	12,075			$	—			$	(1,414	)		$	10,661
			December 31, 2013
			(in thousands)
			Cost				Gross Unrealized Gains				Gross Unrealized Losses				Fair Value
	Securities available for sale, carried at fair value:
	Equity securities		$	428			$	—			$	(281	)		$	147
	Equity securities - related party (see "Note 15 - Related Party Transactions")		2,200				—				(528		)		1,672
	Total Securities available for sale		$	2,628			$	—			$	(809	)		$	1,819
Estimated fair values of commodity derivatives	'
	As of June 30, 2014, the Company had the following commodity derivative instruments:
					Weighted Average
	Natural Gas	Period	MMBtu/day		Price per MMBtu
	Collars (1)	July 2014- Dec 2014	15,000		$4.27 - $5.23
	Swaps	July 2014 - Dec 2014	31,000		$4.23
		Jan 2015 - Dec 2015	20,000		$4.18
	Ceilings purchased (call)	July 2014 - Dec 2014	16,000		$5.91
	Ceilings sold (call)	July 2014 - Dec 2014	16,000		$5.91
					Weighted Average
	Crude Oil	Period	Bbl/day		Price per Bbl
	Collars (1)	July 2014 - Dec 2014	663		$85.00 - $91.25
		Jan 2015 - Dec 2015	259		$85.00 - $91.25
	Traditional three-way collars (2)	July 2014 - Dec 2014	4,000		$64.94 - $85.00 - $102.50
	Ceilings sold (call)	Jan 2015 - Dec 2015	1,570		$120.00
	Floors sold (put)	July 2014 - Dec 2014	663		$65.00
		Jan 2015 - Dec 2015	259		$70.00
	________________________________
	(1) A collar is a sold call and a purchased put. Some collars are "costless" collars with the premiums netting to approximately zero.
	(2) These three-way collars are a combination of three options: a sold call, a purchased put and a sold put.
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:
					Derivative Assets								Derivative Liabilities
	Derivatives not designated as hedging instruments		Balance Sheet Classification		June 30, 2014				December 31, 2013				June 30, 2014				December 31, 2013
					(in thousands)
	Commodity
			Derivative assets		$	—			$	529			$	—			$	—
			Derivative assets - long-term		123				25				—				—
			Derivative liabilities		—				—				(5,709		)		(1,903		)
			Derivative liabilities - long-term		—				—				(420		)		(376		)
	Total commodity				$	123			$	554			$	(6,129	)		$	(2,279	)
	Financial
			Derivative assets		$	317			$	79			$	—			$	—
			Derivative liabilities - long-term		—				—				(115,307		)		(75,934		)
	Total financial				$	317			$	79			$	(115,307	)		$	(75,934	)
	Total derivatives				$	440			$	633			$	(121,436	)		$	(78,213	)
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 in the Company's consolidated balance sheets as of:
		June 30, 2014
		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	$	565		565		$	—
	Long-term assets:  Fair value of derivative contracts	239			116		123
	Current liabilities:  Fair value of derivative contracts	(6,274		)	(565	)	(5,709		)
	Long-term liabilities:  Fair value of derivative contracts	(536		)	(116	)	(420		)
		$	(6,006	)	—		$	(6,006	)
		December 31, 2013
		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	$	4,034		3,505		$	529
	Long-term assets:  Fair value of derivative contracts	516			491		25
	Current liabilities:  Fair value of derivative contracts	(5,408		)	(3,505	)	(1,903		)
	Long-term liabilities:  Fair value of derivative contracts	(867		)	(491	)	(376		)
		$	(1,725	)	—		$	(1,725	)
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 six months ended June 30, 2014 and 2013:
		Three Months Ended June 30,								Six Months Ended
										June 30,
		2014				2013				2014				2013
		(in thousands)
	Gain (loss) on settled transactions	$	(2,267	)		$	(1,261	)		$	(4,551	)		$	(305	)
	Gain (loss) on open contracts	(40,569		)		7,661				(37,938		)		(786		)
	Total gain (loss)	$	(42,836	)		$	6,400			$	(42,489	)		$	(1,091	)

LONGTERM_DEBT_Tables

LONG-TERM DEBT (Tables)	6 Months Ended
	Jun. 30, 2014
Debt Disclosure [Abstract]	'
Schedule of long-term debt	'
	Long-term debt at June 30, 2014 and December 31, 2013 consisted of the following:
		June 30, 2014			December 31, 2013
		(in thousands)
	Senior Notes payable due May 15, 2020, interest rate of 9.75%, net of unamortized net discount of $2.7 million at June 30, 2014 and December 31, 2013	$	597,279		$	597,230
	Various equipment and real estate notes payable with maturity dates January 2015 - April 2021, interest rates of 4.25% - 7.94%(1)	24,395			18,615
	Eureka Hunter Pipeline Credit Agreement due March 28, 2018, interest rate of 3.66%	65,000			—
	Eureka Hunter Pipeline second lien term loan due August 16, 2018, interest rate of 12.5%	—			50,000
	MHR Senior Revolving Credit Facility due April 13, 2016, interest rate of 3.57% at June 30, 2014 and 3.56% at December 31, 2013	164,500			218,000
		851,174			883,845
	Less: current portion	(10,005		)	(3,967		)
	Total long-term debt obligations, net of current portion	$	841,169		$	879,878
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 $2.7 million:
		(in thousands)
	2014	$	3,142
	2015	9,989
	2016	173,047
	2017	2,358
	2018	65,360
	Thereafter	600,000
	Total	$	853,896
Schedule of Interest Expense	'
	The following table sets forth interest expense for the three and six month periods ended June 30, 2014 and 2013, respectively:
		Three Months Ended						Six Months Ended
		June 30,						June 30,
		2014			2013			2014		2013
		(in thousands)
	Interest expense incurred on debt, net of amounts capitalized	$	16,412		$	17,100		$	36,640	$	34,944
	Amortization and write-off of deferred financing costs	4,022			1,693			7,643		2,550
	Total Interest Expense	$	20,434		$	18,793		$	44,283	$	37,494

SHAREBASED_COMPENSATION_Tables

SHARE-BASED COMPENSATION (Tables)	6 Months Ended
	Jun. 30, 2014
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 six months ended June 30, 2014 and 2013 is presented below:
		Six Months Ended June 30,
		2014		2013		2014		2013
		(in thousands of shares)				Weighted Average Exercise Price per Share
	Outstanding at beginning of period	16,891		14,847		$	5.69	$	6.01
	Granted	—		4,363		$	—	$	4.16
	Exercised	(2,115	)	—		$	4.14	$	—
	Forfeited	(932	)	(413	)	$	6.32	$	6.61
	Outstanding at end of period	13,844		18,797		$	5.88	$	5.56
	Exercisable at end of period	9,478		11,139		$	6.2	$	5.72
Summary of non-vested shares	'
	A summary of the Company’s non-vested common stock options and stock appreciation rights for the six months ended June 30, 2014 and 2013 is presented below:
		Six Months Ended June 30,
		2014		2013
		(in thousands of shares)
	Non-vested at beginning of period	6,908		6,163
	Granted	—		4,363
	Vested	(1,801	)	(2,677	)
	Forfeited	(741	)	(191	)
	Non-vested at end of period	4,366		7,658

SHAREHOLDERS_EQUITY_Tables

SHAREHOLDERS' EQUITY (Tables)	6 Months Ended
	Jun. 30, 2014
Equity [Abstract]	'
Schedule of dividends paid	'
	A summary of the Company's preferred dividends for the three and six months ended June 30, 2014 and 2013 is presented below:
		Three Months Ended June 30,					Six Months Ended June 30,
		2014			2013		2014		2013
		(in thousands)					(in thousands)
	Dividend on Eureka Hunter Holdings Series A Preferred Units	$	4,253		$	3,556	$	8,281	$	6,670
	Accretion of the carrying value of the Eureka Hunter Holdings Series A Preferred Units	2,229			1,696		4,277		3,164
	Dividend on Series C Preferred Stock	2,562			2,562		5,124		5,124
	Dividend on Series D Preferred Stock	4,425			4,425		8,849		8,807
	Dividend on Series E Preferred Stock	1,861			1,890		3,695		3,852
	Total dividends on Preferred Stock	$	15,330		$	14,129	$	30,226	$	27,617
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share	'
	The following table summarizes the types of potentially dilutive securities outstanding as of June 30, 2014 and 2013:
		June 30,
		2014		2013
		(in thousands of shares)
	Series E Preferred Stock	10,946		11,169
	Warrants	19,214		13,376
	Unvested restricted shares	1,475		—
	Common stock options and stock appreciation rights	13,844		18,797
	Total	45,479		43,342

TAXES_Tables

TAXES (Tables)	6 Months Ended
	Jun. 30, 2014
Income Tax Disclosure [Abstract]	'
Schedule of Components of Income Tax Expense (Benefit)	'
	The Company's income tax benefit from continuing operations for the three and six months ended June 30, 2014 and 2013 was:
		Three Months Ended				Six Months Ended
		June 30,				June 30,
		2014		2013		2014		2013
		(in thousands)
	Deferred	$	—	$	39,300	$	—	$	44,199
	Income tax benefit	$	—	$	39,300	$	—	$	44,199

RELATED_PARTY_TRANSACTIONS_REL

RELATED PARTY TRANSACTIONS RELATED PARTY TRANSACTIONS (Tables)	6 Months Ended
	Jun. 30, 2014
Related Party Transactions [Abstract]	'
Schedule of Related Party Balances	'
	The following table sets forth the related party balances as of June 30, 2014 and December 31, 2013:
		June 30, 2014			December 31, 2013
		(in thousands)
	Green Hunter (1)
	Accounts payable - net	$	690		$	23
	Derivative assets (2)	$	317		$	79
	Investments (2)	$	2,423		$	2,262
	Notes receivable (2)	$	1,496		$	1,768
	Prepaid expenses	$	—		$	9
Schedule of Related Party Transactions	'
	The following table sets forth the related party transaction activities for the three and six months ended June 30, 2014 and 2013, respectively:
			Three Months Ended						Six Months Ended
			June 30,						June 30,
			2014			2013			2014		2013
			(in thousands)
	GreenHunter
		Salt water disposal (1)	$	613		$	590		$	935	$	1,446
		Equipment rental (1)	19			98			141		73
		Gas gathering-trucking (1)	400			—			400		—
		MAG tank panels (1)	800			—			800		—
		Office space rental	13			—			36		—
		Interest income from note receivable (2)	38			53			83		108
		Dividends earned from Series C shares	55			37			110		92
		Unrealized gain/(loss) on investments (2)	396			(151		)	161		(677		)
	Pilatus Hunter, LLC
		Airplane rental expenses (3)	88			20			158		67
	_________________________________
	-1	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman, a major shareholder and interim CEO. Eagle Ford Hunter received, and 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 its affiliated companies, White Top Oilfield Construction, LLC and Black Water Services, LLC. 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 8 - 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 other long-term assets and an available for sale investment in GreenHunter included in investments.
	-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.

SUPPLEMENTAL_CASH_FLOW_INFORMA1

SUPPLEMENTAL CASH FLOW INFORMATION (Tables)	6 Months Ended
	Jun. 30, 2014
Supplemental Cash Flow Elements [Abstract]	'
Schedule of Cash Flow, Supplemental Disclosures	'
	The following table summarizes cash paid (received) for interest and income taxes, as well as non-cash investing transactions:
		Six Months Ended June 30,
		2014		2013
		(in thousands)
	Cash paid for interest	$	35,679	$	34,448
	Non-cash transactions
	Non-cash consideration received from sale of assets	$	9,447	$	42,300
	Change in accrued capital expenditures	$	41,270	$	42,774
	Non-cash additions to asset retirement obligation	$	13	$	1,896
	Eureka Hunter Holdings Series A Preferred Unit dividends paid in kind	$	1,950	$	2,253

SEGMENT_REPORTING_Tables

SEGMENT REPORTING (Tables)	6 Months Ended
	Jun. 30, 2014
Segment Reporting [Abstract]	'
Details of operating activities by segment	'
	The following tables set forth operating activities by segment for the three and six months ended June 30, 2014 and 2013, respectively.
		As of and for the Three Months Ended June 30, 2014
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	78,191		$	—		$	52,117		$	7,795		$	—		$	(5,587	)	$	132,516
	Depletion, depreciation, amortization and accretion	31,187			—			3,929			837			—			—			35,953
	Loss on sale of assets, net	(316		)	—			—			(371		)	—			—			(687		)
	Other operating expenses	37,692			—			46,700			6,361			13,054			(5,418		)	98,389
	Other income (expense)	201			—			(40,457		)	(211		)	(22,498		)	—			(62,965		)
	Income (loss) from continuing operations before income tax	9,829			—			(38,969		)	757			(35,552		)	(169		)	(64,104		)
	Total income (loss) from discontinued operations, net of tax 1	(177		)	11,461			—			—			(12,776		)	169			(1,323		)
	Net income (loss)	$	9,652		$	11,461		$	(38,969	)	$	757		$	(48,328	)	$	—		$	(65,427	)
	Total assets	$	1,485,120		$	—		$	380,108		$	44,682		$	61,180		$	(7,733	)	$	1,963,357
	Total capital expenditures	$	150,143		$	(3	)	$	51,993		$	2,257		$	83		$	—		$	204,473
	_________________________________
	-1	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.
		As of and for the Three Months Ended June 30, 2013
		U.S. Upstream			Canadian Upstream			Midstream and Marketing			Oilfield Services			Corporate Unallocated			Inter-segment Eliminations			Total
		(in thousands)
	Total revenue	$	50,321		$	—		$	16,151		$	3,694		$	—		$	(2,258	)	$	67,908
	Depletion, depreciation, amortization and accretion	22,573			—			3,281			521			—			—			26,375
	(Gain) loss on sale of assets, net	1,179			—			—			4			—			—			1,183
	Other operating expenses	37,638			—			15,468			4,254			11,485			(2,258		)	66,587
	Other income (expense)	(2,589		)	—			(6,594		)	(142		)	(3,390		)	(62		)	(12,777		)
	Loss from continuing operations before income tax	(13,658		)	—			(9,192		)	(1,227		)	(14,875		)	(62		)	(39,014		)
	Income tax benefit (expense)	(1,674		)	(926		)	—			—			41,900			—			39,300
	Total income (loss) from discontinued operations, net of tax	174,724			(1,565		)	—			—			(8,453		)	62			164,768
	Net income (loss)	$	159,392		$	(2,491	)	$	(9,192	)	$	(1,227	)	$	18,572		$	—		$	165,054
	Total assets	$	1,413,298		$	248,908		$	248,965		$	34,287		$	98,469		$	(8,007	)	$	2,035,920
	Total capital expenditures	$	60,847		$	1,880		$	12,790		$	6,165		$	252		$	—		$	81,934
		As of and for the Six Months Ended June 30, 2014
		U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
		Upstream			Upstream						Services			Unallocated			Eliminations
		(in thousands)
	Total revenue	$	148,365		$	—		$	86,852		$	15,706		$	—		$	(10,963	)	$	239,960
	Depletion, depreciation, amortization and accretion	56,126			—			7,607			1,628			—			—			65,361
	Loss on sale of assets, net	3,141			—			—			(369		)	—			—			2,772
	Other operating expenses	82,421			—			78,770			13,074			23,542			(10,641		)	187,166
	Other income (expense)	(77		)	—			(40,427		)	(420		)	(45,742		)	—			(86,666		)
	Income (loss) from continuing operations before income tax	6,600			—			(39,952		)	953			(69,284		)	(322		)	(102,005		)
	Total income (loss) from discontinued operations, net of tax 1	(23,305		)	10,636			—			—			(12,776		)	322			(25,123		)
	Net income (loss)	$	(16,705	)	$	10,636		$	(39,952	)	$	953		$	(82,060	)	$	—		$	(127,128	)
	Total assets	$	1,485,120		$	—		$	380,108		$	44,682		$	61,180		$	(7,733	)	$	1,963,357
	Total capital expenditures	$	216,454		$	305		$	82,627		$	2,947		$	106		$	—		$	302,439
	_________________________________
	-1	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.
		As of and for the Six Months Ended June 30, 2013
		U.S.			Canadian			Midstream and Marketing			Oilfield			Corporate			Inter-segment			Total
		Upstream			Upstream						Services			Unallocated			Eliminations
		(in thousands)
	Total revenue	$	84,966		$	—		$	33,453		$	7,425		$	—		$	(3,702	)	$	122,142
	Depletion, depreciation, amortization and accretion	36,836			—			5,968			859			—			—			43,663
	(Gain) loss on sale of assets, net	1,160			—			—			4			—			—			1,164
	Other operating expenses	81,701			—			30,136			7,953			27,475			(3,702		)	143,563
	Other income (expense)	(4,712		)	—			(7,689		)	(231		)	(26,516		)	20			(39,128		)
	Loss from continuing operations before income tax	(39,443		)	—			(10,340		)	(1,622		)	(53,991		)	20			(105,376		)
	Income tax benefit	3,180			(926		)	—			—			41,945			—			44,199
	Total income from discontinued operations, net of tax	191,213			(1,209		)	—			—			(8,453		)	(20		)	181,531
	Net income (loss)	$	154,950		$	(2,135	)	$	(10,340	)	$	(1,622	)	$	(20,499	)	$	—		$	120,354
	Total assets	$	1,413,298		$	248,908		$	248,965		$	34,287		$	98,469		$	(8,007	)	$	2,035,920
	Total capital expenditures	$	173,191		$	14,136		$	35,085		$	14,121		$	423		$	—		$	236,956

CONDENSED_CONSOLIDATING_GUARAN1

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Tables)	6 Months Ended
	Jun. 30, 2014
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 June 30, 2014
		Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Net income (loss)	$	(71,300	)	$	14,171		$	(28,598	)	$	20,300		$	(65,427	)
	Foreign currency translation gain	—			—			1,130			—			1,130
	Unrealized loss on available for sale securities	—			(549		)	—			—			(549		)
	Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	20,741			—			—			—			20,741
	Comprehensive income (loss)	(50,559		)	13,622			(27,468		)	20,300			(44,105		)
	Comprehensive income attributable to non-controlling interest	—			—			—			780			780
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(50,559	)	$	13,622		$	(27,468	)	$	21,080		$	(43,325	)
		Three Months Ended June 30, 2013
		Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Net income (loss)	$	160,274		$	4,589		$	(30,564	)	$	30,755		$	165,054
	Foreign currency translation loss	—			—			(7,070		)	—			(7,070		)
	Unrealized gain (loss) on available for sale securities	4,700			(234		)	—			—			4,466
	Comprehensive income (loss)	164,974			4,355			(37,634		)	30,755			162,450
	Comprehensive income attributable to non-controlling interest	—			—			—			386			386
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	164,974		$	4,355		$	(37,634	)	$	31,141		$	162,836
		Six Months Ended June 30, 2014
		Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Net income (loss)	$	(139,119	)	$	(7,510	)	$	(29,459	)	$	48,960		$	(127,128	)
	Foreign currency translation loss	—			—			(1,218		)	—			(1,218		)
	Unrealized loss on available for sale securities	—			(605		)	—			—			(605		)
	Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	20,741			—			—			—			20,741
	Comprehensive income (loss)	(118,378		)	(8,115		)	(30,677		)	48,960			(108,210		)
	Comprehensive income attributable to non-controlling interest	—			—			—			889			889
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	(118,378	)	$	(8,115	)	$	(30,677	)	$	49,849		$	(107,321	)
		Six Months Ended June 30, 2013
		Magnum  Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Net income (loss)	$	111,429		$	(15,506	)	$	(23,741	)	$	48,172		$	120,354
	Foreign currency translation loss	—			—			(11,799		)	—			(11,799		)
	Unrealized gain (loss) on available for sale securities	4,700			(251		)	—			—			4,449
	Comprehensive income (loss)	116,129			(15,757		)	(35,540		)	48,172			113,004
	Comprehensive income attributable to non-controlling interest	—			—			—			889			889
	Comprehensive income (loss) attributable to Magnum Hunter Resources Corporation	$	116,129		$	(15,757	)	$	(35,540	)	$	49,061		$	113,893
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 June 30, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	ASSETS
	Current assets	$	37,995		$	75,812		$	15,539		$	(7,733	)	$	121,613
	Intercompany accounts receivable	1,083,102			—			—			(1,083,102		)	—
	Property and equipment (using successful efforts method of accounting)	5,939			1,381,891			310,195			—			1,698,025
	Investment in subsidiaries	279,116			101,485			—			(380,601		)	—
	Assets held for sale and other	17,246			88,394			38,079			—			143,719
	Total Assets	$	1,423,398		$	1,647,582		$	363,813		$	(1,471,436	)	$	1,963,357
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	63,583		$	118,934		$	51,453		$	(7,774	)	$	226,196
	Intercompany accounts payable	—			1,036,163			46,901			(1,083,064		)	—
	Long-term liabilities	765,072			39,346			180,359			—			984,777
	Redeemable preferred stock	100,000			—			149,379			—			249,379
	Shareholders' equity (deficit)	494,743			453,139			(64,279		)	(380,598		)	503,005
	Total Liabilities and Shareholders' Equity	$	1,423,398		$	1,647,582		$	363,813		$	(1,471,436	)	$	1,963,357
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Balance Sheets
	(in thousands)
		As of December 31, 2013
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	ASSETS
	Current assets	$	53,161		$	43,841		$	27,096		$	(3,372	)	$	120,726
	Intercompany accounts receivable	965,138			—			—			(965,138		)	—
	Property and equipment (using successful efforts method of accounting)	7,214			1,272,027			234,838			—			1,514,079
	Investment in subsidiaries	372,236			102,314			—			(474,550		)	—
	Other assets	17,308			100,894			103,644			—			221,846
	Total Assets	$	1,415,057		$	1,519,076		$	365,578		$	(1,443,060	)	$	1,856,651
	LIABILITIES AND SHAREHOLDERS' EQUITY
	Current liabilities	$	54,826		$	97,520		$	34,929		$	(3,410	)	$	183,865
	Intercompany accounts payable	—			921,237			43,866			(965,103		)	—
	Long-term liabilities	818,651			39,067			127,663			—			985,381
	Redeemable preferred stock	100,000			—			136,675			—			236,675
	Shareholders' equity (deficit)	441,580			461,252			22,445			(474,547		)	450,730
	Total Liabilities and Shareholders' Equity	$	1,415,057		$	1,519,076		$	365,578		$	(1,443,060	)	$	1,856,651
Schedule of condensed consolidating statements of operations	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
		Three Months Ended June 30, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Revenues	$	6		$	125,536		$	12,560		$	(5,586	)	$	132,516
	Expenses	36,512			112,757			52,768			(5,417		)	196,620
	Income (loss) from continuing operations before equity in net income of subsidiaries	(36,506		)	12,779			(40,208		)	(169		)	(64,104		)
	Equity in net income of subsidiaries	(19,314		)	(984		)	—			20,298			—
	Income (loss) from continuing operations before income tax	(55,820		)	11,795			(40,208		)	20,129			(64,104		)
	Income tax benefit (expense)	—			—			—			—			—
	Income (loss) from continuing operations	(55,820		)	11,795			(40,208		)	20,129			(64,104		)
	Income from discontinued operations, net of tax	—			2,376			1,342			171			3,889
	Gain on sale of discontinued operations, net of tax	(15,480		)	—			10,268			—			(5,212		)
	Net income (loss)	(71,300		)	14,171			(28,598		)	20,300			(65,427		)
	Net income attributable to non-controlling interest	—			—			—			780			780
	Net income (loss) attributable to Magnum Hunter Resources Corporation	(71,300		)	14,171			(28,598		)	21,080			(64,647		)
	Dividends on preferred stock	(8,848		)	—			(6,482		)	—			(15,330		)
	Net income (loss) attributable to common shareholders	$	(80,148	)	$	14,171		$	(35,080	)	$	21,080		$	(79,977	)
		Three Months Ended June 30, 2013
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Revenues	$	12		$	62,065		$	8,090		$	(2,259	)	$	67,908
	Expenses	16,577			74,612			17,930			(2,197		)	106,922
	Income (loss) from continuing operations before equity in net income of subsidiaries	(16,565		)	(12,547		)	(9,840		)	(62		)	(39,014		)
	Equity in net income of subsidiaries	(29,060		)	(113		)	(1,582		)	30,755			—
	Income (loss) from continuing operations before income tax	(45,625		)	(12,660		)	(11,422		)	30,693			(39,014		)
	Income tax benefit (expense)	41,900			(1,654		)	(946		)	—			39,300
	Income (loss) from continuing operations	(3,725		)	(14,314		)	(12,368		)	30,693			286
	Income (loss) from discontinued operations, net of tax	(8,453		)	18,903			(18,196		)	62			(7,684		)
	Gain on sale of discontinued operations, net of tax	172,452			—			—			—			172,452
	Net income (loss)	160,274			4,589			(30,564		)	30,755			165,054
	Net income attributable to non-controlling interest	—			—			—			386			386
	Net income (loss) attributable to Magnum Hunter Resources Corporation	160,274			4,589			(30,564		)	31,141			165,440
	Dividends on preferred stock	(8,877		)	—			(5,252		)	—			(14,129		)
	Net income (loss) attributable to common shareholders	$	151,397		$	4,589		$	(35,816	)	$	31,141		$	151,311
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Operations
	(in thousands)
		Six Months Ended June 30, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Revenues	$	114		$	229,550		$	21,258		$	(10,962	)	$	239,960
	Expenses	71,305			219,841			61,460			(10,641		)	341,965
	Income (loss) from continuing operations before equity in net income of subsidiaries	(71,191		)	9,709			(40,202		)	(321		)	(102,005		)
	Equity in net income of subsidiaries	(48,129		)	(829		)	—			48,958			—
	Income (loss) from continuing operations before income tax	(119,320		)	8,880			(40,202		)	48,637			(102,005		)
	Income tax benefit (expense)	—			—			—			—			—
	Income (loss) from continuing operations	(119,320		)	8,880			(40,202		)	48,637			(102,005		)
	Income from discontinued operations, net of tax	—			2,259			4,669			323			7,251
	Gain (loss) on sale of discontinued operations, net of tax	(19,799		)	(18,649		)	6,074			—			(32,374		)
	Net income (loss)	(139,119		)	(7,510		)	(29,459		)	48,960			(127,128		)
	Net income attributable to non-controlling interest	—			—			—			889			889
	Net income (loss) attributable to Magnum Hunter Resources Corporation	(139,119		)	(7,510		)	(29,459		)	49,849			(126,239		)
	Dividends on preferred stock	(17,668		)	—			(12,558		)	—			(30,226		)
	Net income (loss) attributable to common shareholders	$	(156,787	)	$	(7,510	)	$	(42,017	)	$	49,849		$	(156,465	)
	Six Months Ended June 30, 2013
	Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
	Resources			Subsidiaries			Subsidiaries						Resources
	Corporation												Corporation
													Consolidated
Revenues	$	(163	)	$	109,427		$	16,581		$	(3,703	)	$	122,142
Expenses	56,209			146,285			28,747			(3,723		)	227,518
Income (loss) from continuing operations before equity in net income of subsidiaries	(56,372		)	(36,858		)	(12,166		)	20			(105,376		)
Equity in net income of subsidiaries	(38,143		)	(642		)	(9,387		)	48,172			—
Income (loss) from continuing operations before income tax	(94,515		)	(37,500		)	(21,553		)	48,192			(105,376		)
Income tax benefit (expense)	41,945			3,200			(946		)	—			44,199
Income (loss) from continuing operations	(52,570		)	(34,300		)	(22,499		)	48,192			(61,177		)
Income (loss) from discontinued operations, net of tax	(8,453		)	18,794			(1,242		)	(20		)	9,079
Gain on sale of discontinued operations, net of tax	172,452			—			—			—			172,452
Net income (loss)	111,429			(15,506		)	(23,741		)	48,172			120,354
Net income attributable to non-controlling interest	—			—			—			889			889
Net income (loss) attributable to Magnum Hunter Resources Corporation	111,429			(15,506		)	(23,741		)	49,061			121,243
Dividends on preferred stock	(17,783		)	—			(9,834		)	—			(27,617		)
Net income (loss) attributable to common shareholders	$	93,646		$	(15,506	)	$	(33,575	)	$	49,061		$	93,626
Schedule of condensed consolidating statements of cash flows	'
	Magnum Hunter Resources Corporation and Subsidiaries
	Condensed Consolidating Statements of Cash Flows
	(in thousands)
		Six Months Ended June 30, 2014
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Cash flow from operating activities	$	(192,121	)	$	182,620		$	28,248		$	—		$	18,747
	Cash flow from investing activities	49,572			(177,365		)	(57,579		)	—			(185,372		)
	Cash flow from financing activities	111,324			3,038			19,629			—			133,991
	Effect of exchange rate changes on cash	—			—			41			—			41
	Net increase (decrease) in cash	(31,225		)	8,293			(9,661		)	—			(32,593		)
	Cash at beginning of period	47,895			(17,651		)	11,469			—			41,713
	Cash at end of period	$	16,670		$	(9,358	)	$	1,808		$	—		$	9,120
		Six Months Ended June 30, 2013
		Magnum Hunter			100% Owned Guarantor			Non Guarantor			Consolidating/ Eliminating Adjustments			Magnum Hunter
		Resources			Subsidiaries			Subsidiaries						Resources
		Corporation												Corporation
														Consolidated
	Cash flow from operating activities	$	(156,721	)	$	146,932		$	83,657		$	—		$	73,868
	Cash flow from investing activities	371,970			(152,127		)	(115,645		)	—			104,198
	Cash flow from financing activities	(224,493		)	4,051			17,852			—			(202,590		)
	Effect of exchange rate changes on cash	—			—			(357		)	—			(357		)
	Net increase (decrease) in cash	(9,244		)	(1,144		)	(14,493		)	—			(24,881		)
	Cash at beginning of period	26,871			(4,186		)	34,938			—			57,623
	Cash at end of period	$	17,627		$	(5,330	)	$	20,445		$	—		$	32,742

GENERAL_Details

GENERAL (Details) (USD $)	Jun. 30, 2014	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014
	PRC Williston, LLC (PRC)	Eureka Hunter Holdings, LLC	Eureka Hunter Holdings, LLC	Energy Hunter Securities, Inc. (EHS)	Energy Hunter Securities, Inc. (EHS)	Eureka Hunter Pipeline, LLC	Trans Tex Hunter LLC	Eureka Hunter Land, LLC	Sentra Corporation	Sentra Corporation
Summary of Significant Accounting Policies [Line Items]	'	'	'	'	'	'	'	'	'	'
Consolidated controlling interest (as a percent)	87.50%	56.54%	56.40%	'	'	'	'	'	'	'
Consolidated entities ownership percentage in entity (as a percent)	'	'	'	'	'	100.00%	100.00%	100.00%	'	'
Minimum Net Capital Required for Broker-Dealer Subsidiary	'	'	'	$5,000	'	'	'	'	'	'
Ratio of Indebtedness to Net Capital	'	'	'	0.067	'	'	'	'	'	'
Net capital	'	'	'	84,919	77,953	'	'	'	'	'
Aggregate indebtedness	'	'	'	7,289	16,657	'	'	'	'	'
Regulated operating revenue, gas	'	'	'	'	'	'	'	'	$274,827	$445,899

DIVESTITURES_AND_DISCONTINUED_2

DIVESTITURES AND DISCONTINUED OPERATIONS (Details) (USD $)	3 Months Ended			6 Months Ended			3 Months Ended	6 Months Ended	12 Months Ended	6 Months Ended
	Jun. 30, 2014		Jun. 30, 2013	Jun. 30, 2014		Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2014
							Magnum Hunter Production and Williston Hunter Canada	Magnum Hunter Production and Williston Hunter Canada	Magnum Hunter Production and Williston Hunter Canada	Magnum Hunter Production, Inc.	Eagle Ford Hunter, Inc.
Results reclassified to discontinued operations	'		'	'		'	'	'	'	'	'
Revenues	$8,234,000		$24,623,000	$20,517,000		$68,413,000	'	'	'	'	'
Expenses	-4,345,000		-30,013,000	-13,178,000		-58,238,000	'	'	'	'	'
Other income (expense)	0		1,893,000	-88,000		3,136,000	'	'	'	'	'
Income tax expense	0		-4,187,000	0		-4,232,000	'	'	'	'	'
Income (loss) from discontinued operations, net of tax	3,889,000		-7,684,000	7,251,000		9,079,000	'	'	'	'	'
Gain (loss) on disposal of discontinued operations, net of tax	-5,212,000		172,452,000	-32,374,000		172,452,000	'	-12,800,000	'	-84,500,000	172,500,000
Income (loss) from discontinued operations, net of taxes	-1,323,000	[1]	164,768,000	-25,123,000	[1]	181,531,000	'	'	'	'	'
Impairment expense from discontinued operations	'		'	'		'	18,600,000	'	18,500,000	'	'
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	$20,741,000		$0	$20,741,000		$0	($20,741,000)	($20,700,000)	'	'	'
[1]	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.

DIVESTITURES_AND_DISCONTINUED_3

DIVESTITURES AND DISCONTINUED OPERATIONS (Sale of Eagle Ford Hunter) (Details) (USD $)	3 Months Ended		6 Months Ended		1 Months Ended	3 Months Ended	6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Apr. 24, 2013	Jun. 30, 2014	Jun. 30, 2014	Apr. 24, 2013
					Eagle Ford Hunter, Inc.	Eagle Ford Hunter, Inc.	Eagle Ford Hunter, Inc.	Penn Virginia [Member]
								Eagle Ford Hunter, Inc.
Discontinued operations	'	'	'	'	'	'	'	'
Total consideration received	'	'	'	'	$422,100,000	'	'	'
Cash consideration received	'	'	'	'	379,800,000	'	'	'
Consideration received, number of shares of common stock received	'	'	'	'	'	'	'	10,000,000
Consideration received, value of common stock received	'	'	'	'	'	'	'	42,300,000
Price per share	'	'	'	'	'	'	'	$4.23
Gain (loss) on disposal of discontinued operations, net of tax	-5,212,000	172,452,000	-32,374,000	172,452,000	'	'	172,500,000	'
Liabilities of disposal group	'	'	'	'	'	33,700,000	33,700,000	'
Accrued liabilities of disposal group	'	'	'	'	'	1,300,000	1,300,000	'
Amount of adjustment to prior period gain (loss) on disposal	'	'	'	'	'	($2,700,000)	($7,000,000)	'

DIVESTITURES_AND_DISCONTINUED_4

DIVESTITURES AND DISCONTINUED OPERATIONS DIVESTITURES AND DISCONTINUED OPERATIONS (Assets and Liabilities Held for Sale) (Details)

3 Months Ended

6 Months Ended

0 Months Ended

3 Months Ended

6 Months Ended

12 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Apr. 10, 2014

Apr. 10, 2014

12-May-14

12-May-14

Jun. 30, 2014

Jun. 30, 2014

Dec. 31, 2013

Mar. 01, 2014

Jun. 30, 2014

Dec. 31, 2013

USD ($)

USD ($)

USD ($)

USD ($)

USD ($)

Williston Hunter Canada Assets

Williston Hunter Canada Assets

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

Magnum Hunter Production and Williston Hunter Canada

MHP and WHI Canada

MHP and WHI Canada

USD ($)

CAD

USD ($)

CAD

USD ($)

USD ($)

USD ($)

CAD

USD ($)

USD ($)

Assets and Liabilities Held for Sale [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accounts receivable

'

'

'

'

'

'

'

'

'

'

'

'

'

$927,000

$4,362,000

Other current assets

'

'

'

'

'

'

'

'

'

'

'

'

'

711,000

1,004,000

Oil and natural gas properties, net

'

'

'

'

'

'

'

'

'

'

'

'

'

71,935,000

150,770,000

Gas transportation, gathering, and processing equipment and other, net

'

'

'

'

'

'

'

'

'

'

'

'

'

12,972,000

11,721,000

Other long-term assets

84,935,000

'

84,935,000

'

162,687,000

'

'

'

'

'

'

'

'

28,000

196,000

Total assets held for sale

'

'

'

'

'

'

'

'

'

'

'

'

'

86,573,000

168,053,000

Accounts payable

'

'

'

'

'

'

'

'

'

'

'

'

'

7,659,000

7,292,000

Accrued liabilities and other liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

10,302,000

5,573,000

Asset retirement obligations

'

'

'

'

'

'

'

'

'

'

'

'

'

6,975,000

8,678,000

Other long-term liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

4,335,000

5,845,000

Total liabilities held for sale

17,961,000

'

17,961,000

'

12,865,000

'

'

'

'

'

'

'

'

29,271,000

27,388,000

Impairment expense from discontinued operations

'

'

'

'

'

'

'

'

'

18,600,000

'

18,500,000

'

'

'

Cash consideration on sale of certain oil and gas properties and assets

'

'

'

'

'

8,700,000

9,500,000

'

'

'

'

'

'

'

'

Gain (loss) on disposal of discontinued operations, net of tax

-5,212,000

172,452,000

-32,374,000

172,452,000

'

6,100,000

'

'

'

'

-12,800,000

'

'

'

'

Cash consideration received

'

'

'

'

'

'

'

68,800,000

75,000,000

'

'

'

'

'

'

Cash In escrow

'

'

'

'

'

'

'

'

'

'

'

'

18,400,000

'

'

Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.

($20,741,000)

$0

($20,741,000)

$0

'

'

'

'

'

$20,741,000

$20,700,000

'

'

'

'

DIVESTITURES_AND_DISCONTINUED_5

DIVESTITURES AND DISCONTINUED OPERATIONS DIVESTITURES AND DISCONTINUED OPERATIONS (Sale of Certain Eagle Ford Shale Assets) (Details) (Eagle Ford Shale Assets [Member], USD $)	0 Months Ended
In Millions, except Share data, unless otherwise specified	Jan. 28, 2014
Discontinued operations	'
Cash consideration received	$15.50
Loss on the sale of assets	4.5
Leasehold Acreage, Atascosa County, Texas [Member]	'
Discontinued operations	'
Number of horizontal oil and gas wells	5
Number of horizontal oil and gas wells operated by Magnum Hunter Resources	4
New Standard Energy Texas LLC [Member]	'
Discontinued operations	'
Consideration received, number of shares of common stock received	65,650,000
Consideration received, value of common stock received	9.4
Price per share	$0.14
Investment holding of total shares outstanding as a percent	17.00%
MHR Senior Revolving Credit Facility	'
Discontinued operations	'
Reduction in borrowing base	10
Borrowing base	$232.50

OIL_NATURAL_GAS_SALES_Details

OIL & NATURAL GAS SALES (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Oil and Gas In Process Activities [Line Items]	'	'	'	'
Oil and Gas Sales Revenue	$78,190	$49,583	$148,362	$84,224
Oil	'	'	'	'
Oil and Gas In Process Activities [Line Items]	'	'	'	'
Oil and Gas Sales Revenue	39,839	33,122	74,111	58,694
Natural Gas	'	'	'	'
Oil and Gas In Process Activities [Line Items]	'	'	'	'
Oil and Gas Sales Revenue	25,453	12,810	49,583	21,263
NGLs	'	'	'	'
Oil and Gas In Process Activities [Line Items]	'	'	'	'
Oil and Gas Sales Revenue	$12,898	$3,651	$24,668	$4,267

PROPERTY_PLANT_EQUIPMENT_Detai

PROPERTY, PLANT, & EQUIPMENT (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Mineral interests in properties:	'	'	'	'	'
Unproved leasehold costs	$538,872,000	'	$538,872,000	'	$469,337,000
Proved leasehold costs	334,918,000	'	334,918,000	'	336,357,000
Wells and related equipment and facilities	615,998,000	'	615,998,000	'	536,023,000
Advances to operators for wells in progress	20,740,000	'	20,740,000	'	13,571,000
Total costs	1,510,528,000	'	1,510,528,000	'	1,355,288,000
Less accumulated depreciation	-181,827,000	'	-181,827,000	'	-130,629,000
Net capitalized costs	1,328,701,000	'	1,328,701,000	'	1,224,659,000
Impairment of proved oil and gas properties	'	'	158,000	16,034,000	'
Proved Oil and Natural Gas Properties [Member]	'	'	'	'	'
Mineral interests in properties:	'	'	'	'	'
Depreciation, depletion and amortization	30,100,000	21,500,000	53,900,000	34,400,000	'
Impairment of proved oil and gas properties	200,000	200	10,000,000	10,000	'
Gas transportation, gathering and processing equipment and other	'	'	'	'	'
Mineral interests in properties:	'	'	'	'	'
Total costs	405,320,000	'	405,320,000	'	315,642,000
Less accumulated depreciation	-35,996,000	'	-35,996,000	'	-26,222,000
Net capitalized costs	369,324,000	'	369,324,000	'	289,420,000
Depreciation, depletion and amortization	$5,000,000	$3,600,000	$9,600,000	$6,800,000	'

PROPERTY_PLANT_EQUIPMENT_Explo

PROPERTY, PLANT, & EQUIPMENT (Exploration) (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Property, Plant and Equipment [Line Items]	'	'	'	'
Leasehold impairments	$8,834	$3,272	$22,489	$32,625
Geological and geophysical	353	274	727	654
Total exploration expense	9,187	3,546	23,216	33,279
Williston Basin [Member]	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'
Leasehold impairments	$8,834	$3,272	$19,919	$32,625

PROPERTY_PLANT_EQUIPMENT_Capit

PROPERTY, PLANT, & EQUIPMENT (Capitalized costs of oil and gas properties) (Details) (USD $)	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Capitalized costs, gross	$1,510,528,000	'	$1,510,528,000	'	$1,355,288,000
Less accumulated depreciation	-181,827,000	'	-181,827,000	'	-130,629,000
Net capitalized costs	1,328,701,000	'	1,328,701,000	'	1,224,659,000
Gas transportation, gathering and processing equipment and other	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Capitalized costs, gross	405,320,000	'	405,320,000	'	315,642,000
Less accumulated depreciation	-35,996,000	'	-35,996,000	'	-26,222,000
Net capitalized costs	369,324,000	'	369,324,000	'	289,420,000
Depreciation, depletion and amortization	5,000,000	3,600,000	9,600,000	6,800,000	'
Assets Held under Capital Leases [Member]	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
PP&E Useful life (in years)	'	'	'3 years	'	'
Capital Leases, Net Investment in Direct Financing and Sales Type Leases	11,900,000	'	11,900,000	'	'
Capital Leases, Future Minimum Payments Due, Next Twelve Months	3,400,000	'	3,400,000	'	'
Capital Leases Future Minimum Payments Due After Next Twelve Months	700,000	'	700,000	'	'
Farley Pad And Farley 1305 H	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Costs incurred	'	'	1,100,000	'	'
Farley 1305 H	'	'	'	'	'
Property, Plant and Equipment [Line Items]	'	'	'	'	'
Costs incurred	'	'	$13,800,000	'	'

INTANGIBLE_ASSETS_Details

INTANGIBLE ASSETS (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]	'	'	'	'	'
Intangible assets	$10,492	'	$10,492	'	$10,492
Less: accumulated amortization	-4,965	'	-4,965	'	-3,962
Intangible assets, net of accumulated amortization	5,527	'	5,527	'	6,530
Amortization of intangible assets	502	200	1,000	1,400	'
Customer relationships	'	'	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'	'	'
Intangible assets	5,434	'	5,434	'	5,434
Trademark	'	'	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'	'	'
Intangible assets	859	'	859	'	859
Existing contracts	'	'	'	'	'
Finite-Lived Intangible Assets [Line Items]	'	'	'	'	'
Intangible assets	$4,199	'	$4,199	'	$4,199

INVENTORY_Details

INVENTORY (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Inventory Disclosure [Abstract]	'	'
Materials and supplies	$3,440	$6,790
Commodities	390	368
Inventory	$3,830	$7,158

ASSET_RETIREMENT_OBLIGATIONS_D

ASSET RETIREMENT OBLIGATIONS (Details) (USD $)	6 Months Ended		12 Months Ended
	Jun. 30, 2014		Dec. 31, 2013
Summary of asset retirement obligation	'		'
Asset retirement obligation at beginning of period	$16,216,000		$30,680,000
Assumed in acquisitions	0		17,000
Liabilities incurred	216,000		253,000
Liabilities settled	-21,000		-98,000
Liabilities sold	-523,000		-7,614,000
Accretion expense	751,000		2,264,000
Revisions in estimated liabilities	0	[1]	1,935,000	[1]
Reclassified as liabilities associated with assets held for sale	0		-11,148,000
Effect of foreign currency translation	0		-73,000
Asset retirement obligation at end of period	16,639,000		16,216,000
Less: current portion (included in other liabilities)	-71,000		-53,000
Asset retirement obligation at end of period	16,568,000		16,163,000
Revision of estimate due to change in assumptions	$1,500,000		'
[1]	$1.5 million of the revisions in estimated liabilities is related to change in assumptions used with respect to certain wells in the Williston Basin in North Dakota during 2013.

FAIR_VALUE_OF_FINANCIAL_INSTRU2

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Recurring

Maximum

Level 1

Level 1

Level 1

Level 1

Level 1

Level 1

Level 1

Level 1

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 2

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Level 3

Recurring

Commodity derivative assets

Commodity derivative assets

Convertible security derivative assets

Convertible security derivative assets

Convertible preferred stock derivative liabilities

Convertible preferred stock derivative liabilities

Commodity derivative assets

Commodity derivative assets

Convertible security derivative assets

Convertible security derivative assets

Convertible preferred stock derivative liabilities

Convertible preferred stock derivative liabilities

Commodity derivative assets

Commodity derivative assets

Convertible security derivative assets

Convertible security derivative assets

Convertible preferred stock derivative liabilities

Convertible preferred stock derivative liabilities

Level 3

Convertible preferred stock derivative liabilities

Fair Value of Financial Instruments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit spread rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.50%

Total enterprise value

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$608,000,000

'

'

Assumptions and methodology used for calculating fair value of assets and liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Life

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years 7 months 6 days

'

'

'

'2 years

Risk-free interest rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.85%

'

'

'

'

Estimated volatility

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

40.00%

'

'

'

24.00%

Dividend

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.00%

'

'

'

'

GreenHunter stock price at end of period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1.99

'

'

'

'

Fair value measurements on a Recurring Basis

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Available for sale securities

10,661,000

[1]

1,819,000

[1]

10,661,000

1,819,000

'

'

'

'

'

'

0

0

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

Derivative assets

'

'

'

'

0

0

0

0

'

'

'

'

123,000

554,000

0

0

'

'

'

'

0

0

317,000

79,000

'

'

'

Total assets at fair value

'

'

10,661,000

1,819,000

'

'

'

'

'

'

123,000

554,000

'

'

'

'

'

'

317,000

79,000

'

'

'

'

'

'

'

Derivative liabilities

'

'

'

'

0

0

'

'

0

0

'

'

6,129,000

2,279,000

'

'

0

0

'

'

0

0

'

'

115,307,000

75,934,000

'

Total liabilities at fair value

'

'

$0

$0

'

'

'

'

'

'

$6,129,000

$2,279,000

'

'

'

'

'

'

$115,307,000

$75,934,000

'

'

'

'

'

'

'

[1]

Available for sale securities includes $123,000 that has been classified as held for sale associated with the classification of MHP as a discontinued operation.

FAIR_VALUE_OF_FINANCIAL_INSTRU3

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 2) (Level 3, USD $)	6 Months Ended			6 Months Ended	3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014
	Preferred Stock Embedded Derivative Liability	Embedded Derivatives, Assets	Recurring	Recurring	Minimum	Maximum	Eureka Hunter Holdings, LLC	Eureka Hunter Holdings, LLC
	Embedded Derivatives, Liabilities	Convertible Security Embedded Derivative Financial Instruments [Member]	Preferred Stock Embedded Derivative Liability	Convertible Security Embedded Derivative Financial Instruments [Member]	Recurring	Recurring	Minimum	Maximum
					Preferred Stock Embedded Derivative Liability	Preferred Stock Embedded Derivative Liability	Recurring	Recurring
							Preferred Stock Embedded Derivative Liability	Preferred Stock Embedded Derivative Liability
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation [Line Items]	'	'	'	'	'	'	'	'
Expected term	'	'	'	'2 years 7 months 6 days	'1 year	'2 years	'0 years	'6 years
Estimated volatility	'	'	'	40.00%	'	24.00%	'	'
Fair Value, Liabilities Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'	'	'	'	'	'	'	'
31-Dec-13	($75,934,000)	'	'	'	'	'	'	'
Issuance of derivative liability	-5,479,000	'	'	'	'	'	'	'
Decrease in fair value recognized in other income (expense)	-33,894,000	'	'	'	'	'	'	'
30-Jun-14	-115,307,000	'	'	'	'	'	'	'
Fair Value, Assets Measured on Recurring Basis, Unobservable Input Reconciliation, Calculation [Roll Forward]	'	'	'	'	'	'	'	'
Fair value at December 31, 2013 Convertible Security Embedded Derivative Asset	'	79,000	'	'	'	'	'	'
Issuance of derivative liability Convertible Security Embedded Derivative Asset	'	0	'	'	'	'	'	'
Decrease in fair value recognized in other (expense) Convertible Security Embedded Derivative Asset	'	238,000	'	'	'	'	'	'
Fair value as of June 30, 2014 Convertible Security Embedded Derivative Asset	'	317,000	'	'	'	'	'	'
Fair Value Assumptions Credit Spread Rate	'	'	'	'	'	10.50%	'	'
Business Acquisition, Cost of Acquired Entity, Total Enterprise Value	'	'	$608,000,000	'	'	'	$406,000,000	$1,000,000,000

FAIR_VALUE_OF_FINANCIAL_INSTRU4

FAIR VALUE OF FINANCIAL INSTRUMENTS (Details 4) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Level 2 | Carrying Amount | Senior Notes	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	$597,279	$597,230
Level 2 | Estimated Fair Value | Senior Notes	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	666,000	651,300
Level 3 | Carrying Amount | MHR Senior Revolving Credit Facility	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	164,500	218,000
Level 3 | Carrying Amount | Eureka Hunter Pipeline second lien term loan	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	0	50,000
Level 3 | Carrying Amount | Eureka Hunter Pipeline Credit Agreement	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	65,000	0
Level 3 | Carrying Amount | Equipment Notes Payable	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	24,395	18,615
Level 3 | Estimated Fair Value | MHR Senior Revolving Credit Facility	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	164,500	218,000
Level 3 | Estimated Fair Value | Eureka Hunter Pipeline second lien term loan	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	0	58,921
Level 3 | Estimated Fair Value | Eureka Hunter Pipeline Credit Agreement	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	65,000	0
Level 3 | Estimated Fair Value | Equipment Notes Payable	'	'
Carrying amounts and fair values of long-term debt	'	'
Fair value of senior notes	$24,303	$17,676

FINANCIAL_INSTRUMENTS_AND_DERI2

FINANCIAL INSTRUMENTS AND DERIVATIVES INVESTMENTS BY TYPE (Details) (USD $)	6 Months Ended
	Jun. 30, 2014
Schedule of Available-for-sale Securities [Line Items]	'
Available-for-sale Securities, beginning of period	$1,819,000	[1]
Securities received as consideration for assets sold	9,447,000	[1]
Change in fair value recognized in other comprehensive loss	-605,000	[1]
Available-for-sale Securities, end of period	10,661,000	[1]
Current available-for-sale securities	10,538,000
Equity Method Investments, end of period	940,000	[2]
Equity in net loss recognized in other income (expense)	-403,000	[2]
Equity Method Investments, end of period	537,000	[2]
Equity Method Investments, Noncurrent	304,000
MHP Subsidiary [Member]	'
Schedule of Available-for-sale Securities [Line Items]	'
Current available-for-sale securities	123,000
Long Term Assets [Member]	'
Schedule of Available-for-sale Securities [Line Items]	'
Equity Method Investments, Noncurrent	$304,000
[1]	Available for sale securities includes $123,000 that has been classified as held for sale associated with the classification of MHP as a discontinued operation.
[2]	Equity method investments includes $304,000 classified as long-term other assets.

FINANCIAL_INSTRUMENTS_AND_DERI3

FINANCIAL INSTRUMENTS AND DERIVATIVES INVESTMENTS BY BALANCE SHEET LOCATION (Details) (USD $)	Jun. 30, 2014		Dec. 31, 2013
Schedule of Available-for-sale Securities [Line Items]	'		'
Available-for-sale Securities, Current	$10,538,000		'
Equity Method Investments, Current	233,000		'
Investments, Available-for-sale and Equity Method, Current	10,771,000		'
Available-for-sale Securities, Noncurrent	0		'
Equity Method Investments, Noncurrent	304,000		'
Investments, Available-for-sale and Equity Method, Noncurrent	304,000		'
Available-for-sale Securities	10,661,000	[1]	1,819,000	[1]
Equity Method Investments	537,000	[2]	940,000	[2]
Investments, Available-for-sale and Equity Method, Current and Noncurrent	11,198,000		'
Long Term Assets [Member]	'		'
Schedule of Available-for-sale Securities [Line Items]	'		'
Equity Method Investments, Noncurrent	304,000		'
MHP Subsidiary [Member]	'		'
Schedule of Available-for-sale Securities [Line Items]	'		'
Available-for-sale Securities, Current	$123,000		'
[1]	Available for sale securities includes $123,000 that has been classified as held for sale associated with the classification of MHP as a discontinued operation.
[2]	Equity method investments includes $304,000 classified as long-term other assets.

FINANCIAL_INSTRUMENTS_AND_DERI4

FINANCIAL INSTRUMENTS AND DERIVATIVES INVESTMENTS, FAIR VALUE (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Investments, Debt and Equity Securities [Abstract]	'	'
Equity Securities, Amortized Cost	$9,875	$428
Equity Securities, Gross Unrealized Gain	0	0
Equity Securities, Gross Unrealized Loss	-1,404	-281
Equity Securities	8,471	147
Equity Securities, Related Party, Amortized Cost Basis	2,200	2,200
Equity Securities, Related Party, Gross Unrealized Gain	0	0
Equity Securities, Related Party, Gross Unrealized Loss	-10	-528
Equity Securities, Related Party	2,190	1,672
Equity Securities, Including Related Party, Amortized Cost Basis	12,075	2,628
Equity Securities, Including Related Party, Gross Unrealized Gain	0	0
Equity Securities, Including Related Party, Gross Unrealized Loss	-1,414	-809
Equity Securities, Including Related Party	$10,661	$1,819

FINANCIAL_INSTRUMENT_AND_DERIV

FINANCIAL INSTRUMENT AND DERIVATIVES (Commodity Derivatives) (Details)	6 Months Ended
	Jun. 30, 2014
Natural Gas | Swap [Member]	'
Derivative [Line Items]	'
Weighted Average Price	4.23
Natural Gas | July 2014 to December 2014 [Member] | Collars [Member]	'
Derivative [Line Items]	'
MMBtu/day	15,000
Natural Gas | July 2014 to December 2014 [Member] | Swap [Member]	'
Derivative [Line Items]	'
MMBtu/day	31,000
Natural Gas | July 2014 to December 2014 [Member] | Call Option [Member]	'
Derivative [Line Items]	'
MMBtu/day	16,000
Weighted Average Price	5.91
Natural Gas | January 2015 to December 2015 [Member] | Swap [Member]	'
Derivative [Line Items]	'
MMBtu/day	20,000
Weighted Average Price	4.18
Crude Oil [Member] | July 2014 to December 2014 [Member] | Collars [Member]	'
Derivative [Line Items]	'
Bbl/day	663
Crude Oil [Member] | July 2014 to December 2014 [Member] | Three Way Collars [Member]	'
Derivative [Line Items]	'
Bbl/day	4,000
Weighted Average Price	85	[1]
Crude Oil [Member] | July 2014 to December 2014 [Member] | Put Option [Member]	'
Derivative [Line Items]	'
Bbl/day	663
Weighted Average Price	65
Crude Oil [Member] | January 2015 to December 2015 [Member] | Collars [Member]	'
Derivative [Line Items]	'
Bbl/day	259
Crude Oil [Member] | January 2015 to December 2015 [Member] | Call Option [Member]	'
Derivative [Line Items]	'
Bbl/day	1,570
Weighted Average Price	120
Crude Oil [Member] | January 2015 to December 2015 [Member] | Put Option [Member]	'
Derivative [Line Items]	'
Bbl/day	259
Weighted Average Price	70
Maximum | Natural Gas | July 2014 to December 2014 [Member] | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	5.23	[2]
Maximum | Crude Oil [Member] | July 2014 to December 2014 [Member] | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	91.25	[2]
Maximum | Crude Oil [Member] | July 2014 to December 2014 [Member] | Three Way Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	102.5	[1]
Maximum | Crude Oil [Member] | January 2015 to December 2015 [Member] | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	91.25	[2]
Minimum | Natural Gas | July 2014 to December 2014 [Member] | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	4.27	[2]
Minimum | Crude Oil [Member] | July 2014 to December 2014 [Member] | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	85	[2]
Minimum | Crude Oil [Member] | July 2014 to December 2014 [Member] | Three Way Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	64.94	[1]
Minimum | Crude Oil [Member] | January 2015 to December 2015 [Member] | Collars [Member]	'
Derivative [Line Items]	'
Weighted Average Price	85	[2]
[1]	These three-way collars are a combination of three options: a sold call, a purchased put and a sold put.
[2]	A collar is a sold call and a purchased put. Some collars are "costless" collars with the premiums netting to approximately zero.

FINANCIAL_INSTRUMENTS_AND_DERI5

FINANCIAL INSTRUMENTS AND DERIVATIVES (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivatives, Fair Value	'	'
Derivative Assets	$440	$633
Derivative Liabilities	-121,436	-78,213
Commodity	'	'
Derivatives, Fair Value	'	'
Derivative Assets	123	554
Derivative Liabilities	-6,129	-2,279
Financial	'	'
Derivatives, Fair Value	'	'
Derivative Assets	317	79
Derivative Liabilities	-115,307	-75,934
Derivative assets | Commodity	'	'
Derivatives, Fair Value	'	'
Derivative Assets	0	529
Derivative assets | Financial	'	'
Derivatives, Fair Value	'	'
Derivative Assets	317	79
Derivative assets - long-term | Commodity	'	'
Derivatives, Fair Value	'	'
Derivative Assets	123	25
Derivative liabilities | Commodity	'	'
Derivatives, Fair Value	'	'
Derivative Liabilities	-5,709	-1,903
Derivative liabilities - long-term | Commodity	'	'
Derivatives, Fair Value	'	'
Derivative Liabilities	-420	-376
Derivative liabilities - long-term | Financial	'	'
Derivatives, Fair Value	'	'
Derivative Liabilities	($115,307)	($75,934)

FINANCIAL_INSTRUMENTS_AND_DERI6

FINANCIAL INSTRUMENTS AND DERIVATIVES (Effect of Master Netting) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Derivative [Line Items]	'	'
Derivative Assets	$440	$633
Derivative Asset, Fair Value, Amount Not Offset Against Collateral	-6,006	-1,725
Derivative, Fair Value, Amount Offset Against Collateral, Net	0	0
Derivative, Fair Value, Net	-6,006	-1,725
Current Assets [Member]	'	'
Derivative [Line Items]	'	'
Derivative Assets	565	4,034
Derivative Asset, Fair Value, Amount Offset Against Collateral	565	3,505
Derivative assets	0	529
Long Term Assets [Member]	'	'
Derivative [Line Items]	'	'
Derivative Assets	239	516
Derivative Asset, Fair Value, Amount Offset Against Collateral	116	491
Derivative assets	123	25
Current Liabilities [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-6,274	-5,408
Derivative Liability, Fair Value, Amount Offset Against Collateral	-565	-3,505
Derivative Liability	-5,709	-1,903
Long-term Liabilities [Member]	'	'
Derivative [Line Items]	'	'
Derivative Liability, Fair Value, Gross Liability	-536	-867
Derivative Liability, Fair Value, Amount Offset Against Collateral	-116	-491
Derivative Liability	($420)	($376)

FINANCIAL_INSTRUMENTS_AND_DERI7

FINANCIAL INSTRUMENTS AND DERIVATIVES (Details 3) (Commodity derivative assets, Other Income (Expense) [Member], USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Summary of net gain (loss) on derivative contracts	'	'	'	'
Gain (loss) on derivative contracts	($42,836)	$6,400	($42,489)	($1,091)
Settled Transaction [Member]	'	'	'	'
Summary of net gain (loss) on derivative contracts	'	'	'	'
Gain (loss) on derivative contracts	-2,267	-1,261	-4,551	-305
Open Transaction [Member]	'	'	'	'
Summary of net gain (loss) on derivative contracts	'	'	'	'
Gain (loss) on derivative contracts	($40,569)	$7,661	($37,938)	($786)

LONGTERM_DEBT_Details

LONG-TERM DEBT (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2012

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Mar. 28, 2014

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Senior Notes

Senior Notes

Notes Payable, Other Payables [Member]

Notes Payable, Other Payables [Member]

Notes Payable, Other Payables [Member]

Notes Payable, Other Payables [Member]

Notes Payable, Other Payables [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Term Loan [Member]

Term Loan [Member]

Term Loan [Member]

Term Loan [Member]

Term Loan [Member]

9.75 Percent Senior Notes Due May 15, 2020 [Member]

9.75 Percent Senior Notes Due May 15, 2020 [Member]

Notes Payable Due January 2015 - April 2021 [Member]

Notes Payable Due January 2015 - April 2021 [Member]

Notes Payable Due January 2015 - April 2021 [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

2.96 and 3.56 Percent Revolving Credit Facility due April 2016 and December 2013 [Member]

2.96 and 3.56 Percent Revolving Credit Facility due April 2016 and December 2013 [Member]

Eureka Hunter Pipeline, LLC

Eureka Hunter Pipeline, LLC

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt, outstanding

$851,174,000

$883,845,000

$597,279,000

$597,230,000

'

'

$24,395,000

[1]

'

$18,615,000

[1]

$65,000,000

$0

$164,500,000

$218,000,000

$0

$50,000,000

$50,000,000

'

'

Less: current portion

-10,005,000

-3,967,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Total long-term debt obligations, net of current portion

841,169,000

879,878,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liabilities associated with assets held for sale

'

'

'

'

4,600,000

200,000

'

'

'

'

'

'

'

'

'

'

'

'

Long-term liabilities associated with assets held for sale

11,310,000

14,523,000

'

'

2,200,000

3,800,000

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt, stated interest rate

'

'

9.75%

9.75%

'

'

'

'

'

3.66%

3.66%

3.57%

3.56%

'

'

'

12.50%

12.50%

Long-term debt, unamortized discount

'

'

$2,700,000

$2,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt, stated interest rate, minimum

'

'

'

'

'

'

4.25%

4.25%

'

'

'

'

'

'

'

'

'

'

Long-term debt, stated interest rate, maximum

'

'

'

'

'

'

7.94%

7.94%

'

'

'

'

'

'

'

'

'

'

[1]

Includes notes classified as liabilities associated with assets held for sale of which $4.6 million is current and $2.2 million is long-term at June 30, 2014, and $0.2 million is current and $3.8 million is long-term at December 31, 2013.

LONGTERM_DEBT_Expected_Annual_

LONG-TERM DEBT (Expected Annual Maturities of Debt) (Details) (USD $)	Jun. 30, 2014	Dec. 31, 2013
Summary of approximate annual maturities of debt	'	'
2014	$3,142,000	'
2015	9,989,000	'
2016	173,047,000	'
2017	2,358,000	'
2018	65,360,000	'
Thereafter	600,000,000	'
Total long-term debt, outstanding	853,896,000	'
Senior Notes | 9.75 Percent Senior Notes Due May 15, 2020 [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term debt, unamortized discount	$2,700,000	$2,700,000

LONGTERM_DEBT_MHR_Senior_Revol

LONG-TERM DEBT (MHR Senior Revolving Credit Facility) (Details) (USD $)

0 Months Ended

0 Months Ended

6-May-14

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

6-May-14

Dec. 31, 2013

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

6-May-14

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Letter of Credit [Member]

Letter of Credit [Member]

Period On or Before July 1, 2014 [Member]

Period July 1, 2014 [Member]

Line of Credit [Member]

Fiscal Quarters Ending June 30, 2014 and September 30, 2014 [Member]

Line of Credit [Member]

Fiscal Quarter Ending December 31, 2014 [Member]

Fiscal Quarter Ending March 31, 2015 and Each Quarter Thereafter [Member]

Alternate Base Rate [Member]

Eurodollar [Member]

Minimum

Minimum

Minimum

Minimum

Maximum

Maximum

Maximum

Maximum

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

MHR Senior Revolving Credit Facility

MHR Senior Revolving Credit Facility

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Line of Credit [Member]

Line of Credit [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Line of Credit [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Line of Credit [Member]

Line of Credit [Member]

Period May 6, 2014 Through July 1, 2014 [Member]

Period May 6, 2014 Through July 1, 2014 [Member]

Alternate Base Rate [Member]

Alternate Base Rate [Member]

Eurodollar [Member]

Eurodollar [Member]

Alternate Base Rate [Member]

Alternate Base Rate [Member]

Eurodollar [Member]

Eurodollar [Member]

MHR Senior Revolving Credit Facility [Member]

MHR Senior Revolving Credit Facility [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Line of Credit [Member]

Line of Credit [Member]

Period From July 1, 2014 Through Date of Delivery of Compliance Certificate for Quarter Ending June 30, 2014 [Member]

Period From Delivery of Compliance Certificate and After [Member]

Period From July 1, 2014 Through Date of Delivery of Compliance Certificate for Quarter Ending June 30, 2014 [Member]

Period From Delivery of Compliance Certificate and After [Member]

Period From July 1, 2014 Through Date of Delivery of Compliance Certificate for Quarter Ending June 30, 2014 [Member]

Period From Delivery of Compliance Certificate and After [Member]

Period From July 1, 2014 Through Date of Delivery of Compliance Certificate for Quarter Ending June 30, 2014 [Member]

Period From Delivery of Compliance Certificate and After [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Amendment to Third Amended and Restated Credit Agreement [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

$325,000,000

$232,500,000

'

'

$50,000,000

$10,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liens percentage used in reserve reports for borrowing base determinations

90.00%

80.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base

'

'

272,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Credit facility amount outstanding

'

'

164,500,000

218,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing capacity limit increase

750,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reduction of borrowing base

'

'

'

'

'

'

25,000,000

25,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reduction of borrowing base for each dollar of additional senior notes

'

'

'

'

'

'

'

$0.25

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Reduction of borrowing base, percent of net proceeds from issuance of common equity

'

'

'

'

'

'

50.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, basis spread on variable rate

'

'

'

'

'

'

'

'

'

'

'

'

'

2.75%

3.75%

1.50%

1.00%

2.50%

2.00%

2.25%

1.75%

3.25%

2.75%

Required minimum consolidated Current Ratio

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

EBITDAX to interest expense

'

'

'

'

'

'

'

'

200.00%

225.00%

250.00%

'

'

'

'

'

'

'

'

'

'

'

'

Required maximum ratio of Total Debt to EBITDAX

'

'

'

'

'

'

'

'

'

4.75

'

4.5

4.25

'

'

'

'

'

'

'

'

'

'

LONGTERM_DEBT_Eureka_Hunter_Pi

LONG-TERM DEBT (Eureka Hunter Pipeline Credit Agreement) (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Jun. 30, 2014

Mar. 28, 2014

Dec. 31, 2013

Jan. 21, 2014

Mar. 28, 2014

Jun. 30, 2014

Dec. 31, 2013

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Mar. 28, 2014

Term Loan [Member]

Term Loan [Member]

Term Loan [Member]

Notes Payable, Other Payables [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Minimum

Minimum

Maximum

Maximum

Revolving Credit Facility [Member]

Fiscal Quarter Ending March 31, 2014 Through September 30, 2014 [Member]

Commitment Fee Percent When Consolidated Leverage Ratio is Less Than 3 to 1 [Member]

Commitment Fee Percent When Consolidated Leverage Ratio is Greater or Equal to 3 to 1 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

12.5 Percent Term Loan due August 16, 2018 [Member]

7.94 Percent Equipment Note Payable [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Line of Credit [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

Line of Credit [Member]

Line of Credit [Member]

Line of Credit [Member]

Eurodollar [Member]

Federal Funds Rate

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

5.75 Percent Credit Agreement due March 28, 2018 [Member]

Eurodollar [Member]

Base Rate [Member]

Eurodollar [Member]

Base Rate [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base

'

'

'

'

'

'

$117,000,000

$72,200,000

'

'

'

'

'

'

'

'

'

'

'

Borrowing capacity limit increase

'

'

'

'

'

'

150,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Deferred finance costs

'

'

'

'

'

'

1,200,000

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt

851,174,000

883,845,000

0

50,000,000

50,000,000

'

'

65,000,000

0

'

'

'

'

'

'

'

'

'

'

Line of credit facility, commitment fee percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.38%

0.50%

Consolidated leverage ratio

'

'

'

'

'

'

3

'

'

'

'

'

'

'

'

'

'

'

'

Debt instrument, basis spread on variable rate

'

'

'

'

'

'

'

'

'

1.00%

0.50%

2.00%

1.00%

3.50%

2.50%

'

'

'

'

Interest rate increase under default

'

'

'

'

'

'

2.00%

'

'

'

'

'

'

'

'

'

'

'

'

Maximum leverage ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4.5

4.75

'

'

Minimum interest coverage ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2.5

2.75

'

'

Credit facility amount outstanding

'

'

'

'

'

'

'

-65,000,000

'

'

'

'

'

'

'

'

'

'

'

Prepayment penalty

'

'

2,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued interest

'

'

'

1,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Face amount

'

'

'

'

'

$5,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt, stated interest rate

'

'

'

'

'

7.94%

'

3.66%

3.66%

'

'

'

'

'

'

'

'

'

'

Term of note payable

'

'

'

'

'

'48 months

'

'

'

'

'

'

'

'

'

'

'

'

'

LONGTERM_DEBT_Interest_Expense

LONG-TERM DEBT (Interest Expense) (Details) (USD $)	3 Months Ended		6 Months Ended				3 Months Ended		6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2014	Jun. 30, 2014	Mar. 31, 2013	Jun. 30, 2014	Jun. 30, 2013
					Amendment to Third Amended and Restated Credit Agreement [Member]	Term Loan [Member]	Oil and Gas Properties [Member]	Oil and Gas Properties [Member]	Oil and Gas Properties [Member]	Oil and Gas Properties [Member]
						12.5 Percent Term Loan due August 16, 2018 [Member]
Debt Instrument [Line Items]	'	'	'	'	'	'	'	'	'	'
Interest costs capitalized	'	'	'	'	'	'	$219,000	$573,000	$800,000	$1,400,000
Prepayment penalty	'	'	'	'	'	2,200,000	'	'	'	'
Write off of unamortized deferred financing costs	'	'	2,700,000	'	1,700,000	'	'	'	'	'
Interest expense incurred on debt, net of amounts capitalized	16,412,000	17,100,000	36,640,000	34,944,000	'	'	'	'	'	'
Amortization and write-off of deferred financing costs	4,022,000	1,693,000	7,643,000	2,550,000	'	'	'	'	'	'
Total Interest Expense	$20,434,000	$18,793,000	$44,283,000	$37,494,000	'	'	'	'	'	'

SHAREBASED_COMPENSATION_Detail

SHARE-BASED COMPENSATION (Details) (USD $)

3 Months Ended

6 Months Ended

6 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

0 Months Ended

0 Months Ended

Jun. 30, 2013

Jun. 30, 2012

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2011

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

12-May-14

12-May-14

12-May-14

12-May-14

Stock options and stock appreciation rights

Stock options and stock appreciation rights

Stock options and stock appreciation rights

Restricted stock

Restricted stock

Restricted stock

Restricted stock

Restricted stock

Restricted stock

Restricted stock

Eureka Hunter Holdings Plan

Eureka Hunter Holdings Plan

Eureka Hunter Holdings Plan

Eureka Hunter Holdings Plan

Officers executives and employees

Officers executives and employees

Board of directors

Board of directors

Class B Common Units

Class B Common Units

Incentive Plan Units

Incentive Plan Units

Share Based Compensation

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares authorized under the plan

'

'

27,500,000

'

'

'

'

'

'

'

'

'

'

'

'

2,336,905

'

2,336,905

Number of shares issued under the plan

'

'

9,610,873

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock options, granted

'

'

'

'

'

'

'

'

'

'

1,352,575

'

123,798

'

'

'

'

'

Award vesting period

'

'

'

'

'

'

'

'

'

'1 year

'3 years

'

'

'

'5 years

'

'

'

Estimated future forfeiture rate

'

'

'

'

'

'

'

'

'

'

'

'

'

3.40%

'

'

'

'

Vesting rights percentage

'

'

'

'

'

'

'

'

'

'

33.00%

'

100.00%

'

'

'

'

'

Vesting Period for One Third of Shares

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

Share based compensation

$2,300,000

$2,449,000

$3,375,000

$8,699,000

'

'

'

'

'

'

'

'

'

$10,800,000

'

'

'

'

Grants under the plan

'

'

'

'

'

'

'

'

'

'

'

'

'

'

894,102

'

894,102

'

Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at beginning of period (in shares)

'

'

'

'

16,891,000

'

14,847,000

'

'

'

'

'

'

'

'

'

'

'

Granted (in shares)

'

'

'

'

0

4,363,000

'

'

'

'

'

'

'

'

'

'

'

'

Exercised (in shares)

'

'

'

'

-2,115,000

0

'

'

'

'

'

'

'

'

'

'

'

'

Cancelled (in shares)

'

'

'

'

-932,000

-413,000

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at end of period (in shares)

'

'

'

'

13,844,000

18,797,000

14,847,000

'

'

'

'

'

'

'

'

'

'

'

Exercisable at end of period (in shares)

'

'

'

'

9,478,000

11,139,000

'

'

'

'

'

'

'

'

'

'

'

'

Weighted Average Exercise Price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at beginning of period (in dollars per share)

'

'

'

'

$5.69

'

$6.01

'

'

'

'

'

'

'

'

'

'

'

Granted (in dollars per share)

'

'

'

'

$0

$4.16

'

'

'

'

'

'

'

'

'

'

'

'

Exercised (in dollars per share)

'

'

'

'

$4.14

$0

'

'

'

'

'

'

'

'

'

'

'

'

Cancelled (in dollars per share)

'

'

'

'

$6.32

$6.61

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding at end of period (in dollars per share)

'

'

'

'

$5.88

$5.56

$6.01

'

'

'

'

'

'

'

'

'

'

'

Exercisable at end of period (in dollars per share)

'

'

'

'

$6.20

$5.72

'

'

'

'

'

'

'

'

'

'

'

'

Non-vested Shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Non-vested at beginning of period (in shares)

'

'

'

'

6,908,000

'

6,163,000

'

'

'

'

'

'

'

'

'

'

'

Granted (in shares)

'

'

'

'

0

4,363,000

'

'

'

'

'

'

'

'

'

'

'

'

Vested (in shares)

'

'

'

'

-1,801,000

-2,677,000

'

'

'

'

'

'

'

'

'

'

'

'

Cancelled (in shares)

'

'

'

'

-741,000

-191,000

'

'

'

'

'

'

'

'

'

'

'

'

Non-vested at end of period (in shares)

'

'

'

'

4,366,000

7,658,000

6,163,000

'

'

'

'

'

'

'

'

'

'

'

Additional disclosures

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Unrecognized compensation cost

'

'

'

'

$6,300,000

$14,300,000

'

$8,300,000

$200,000

'

'

'

'

'

'

'

'

'

Weighted average period for recognition of compensation cost

'

'

'

'

'1 year 3 months 18 days

'

'

'2 years 4 months 24 days

'

'

'

'

'

'

'

'

'

'

Remaining contractual term

'

'

'

'

'5 years 9 months 18 days

'

'

'

'

'

'

'

'

'

'

'

'

'

SHAREHOLDERS_EQUITY_Details

SHAREHOLDERS’ EQUITY (Details) (USD $)

3 Months Ended

6 Months Ended

1 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

3 Months Ended

6 Months Ended

1 Months Ended

In Thousands, except Share data, unless otherwise specified

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

31-May-14

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

Jun. 30, 2014

Jun. 30, 2013

31-May-14

Common Stock

Common Stock

Depositary Shares

Class A Preferred Units

Class A Preferred Units

Class A Preferred Units

Class A Preferred Units

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series C Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series D Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Series E Preferred Stock

Common Stock

Dilutive [Member]

Dilutive [Member]

Series E Preferred Stock

Series E Preferred Stock

Warrant [Member]

Warrant [Member]

Unvested restricted shares

Unvested restricted shares

Common stock options and stock appreciation rights

Common stock options and stock appreciation rights

Common Stock Warrant [Member]

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Dilutive [Member]

Class of Stock [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

45,479,000

43,342,000

10,946,000

11,169,000

19,214,000

13,376,000

1,475,000

0

13,844,000

18,797,000

'

Shares issued in connection with share-based compensation

'

'

47,426

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Shares of common stock issued upon exercise of common stock options

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,115,000

'

'

'

'

'

'

'

'

'

'

'

Dividends, ratio of warrants received per common stock

'

'

'

'

'

10.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stocks issued (in Shares)

'

'

'

'

21,428,580

'

'

'

'

610,000

'

'

'

'

'

'

'

'

'

'

'

'

'

25,729,000

'

'

'

'

'

'

'

'

'

'

'

Proceeds from stock issuance

'

'

'

$10,181

'

'

$28,900

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest in share of Series E Preferred Stock per Depository Share

'

'

'

'

'

'

0.001

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock issued in connection with acquisition (in shares)

'

'

'

'

'

'

4,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share price

'

'

'

'

$7

'

$7

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock dividends

15,330

14,129

30,226

27,617

'

'

'

4,253

3,556

8,281

6,670

2,562

2,562

5,124

5,124

4,425

4,425

8,849

8,807

1,861

1,890

3,695

3,852

'

'

'

'

'

'

'

'

'

'

'

'

Accretion of the difference between the carrying value and the redemption value of preferred stock included in dividends

2,229

1,696

4,277

3,164

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Stock Issued, value

'

'

$178,575

'

$149,700

'

'

'

'

$12,000

'

'

'

'

'

'

'

'

'

'

'

'

'

$257

'

'

'

'

'

'

'

'

'

'

'

Warrants Exercised Number

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,142,858

Exercise price of warrant

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8.5

Redemption price

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

Redemption period notice

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'30 days

REDEEMABLE_PREFERRED_STOCK_Det

REDEEMABLE PREFERRED STOCK (Details) (USD $)	3 Months Ended		6 Months Ended						6 Months Ended
	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Dec. 31, 2013	Jun. 30, 2014	Jun. 30, 2014	Apr. 14, 2014
					Level 3	Level 3	Series A Preferred Units	Series A Preferred Units	Series A Preferred Units	Series A Preferred Units	Series A Preferred Units
					Derivative Financial Instruments, Liabilities	Derivative Financial Instruments, Liabilities			Eureka Hunter Holdings, LLC	Eureka Hunter Holdings, LLC	Eureka Hunter Holdings, LLC
					Preferred Stock Embedded Derivative Liability	Preferred Stock Embedded Derivative Liability				Ridgeline Midstream Holdings, LLC	Ridgeline Midstream Holdings, LLC
Class of Stock [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Maximum purchase commitment amount	'	'	'	'	'	'	'	'	'	'	$200,000,000
Proceeds from sale of Eureka Hunter Holdings Series A Preferred Units	'	'	11,956,000	19,600,000	'	'	'	'	'	200,000,000	'
Stocks issued (in Shares)	'	'	'	'	'	'	'	'	610,000	'	'
Stock Issued, value	'	'	178,575,000	'	'	'	'	'	12,000,000	'	'
Preferred stock, shares issued	'	'	'	'	'	'	10,592,540	9,885,048	'	'	'
Ownership percentage	'	'	'	'	'	'	'	'	41.80%	'	'
Preferred stock issued as in-kind payment (in shares)	'	'	'	'	'	'	'	'	97,492	'	'
Preferred stock, dividends paid-in-kind	'	'	1,950,000	2,253,000	'	'	'	'	1,900,000	'	'
Embedded derivative, fair value	'	'	'	'	115,307,000	75,934,000	'	'	'	'	'
Accretion of the difference between the carrying value and the redemption value of preferred stock included in dividends	$2,229,000	$1,696,000	$4,277,000	$3,164,000	'	'	'	'	'	'	'

TAXES_Details

TAXES (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Income Tax Expense (Benefit), Continuing Operations [Abstract]	'	'	'	'
Deferred	$0	$39,300	$0	$44,199
Income tax benefit	$0	$39,300	$0	$44,199

RELATED_PARTY_TRANSACTIONS_Bal

RELATED PARTY TRANSACTIONS (Balances) (Details) (GreenHunter Resources, Inc., USD $)	Jun. 30, 2014		Dec. 31, 2013
Related Party Transaction	'		'
Accounts payable - net	$690,000	[1]	$23,000	[1]
Derivative assets	317,000	[1],[2]	79,000	[1],[2]
Investments	2,423,000	[1],[2]	2,262,000	[1],[2]
Notes receivable	1,496,000	[1],[2]	1,768,000	[1],[2]
Prepaid Expense	0	[1]	9,000	[1]
Common Stock	'		'
Related Party Transaction	'		'
Investment in related parties, shares	1,846,722		'
Investment in related parties, carrying value	232,896		'
Series C Preferred Stock	'		'
Related Party Transaction	'		'
Investment in related parties, shares	88,000		'
Investment in related parties, carrying value	$2,200,000		'
[1]	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman, a major shareholder and interim CEO. Eagle Ford Hunter received, and 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 its affiliated companies, White Top Oilfield Construction, LLC and Black Water Services, LLC. 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 8 - 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 other long-term assets and an available for sale investment in GreenHunter included in investments.

RELATED_PARTY_TRANSACTIONS_Det

RELATED PARTY TRANSACTIONS (Details) (USD $)	3 Months Ended				6 Months Ended
In Thousands, except Share data, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013		Jun. 30, 2014		Jun. 30, 2013
GreenHunter Resources, Inc.	'		'		'		'
Related Party Transaction	'		'		'		'
Loss related to investment	$396	[1]	($151)	[1]	$161	[1]	($677)	[1]
Rental agreement term	'		'		'5 years		'
GreenHunter Resources, Inc. | Water disposal costs	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	613	[2]	590	[2]	935	[2]	1,446	[2]
GreenHunter Resources, Inc. | Equipment Rental Expense	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	19	[2]	98	[2]	141	[2]	73	[2]
GreenHunter Resources, Inc. | Gas gathering-trucking	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	400	[2]	0	[2]	400	[2]	0	[2]
GreenHunter Resources, Inc. | MAG tank panels	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	800	[2]	0	[2]	800	[2]	0	[2]
GreenHunter Resources, Inc. | Office space rental	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	13		0		36		0
GreenHunter Resources, Inc. | Interest Income from Note Receivable	'		'		'		'
Related Party Transaction	'		'		'		'
Drilling revenues	38	[1]	53	[1]	83	[1]	108	[1]
Pilatus Hunter	'		'		'		'
Related Party Transaction	'		'		'		'
Percentage of owned in subsidiary	'		'		100.00%		'
Pilatus Hunter | Airplane Rental Expenses	'		'		'		'
Related Party Transaction	'		'		'		'
Related party expenses	88	[3]	20	[3]	158	[3]	67	[3]
Series C Cumulative Perpetual Preferred Stock | GreenHunter Resources, Inc.	'		'		'		'
Related Party Transaction	'		'		'		'
Proceeds from Dividends Received	$55		$37		$110		$92
Chief Executive Officer | GreenHunter Resources, Inc.	'		'		'		'
Related Party Transaction	'		'		'		'
Shares purchased by related party from agreement for acquisition of assets	'		'		27,641		'
[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 8 - 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 other long-term assets and an available for sale investment in GreenHunter included in investments.
[2]	GreenHunter is an entity of which Gary C. Evans, the Company's Chairman and CEO, is the Chairman, a major shareholder and interim CEO. Eagle Ford Hunter received, and 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 its affiliated companies, White Top Oilfield Construction, LLC and Black Water Services, LLC. 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.

COMMITMENTS_AND_CONTINGENCIES_

COMMITMENTS AND CONTINGENCIES Commitments and Contingencies (Details) (USD $)

Jun. 30, 2014

Dec. 31, 2013

Aug. 12, 2013

Jun. 05, 2014

Jun. 30, 2014

Jun. 05, 2014

Jun. 30, 2014

Jun. 18, 2014

Jul. 24, 2014

Jun. 30, 2014

Jun. 20, 2014

Jun. 30, 2014

Jul. 01, 2014

28-May-14

Dec. 30, 2013

Jul. 24, 2014

Dec. 30, 2013

Jun. 18, 2014

Jun. 18, 2014

Jun. 17, 2014

Jun. 30, 2014

Jun. 30, 2014

31-May-14

Jun. 30, 2014

Triad Hunter

Leasehold Acreage From MNW Energy, LLC

Leasehold Acreage From MNW Energy, LLC

Leasehold Acreage From MNW Energy, LLC

Ormet Asset Purchase Agreement

Ormet Asset Purchase Agreement

Ormet Asset Purchase Agreement

Ambassador Oil And Gas Limited, Off-market Takeover

Ambassador Oil And Gas Limited, Off-market Takeover

Drilling Rig Purchase

Drilling Rig Purchase

The Company, Triad Hunter, MNW vs. Dux Petroleum, LLC

PRC Williston vs. Drawbridge Special Opportunities Fund LP And Fortress Value Recovery Fund I LLC D.B. Zwirn Special Opportunities Fund, L.P.

PRC Williston vs. Drawbridge Special Opportunities Fund LP And Fortress Value Recovery Fund I LLC D.B. Zwirn Special Opportunities Fund, L.P.

PRC Williston vs. Drawbridge Special Opportunities Fund LP And Fortress Value Recovery Fund I LLC D.B. Zwirn Special Opportunities Fund, L.P.

Monroe County, Ohio

Wetzerl County, West Virginia

Marcellus Zone

Southern Appalachia

Muhlenberg County, Kentucky

Common Stock

Common Stock

acre

acre

acre

acre

Subsequent Event

Outback Shale Hunter Pty Ltd

Outback Shale Hunter Pty Ltd

Alpha Hunter Drilling LLC

Alpha Hunter Drilling LLC

Triad Hunter

Subsequent Event

PRC Williston Inc

Ormet Asset Purchase Agreement

Ormet Asset Purchase Agreement

Ormet Asset Purchase Agreement

Seminole Energy Services, Settlement Agreement [Member]

Seminole Energy Services, Settlement Agreement [Member]

Ambassador Oil And Gas Limited, Off-market Takeover

Subsequent Event

acre

acre

Well

Natural gas gathering trunk line and treatment facility

Outback Shale Hunter Pty Ltd

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of mineral acres agreed to acquire

'

'

32,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Litigation settlement, amount

'

'

'

'

'

'

'

'

'

'

'

'

'

$500,000

'

$2,900,000

'

'

'

'

$450,000

'

'

'

Net leasehold acres purchased

'

'

'

'

17,000

11,128

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Payment to acquire leasehold acres

'

'

'

45,900,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percent of total leasehold acres acquired under the asset purchase agreement

'

'

'

'

53.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acreage in which mineral interests are acquired

'

'

'

'

'

'

'

2,000

'

'

'

'

'

'

'

'

'

1,375

325

'

'

'

'

'

Leasehold rights royalty carried on production, percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12.50%

'

'

'

'

Purchase price to acquire mineral rights

'

'

'

'

'

'

'

'

22,700,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Deposit in escrow

'

'

'

'

'

'

2,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock, par value (in dollars per share)

$0.01

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares offered for one share in off-market takeover

'

'

'

'

'

'

'

'

'

'

23.6

'

'

'

'

'

'

'

'

'

'

'

'

'

Share price

'

'

'

'

'

'

'

'

'

$8.20

'

'

'

'

'

'

'

'

'

'

'

'

$7

'

Off-market takeover offer

'

'

'

'

'

'

'

'

'

$0.37

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares to be issued if offer is accepted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,019,427

Implied value of stock issued if offer is accepted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

49,400,000

Number of wells not drilled

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2

'

'

'

Number of wells required to be drilled per agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

4

'

'

'

Interest acquired (percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50.00%

'

'

Purchase price of a new drilling rig

'

'

'

'

'

'

'

'

'

'

'

6,500,000

'

'

'

'

'

'

'

'

'

'

'

'

Deposit on equipment purchase

'

'

'

'

'

'

'

'

'

'

'

'

1,300,000

'

'

'

'

'

'

'

'

'

'

'

Collective interest in any distributions in respect of the equity interests

'

'

'

'

'

'

'

'

'

'

'

'

'

'

12.50%

'

'

'

'

'

'

'

'

'

Proceeds from sale of assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$5,000,000

'

'

'

'

'

'

'

SUPPLEMENTAL_CASH_FLOW_INFORMA2

SUPPLEMENTAL CASH FLOW INFORMATION (Details) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Supplemental Cash Flow Elements [Abstract]	'	'
Cash paid for interest	$35,679	$34,448
Non-cash transactions	'	'
Non-cash consideration received from sale of assets	9,447	42,300
Change in accrued capital expenditures	41,270	42,774
Non-cash additions to asset retirement obligation	13	1,896
Eureka Hunter Holdings Series A Preferred Unit dividends paid in kind	$1,950	$2,253

SEGMENT_REPORTING_Details

SEGMENT REPORTING (Details) (USD $)	3 Months Ended			6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014		Jun. 30, 2013	Jun. 30, 2014		Jun. 30, 2013	Dec. 31, 2013
Details of operating activities by segment	'		'	'		'	'
Total revenue	$132,516		$67,908	$239,960		$122,142	'
Depletion, depreciation, amortization and accretion	35,953		26,375	65,361		43,663	'
Loss (gain) on sale of assets, net	-687		1,183	2,772		1,164	'
Other operating expenses	98,389		66,587	187,166		143,563	'
Other income (expense)	-62,965		-12,777	-86,666		-39,128	'
Income (loss) from continuing operations before income tax	-64,104		-39,014	-102,005		-105,376	'
Income tax benefit	0		39,300	0		44,199	'
Total income from discontinued operations, net of tax	-1,323	[1]	164,768	-25,123	[1]	181,531	'
Net income (loss)	-65,427		165,054	-127,128		120,354	'
Total assets	1,963,357		2,035,920	1,963,357		2,035,920	1,856,651
Total capital expenditures	204,473		81,934	302,439		236,956	'
U.S. Upstream	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	78,191		50,321	148,365		84,966	'
Depletion, depreciation, amortization and accretion	31,187		22,573	56,126		36,836	'
Loss (gain) on sale of assets, net	-316		1,179	3,141		1,160	'
Other operating expenses	37,692		37,638	82,421		81,701	'
Other income (expense)	201		-2,589	-77		-4,712	'
Income (loss) from continuing operations before income tax	9,829		-13,658	6,600		-39,443	'
Income tax benefit	'		-1,674	'		3,180	'
Total income from discontinued operations, net of tax	-177	[1]	174,724	-23,305	[1]	191,213	'
Net income (loss)	9,652		159,392	-16,705		154,950	'
Total assets	1,485,120		1,413,298	1,485,120		1,413,298	'
Total capital expenditures	150,143		60,847	216,454		173,191	'
Canadian Upstream	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	0		0	0		0	'
Depletion, depreciation, amortization and accretion	0		0	0		0	'
Loss (gain) on sale of assets, net	0		0	0		0	'
Other operating expenses	0		0	0		0	'
Other income (expense)	0		0	0		0	'
Income (loss) from continuing operations before income tax	0		0	0		0	'
Income tax benefit	'		-926	'		-926	'
Total income from discontinued operations, net of tax	11,461	[1]	-1,565	10,636	[1]	-1,209	'
Net income (loss)	11,461		-2,491	10,636		-2,135	'
Total assets	0		248,908	0		248,908	'
Total capital expenditures	-3		1,880	305		14,136	'
Midstream and Marketing	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	52,117		16,151	86,852		33,453	'
Depletion, depreciation, amortization and accretion	3,929		3,281	7,607		5,968	'
Loss (gain) on sale of assets, net	0		0	0		0	'
Other operating expenses	46,700		15,468	78,770		30,136	'
Other income (expense)	-40,457		-6,594	-40,427		-7,689	'
Income (loss) from continuing operations before income tax	-38,969		-9,192	-39,952		-10,340	'
Income tax benefit	'		0	'		0	'
Total income from discontinued operations, net of tax	0	[1]	0	0	[1]	0	'
Net income (loss)	-38,969		-9,192	-39,952		-10,340	'
Total assets	380,108		248,965	380,108		248,965	'
Total capital expenditures	51,993		12,790	82,627		35,085	'
Oilfield Services	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	7,795		3,694	15,706		7,425	'
Depletion, depreciation, amortization and accretion	837		521	1,628		859	'
Loss (gain) on sale of assets, net	-371		4	-369		4	'
Other operating expenses	6,361		4,254	13,074		7,953	'
Other income (expense)	-211		-142	-420		-231	'
Income (loss) from continuing operations before income tax	757		-1,227	953		-1,622	'
Income tax benefit	'		0	'		0	'
Total income from discontinued operations, net of tax	0	[1]	0	0	[1]	0	'
Net income (loss)	757		-1,227	953		-1,622	'
Total assets	44,682		34,287	44,682		34,287	'
Total capital expenditures	2,257		6,165	2,947		14,121	'
Corporate Unallocated	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	0		0	0		0	'
Depletion, depreciation, amortization and accretion	0		0	0		0	'
Loss (gain) on sale of assets, net	0		0	0		0	'
Other operating expenses	13,054		11,485	23,542		27,475	'
Other income (expense)	-22,498		-3,390	-45,742		-26,516	'
Income (loss) from continuing operations before income tax	-35,552		-14,875	-69,284		-53,991	'
Income tax benefit	'		41,900	'		41,945	'
Total income from discontinued operations, net of tax	-12,776	[1]	-8,453	-12,776	[1]	-8,453	'
Net income (loss)	-48,328		18,572	-82,060		-20,499	'
Total assets	61,180		98,469	61,180		98,469	'
Total capital expenditures	83		252	106		423	'
Inter-segment Eliminations	'		'	'		'	'
Details of operating activities by segment	'		'	'		'	'
Total revenue	-5,587		-2,258	-10,963		-3,702	'
Depletion, depreciation, amortization and accretion	0		0	0		0	'
Loss (gain) on sale of assets, net	0		0	0		0	'
Other operating expenses	-5,418		-2,258	-10,641		-3,702	'
Other income (expense)	0		-62	0		20	'
Income (loss) from continuing operations before income tax	-169		-62	-322		20	'
Income tax benefit	'		0	'		0	'
Total income from discontinued operations, net of tax	169	[1]	62	322	[1]	-20	'
Net income (loss)	0		0	0		0	'
Total assets	-7,733		-8,007	-7,733		-8,007	'
Total capital expenditures	$0		$0	$0		$0	'
[1]	Gain (loss) on disposal of discontinued operations related to WHI Canada is included in the Corporate Unallocated segment, as the Company sold 100% of its ownership interest in the entity.

CONDENSED_CONSOLIDATING_GUARAN2

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	($65,427)	$165,054	($127,128)	$120,354	'
ASSETS	'	'	'	'	'
Current assets	121,613	'	121,613	'	120,726
Property and equipment (using successful efforts method of accounting)	1,698,025	'	1,698,025	'	1,514,079
Total assets	1,963,357	2,035,920	1,963,357	2,035,920	1,856,651
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	226,196	'	226,196	'	183,865
Redeemable preferred stock	249,379	'	249,379	'	236,675
Shareholders’ equity	503,005	'	503,005	'	450,730
Total liabilities and shareholders’ equity	1,963,357	'	1,963,357	'	1,856,651
Magnum Hunter Resources Corporation	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-71,300	160,274	-139,119	111,429	'
100% Owned Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	14,171	4,589	-7,510	-15,506	'
Non Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-28,598	-30,564	-29,459	-23,741	'
Eliminations	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	20,300	30,755	48,960	48,172	'
Magnum Hunter Resources Corporation Consolidated	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-65,427	165,054	-127,128	120,354	'
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-71,300	160,274	-139,119	111,429	'
ASSETS	'	'	'	'	'
Current assets	37,995	'	37,995	'	53,161
Intercompany accounts receivable	1,083,102	'	1,083,102	'	965,138
Property and equipment (using successful efforts method of accounting)	5,939	'	5,939	'	7,214
Investment in subsidiaries	279,116	'	279,116	'	372,236
Other assets	17,246	'	17,246	'	17,308
Total assets	1,423,398	'	1,423,398	'	1,415,057
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	63,583	'	63,583	'	54,826
Intercompany accounts payable	0	'	0	'	0
Long-term liabilities	765,072	'	765,072	'	818,651
Redeemable preferred stock	100,000	'	100,000	'	100,000
Shareholders’ equity	494,743	'	494,743	'	441,580
Total liabilities and shareholders’ equity	1,423,398	'	1,423,398	'	1,415,057
Debt Securities Under Universal Shelf Registration Statement Form S-4 | 100% Owned Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	14,171	4,589	-7,510	-15,506	'
ASSETS	'	'	'	'	'
Current assets	75,812	'	75,812	'	43,841
Intercompany accounts receivable	'	'	'	'	'
Property and equipment (using successful efforts method of accounting)	1,381,891	'	1,381,891	'	1,272,027
Investment in subsidiaries	101,485	'	101,485	'	102,314
Other assets	88,394	'	88,394	'	100,894
Total assets	1,647,582	'	1,647,582	'	1,519,076
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	118,934	'	118,934	'	97,520
Intercompany accounts payable	1,036,163	'	1,036,163	'	921,237
Long-term liabilities	39,346	'	39,346	'	39,067
Redeemable preferred stock	0	'	0	'	0
Shareholders’ equity	453,139	'	453,139	'	461,252
Total liabilities and shareholders’ equity	1,647,582	'	1,647,582	'	1,519,076
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Non Guarantor Subsidiaries	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-28,598	-30,564	-29,459	-23,741	'
ASSETS	'	'	'	'	'
Current assets	15,539	'	15,539	'	27,096
Intercompany accounts receivable	'	'	'	'	'
Property and equipment (using successful efforts method of accounting)	310,195	'	310,195	'	234,838
Investment in subsidiaries	'	'	'	'	'
Other assets	38,079	'	38,079	'	103,644
Total assets	363,813	'	363,813	'	365,578
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	51,453	'	51,453	'	34,929
Intercompany accounts payable	46,901	'	46,901	'	43,866
Long-term liabilities	180,359	'	180,359	'	127,663
Redeemable preferred stock	149,379	'	149,379	'	136,675
Shareholders’ equity	-64,279	'	-64,279	'	22,445
Total liabilities and shareholders’ equity	363,813	'	363,813	'	365,578
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Eliminations	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	20,300	30,755	48,960	48,172	'
ASSETS	'	'	'	'	'
Current assets	-7,733	'	-7,733	'	-3,372
Intercompany accounts receivable	-1,083,102	'	-1,083,102	'	-965,138
Property and equipment (using successful efforts method of accounting)	'	'	'	'	'
Investment in subsidiaries	-380,601	'	-380,601	'	-474,550
Other assets	'	'	'	'	'
Total assets	-1,471,436	'	-1,471,436	'	-1,443,060
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	-7,774	'	-7,774	'	-3,410
Intercompany accounts payable	-1,083,064	'	-1,083,064	'	-965,103
Long-term liabilities	0	'	0	'	0
Redeemable preferred stock	0	'	0	'	0
Shareholders’ equity	-380,598	'	-380,598	'	-474,547
Total liabilities and shareholders’ equity	-1,471,436	'	-1,471,436	'	-1,443,060
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation Consolidated	'	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'	'
Net income (loss)	-65,427	165,054	-127,128	120,354	'
ASSETS	'	'	'	'	'
Current assets	121,613	'	121,613	'	120,726
Intercompany accounts receivable	0	'	0	'	0
Property and equipment (using successful efforts method of accounting)	1,698,025	'	1,698,025	'	1,514,079
Investment in subsidiaries	0	'	0	'	0
Other assets	143,719	'	143,719	'	221,846
Total assets	1,963,357	'	1,963,357	'	1,856,651
LIABILITIES AND SHAREHOLDERS’ EQUITY	'	'	'	'	'
Current liabilities	226,196	'	226,196	'	183,865
Intercompany accounts payable	0	'	0	'	0
Long-term liabilities	984,777	'	984,777	'	985,381
Redeemable preferred stock	249,379	'	249,379	'	236,675
Shareholders’ equity	503,005	'	503,005	'	450,730
Total liabilities and shareholders’ equity	$1,963,357	'	$1,963,357	'	$1,856,651

CONDENSED_CONSOLIDATING_GUARAN3

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 2) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Condensed consolidating statements of operations	'	'	'	'
Revenues	$132,516	$67,908	$239,960	$122,142
Income (loss) from continuing operations before income taxes	-64,104	-39,014	-102,005	-105,376
Income tax benefit	0	39,300	0	44,199
Income (loss) from continuing operations	-64,104	286	-102,005	-61,177
Income (loss) from discontinued operations, net of tax	3,889	-7,684	7,251	9,079
Gain (loss) on disposal of discontinued operations, net of tax	-5,212	172,452	-32,374	172,452
Net income (loss)	-65,427	165,054	-127,128	120,354
Net loss attributed to non-controlling interests	780	386	889	889
Net income (loss) attributable to Magnum Hunter Resources Corporation	-64,647	165,440	-126,239	121,243
Dividends on preferred stock	-15,330	-14,129	-30,226	-27,617
Net income (loss) attributable to common shareholders	-79,977	151,311	-156,465	93,626
Magnum Hunter Resources Corporation	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Net income (loss)	-71,300	160,274	-139,119	111,429
100% Owned Guarantor Subsidiaries	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Net income (loss)	14,171	4,589	-7,510	-15,506
Non Guarantor Subsidiaries	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Net income (loss)	-28,598	-30,564	-29,459	-23,741
Eliminations	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Net income (loss)	20,300	30,755	48,960	48,172
Magnum Hunter Resources Corporation Consolidated	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Net income (loss)	-65,427	165,054	-127,128	120,354
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Revenues	6	12	114	-163
Expenses	36,512	16,577	71,305	56,209
Loss from continuing operations before equity in net income of subsidiary	-36,506	-16,565	-71,191	-56,372
Equity in net income of subsidiary	-19,314	-29,060	-48,129	-38,143
Income (loss) from continuing operations before income taxes	-55,820	-45,625	-119,320	-94,515
Income tax benefit	'	41,900	0	41,945
Income (loss) from continuing operations	-55,820	-3,725	-119,320	-52,570
Income (loss) from discontinued operations, net of tax	0	-8,453	0	-8,453
Gain (loss) on disposal of discontinued operations, net of tax	-15,480	172,452	-19,799	172,452
Net income (loss)	-71,300	160,274	-139,119	111,429
Net loss attributed to non-controlling interests	0	'	0	0
Net income (loss) attributable to Magnum Hunter Resources Corporation	-71,300	160,274	-139,119	111,429
Dividends on preferred stock	-8,848	-8,877	-17,668	-17,783
Net income (loss) attributable to common shareholders	-80,148	151,397	-156,787	93,646
Debt Securities Under Universal Shelf Registration Statement Form S-4 | 100% Owned Guarantor Subsidiaries	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Revenues	125,536	62,065	229,550	109,427
Expenses	112,757	74,612	219,841	146,285
Loss from continuing operations before equity in net income of subsidiary	12,779	-12,547	9,709	-36,858
Equity in net income of subsidiary	-984	-113	-829	-642
Income (loss) from continuing operations before income taxes	11,795	-12,660	8,880	-37,500
Income tax benefit	'	-1,654	0	3,200
Income (loss) from continuing operations	11,795	-14,314	8,880	-34,300
Income (loss) from discontinued operations, net of tax	2,376	18,903	2,259	18,794
Gain (loss) on disposal of discontinued operations, net of tax	0	0	-18,649	0
Net income (loss)	14,171	4,589	-7,510	-15,506
Net loss attributed to non-controlling interests	0	'	0	0
Net income (loss) attributable to Magnum Hunter Resources Corporation	14,171	4,589	-7,510	-15,506
Dividends on preferred stock	0	0	0	0
Net income (loss) attributable to common shareholders	14,171	4,589	-7,510	-15,506
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Non Guarantor Subsidiaries	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Revenues	12,560	8,090	21,258	16,581
Expenses	52,768	17,930	61,460	28,747
Loss from continuing operations before equity in net income of subsidiary	-40,208	-9,840	-40,202	-12,166
Equity in net income of subsidiary	0	-1,582	0	-9,387
Income (loss) from continuing operations before income taxes	-40,208	-11,422	-40,202	-21,553
Income tax benefit	'	-946	0	-946
Income (loss) from continuing operations	-40,208	-12,368	-40,202	-22,499
Income (loss) from discontinued operations, net of tax	1,342	-18,196	4,669	-1,242
Gain (loss) on disposal of discontinued operations, net of tax	10,268	0	6,074	0
Net income (loss)	-28,598	-30,564	-29,459	-23,741
Net loss attributed to non-controlling interests	0	'	0	0
Net income (loss) attributable to Magnum Hunter Resources Corporation	-28,598	-30,564	-29,459	-23,741
Dividends on preferred stock	-6,482	-5,252	-12,558	-9,834
Net income (loss) attributable to common shareholders	-35,080	-35,816	-42,017	-33,575
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Eliminations	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Revenues	-5,586	-2,259	-10,962	-3,703
Expenses	-5,417	-2,197	-10,641	-3,723
Loss from continuing operations before equity in net income of subsidiary	-169	-62	-321	20
Equity in net income of subsidiary	20,298	30,755	48,958	48,172
Income (loss) from continuing operations before income taxes	20,129	30,693	48,637	48,192
Income tax benefit	'	'	0	0
Income (loss) from continuing operations	20,129	30,693	48,637	48,192
Income (loss) from discontinued operations, net of tax	171	62	323	-20
Gain (loss) on disposal of discontinued operations, net of tax	0	0	0	0
Net income (loss)	20,300	30,755	48,960	48,172
Net loss attributed to non-controlling interests	780	386	889	889
Net income (loss) attributable to Magnum Hunter Resources Corporation	21,080	31,141	49,849	49,061
Dividends on preferred stock	0	0	0	0
Net income (loss) attributable to common shareholders	21,080	31,141	49,849	49,061
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation Consolidated	'	'	'	'
Condensed consolidating statements of operations	'	'	'	'
Revenues	132,516	67,908	239,960	122,142
Expenses	196,620	106,922	341,965	227,518
Loss from continuing operations before equity in net income of subsidiary	-64,104	-39,014	-102,005	-105,376
Equity in net income of subsidiary	0	0	0	0
Income (loss) from continuing operations before income taxes	-64,104	-39,014	-102,005	-105,376
Income tax benefit	'	39,300	0	44,199
Income (loss) from continuing operations	-64,104	286	-102,005	-61,177
Income (loss) from discontinued operations, net of tax	3,889	-7,684	7,251	9,079
Gain (loss) on disposal of discontinued operations, net of tax	-5,212	172,452	-32,374	172,452
Net income (loss)	-65,427	165,054	-127,128	120,354
Net loss attributed to non-controlling interests	780	386	889	889
Net income (loss) attributable to Magnum Hunter Resources Corporation	-64,647	165,440	-126,239	121,243
Dividends on preferred stock	-15,330	-14,129	-30,226	-27,617
Net income (loss) attributable to common shareholders	($79,977)	$151,311	($156,465)	$93,626

CONDENSED_CONSOLIDATING_GUARAN4

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 3) (USD $)	3 Months Ended		6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013	Jun. 30, 2014	Jun. 30, 2013
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	($65,427)	$165,054	($127,128)	$120,354
Foreign currency translation gain	1,130	-7,070	-1,218	-11,799
Unrealized loss on available for sale securities	-549	4,466	-605	4,449
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	20,741	0	20,741	0
COMPREHENSIVE LOSS	-44,105	162,450	-108,210	113,004
Comprehensive loss attributable to non-controlling interests	780	386	889	889
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-43,325	162,836	-107,321	113,893
Magnum Hunter Resources Corporation	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-71,300	160,274	-139,119	111,429
Foreign currency translation gain	0	0	0	0
Unrealized loss on available for sale securities	0	4,700	0	4,700
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	20,741	'	'	'
COMPREHENSIVE LOSS	-50,559	164,974	-118,378	116,129
Comprehensive loss attributable to non-controlling interests	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-50,559	164,974	-118,378	116,129
100% Owned Guarantor Subsidiaries	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	14,171	4,589	-7,510	-15,506
Foreign currency translation gain	0	0	0	0
Unrealized loss on available for sale securities	-549	-234	-605	-251
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	'	'	'
COMPREHENSIVE LOSS	13,622	4,355	-8,115	-15,757
Comprehensive loss attributable to non-controlling interests	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	13,622	4,355	-8,115	-15,757
Non-Guarantor Subsidiaries [Member]	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-28,598	-30,564	-29,459	-23,741
Foreign currency translation gain	1,130	-7,070	-1,218	-11,799
Unrealized loss on available for sale securities	0	0	0	0
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	'	'	'
COMPREHENSIVE LOSS	-27,468	-37,634	-30,677	-35,540
Comprehensive loss attributable to non-controlling interests	0	0	0	0
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	-27,468	-37,634	-30,677	-35,540
Eliminations	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	20,300	30,755	48,960	48,172
Foreign currency translation gain	0	0	0	0
Unrealized loss on available for sale securities	0	0	0	0
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	0	'	'	'
COMPREHENSIVE LOSS	20,300	30,755	48,960	48,172
Comprehensive loss attributable to non-controlling interests	780	386	889	889
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	21,080	31,141	49,849	49,061
Magnum Hunter Resources Corporation Consolidated	'	'	'	'
Condensed Financial Statements, Captions [Line Items]	'	'	'	'
Net income (loss)	-65,427	165,054	-127,128	120,354
Foreign currency translation gain	1,130	-7,070	-1,218	-11,799
Unrealized loss on available for sale securities	-549	4,466	-605	4,449
Amounts reclassified from accumulated other comprehensive income upon sale of Williston Hunter Canada, Inc.	20,741	'	'	'
COMPREHENSIVE LOSS	-44,105	162,450	-108,210	113,004
Comprehensive loss attributable to non-controlling interests	780	386	889	889
Comprehensive Income (Loss), Net of Tax, Attributable to Parent	($43,325)	$162,836	($107,321)	$113,893

CONDENSED_CONSOLIDATING_GUARAN5

CONDENSED CONSOLIDATING GUARANTOR FINANCIAL STATEMENTS (Details 4) (USD $)	6 Months Ended
In Thousands, unless otherwise specified	Jun. 30, 2014	Jun. 30, 2013
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	$18,747	$73,868
Cash flow from operating activities	-185,372	104,198
Cash flow from investing activities	133,991	-202,590
Effect of changes in exchange rate on cash	41	-357
Net increase (decrease) in cash	-32,593	-24,881
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	41,713	57,623
CASH AND CASH EQUIVALENTS, END OF PERIOD	9,120	32,742
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation	'	'
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	-192,121	-156,721
Cash flow from operating activities	49,572	371,970
Cash flow from investing activities	111,324	-224,493
Effect of changes in exchange rate on cash	'	'
Net increase (decrease) in cash	-31,225	-9,244
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	47,895	26,871
CASH AND CASH EQUIVALENTS, END OF PERIOD	16,670	17,627
Debt Securities Under Universal Shelf Registration Statement Form S-4 | 100% Owned Guarantor Subsidiaries	'	'
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	182,620	146,932
Cash flow from operating activities	-177,365	-152,127
Cash flow from investing activities	3,038	4,051
Effect of changes in exchange rate on cash	'	'
Net increase (decrease) in cash	8,293	-1,144
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	-17,651	-4,186
CASH AND CASH EQUIVALENTS, END OF PERIOD	-9,358	-5,330
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Non Guarantor Subsidiaries	'	'
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	28,248	83,657
Cash flow from operating activities	-57,579	-115,645
Cash flow from investing activities	19,629	17,852
Effect of changes in exchange rate on cash	41	-357
Net increase (decrease) in cash	-9,661	-14,493
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	11,469	34,938
CASH AND CASH EQUIVALENTS, END OF PERIOD	1,808	20,445
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Eliminations	'	'
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	'	'
Cash flow from operating activities	'	'
Cash flow from investing activities	'	'
Effect of changes in exchange rate on cash	'	'
Net increase (decrease) in cash	'	'
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	'	'
CASH AND CASH EQUIVALENTS, END OF PERIOD	'	'
Debt Securities Under Universal Shelf Registration Statement Form S-4 | Magnum Hunter Resources Corporation Consolidated	'	'
Schedule of condensed consolidating statements of cash flows	'	'
Cash flow from operating activities	18,747	73,868
Cash flow from operating activities	-185,372	104,198
Cash flow from investing activities	133,991	-202,590
Effect of changes in exchange rate on cash	41	-357
Net increase (decrease) in cash	-32,593	-24,881
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	41,713	57,623
CASH AND CASH EQUIVALENTS, END OF PERIOD	$9,120	$32,742

SUBSEQUENT_EVENTS_Details

SUBSEQUENT EVENTS (Details) (USD $)

6 Months Ended

0 Months Ended

0 Months Ended

0 Months Ended

Jun. 30, 2014

Jun. 30, 2013

Dec. 31, 2013

Jun. 30, 2014

Dec. 31, 2013

Jul. 18, 2014

Jul. 14, 2014

Jul. 01, 2014

Jul. 14, 2014

Jul. 01, 2014

Jul. 29, 2014

Jun. 30, 2014

Jul. 25, 2014

Jul. 24, 2014

Jul. 24, 2014

Jul. 24, 2014

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Eagle Ford Hunter, Inc.

Eagle Ford Hunter, Inc.

The Company, PRC Williston vs. Drawbridge Special Opportunities Fund LP [Member]

Mineral Interests From Ormet Corporation [Member]

Mineral Interests From Ormet Corporation [Member]

Common Class A Units

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Eureka Hunter Holdings, LLC

Ridgeline Midstream Holdings, LLC

Subsequent Event

Subsequent Event

Subsequent Event

Subsequent Event

Common Class A Units

Common Class A Units

Common Class A Units

Common Class A Units

Common Class A Units

Triad Hunter

Triad Hunter

Subsequent Event [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred units issued

'

'

'

'

'

'

'

'

'

537,209

'

'

'

'

'

'

Proceeds from Issuance of Preferred Units

'

'

'

'

'

'

'

$10,700,000

'

'

'

'

'

'

'

'

Consolidated controlling interest (as a percent)

'

'

'

56.54%

56.40%

'

'

'

'

59.10%

'

'

'

'

'

'

Number of shares authorized under the plan

27,500,000

'

'

'

'

'

'

'

1,000,000

'

'

'

'

'

'

'

Common stock, par value (in dollars per share)

$0.01

'

$0.01

'

'

'

'

'

$20

'

'

'

'

'

'

'

Proceeds from Issuance or Sale of Equity

11,956,000

19,600,000

'

'

'

'

20,000,000

'

'

'

'

'

'

'

'

'

Stock Repurchased During Period, Shares

'

'

'

'

'

590,976

'

'

'

'

409,024

'

'

'

'

'

Stock Repurchased During Period, Value

'

'

'

'

'

11,800,000

'

'

'

'

8,200,000

'

'

'

'

'

Liabilities of disposal group

'

'

'

'

'

'

'

'

'

'

'

33,700,000

'

'

'

'

Accrued liabilities of disposal group

'

'

'

'

'

'

'

'

'

'

'

1,300,000

'

'

'

'

Working capital adjustments, basis for liability claims

'

'

'

'

'

'

'

'

'

'

'

'

7,800,000

'

'

'

Litigation settlement, amount

'

'

'

'

'

'

'

'

'

'

'

'

'

2,900,000

'

'

Loss Contingency, Settlement Agreement, Percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

Purchase price to acquire mineral rights

'

'

'

'

'

'

'

'

'

'

'

'

'

'

22,700,000

'

Business Combination, Credit Received For Funds In Escrow

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$2,500,000