Rex Energy 10-Q 11 May 15 2015 Q1 Quarterly report Financial data

Document_and_Entity_Informatio

Document and Entity Information	3 Months Ended
	Mar. 31, 2015	7-May-15
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	FALSE
Document Period End Date	31-Mar-15
Document Fiscal Year Focus	2015
Document Fiscal Period Focus	Q1
Trading Symbol	REXX
Entity Registrant Name	REX ENERGY CORP
Entity Central Index Key	1397516
Current Fiscal Year End Date	-19
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		55,274,519

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Current Assets
Cash and Cash Equivalents	$4,964	$17,978
Accounts Receivable	33,386	43,936
Taxes Receivable	2	504
Short-Term Derivative Instruments	32,849	29,265
Inventory, Prepaid Expenses and Other	2,737	3,403
Assets Held for Sale	42,696	34,257
Total Current Assets	116,634	129,343
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties	1,147,468	1,079,039
Unevaluated Oil and Gas Properties	335,279	322,413
Other Property and Equipment	46,732	46,361
Wells and Facilities in Progress	101,993	127,655
Pipelines	15,657	15,657
Total Property and Equipment	1,647,129	1,591,125
Less: Accumulated Depreciation, Depletion and Amortization	-395,337	-366,917
Net Property and Equipment	1,251,792	1,224,208
Deferred Financing Costs and Other Assets – Net	17,058	17,070
Equity Method Investments	17,692	17,895
Long-Term Derivative Instruments	10,040	4,904
Long-Term Deferred Tax Asset	8,301	8,301
Total Assets	1,421,517	1,401,721
Current Liabilities
Accounts Payable	45,116	53,340
Current Maturities of Long-Term Debt	1,056	1,176
Accrued Liabilities	56,559	59,478
Short-Term Derivative Instruments	1,393	421
Current Deferred Tax Liability	8,301	8,301
Liabilities Related to Assets Held for Sale	31,519	25,115
Total Current Liabilities	143,944	147,831
Noncurrent Liabilities
Long-Term Derivative Instruments	4,086	2,377
Senior Secured Line of Credit and Long-Term Debt	38,137	251
Senior Notes	675,000
Premium on Senior Notes, Net	2,632	2,725
Other Deposits and Liabilities	3,812	4,018
Future Abandonment Cost	39,040	38,146
Total Liabilities	906,651	870,348
Commitments and Contingencies (See Note 12)
Stockholders’ Equity
Preferred Stock	1	1
Common Stock	54	54
Additional Paid-In Capital	620,782	617,826
Accumulated Deficit	-110,978	-90,749
Rex Energy Stockholders’ Equity	509,859	527,132
Noncontrolling Interests	5,007	4,241
Total Stockholders’ Equity	514,866	531,373
Total Liabilities and Stockholders’ Equity	1,421,517	1,401,721
8.875% Senior Notes
Noncurrent Liabilities
Senior Notes	350,000	350,000
6.25% Senior Notes
Noncurrent Liabilities
Senior Notes	$325,000	$325,000

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Preferred Stock, par value	0.001	0.001
Preferred Stock, shares authorized	100,000	100,000
Preferred Stock, shares issued	16,100	16,100
Preferred Stock, shares outstanding	16,100	16,100
Common Stock, par value	0.001	0.001
Common stock, shares authorized	100,000,000	100,000,000
Common Stock, shares issued	55,266,519	54,174,763
Common Stock, shares outstanding	55,266,519	54,174,763
8.875% Senior Notes
Interest rate	8.88%	8.88%
Due date	2020	2020
6.25% Senior Notes
Interest rate	6.25%	6.25%
Due date	2022	2022

Consolidated_Statements_of_Ope

Consolidated Statements of Operations (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
OPERATING REVENUE
Oil, Natural Gas and NGL Sales	$54,111	$81,299
Other Revenue	11	44
TOTAL OPERATING REVENUE	54,122	81,343
OPERATING EXPENSES
Production and Lease Operating Expense	29,052	20,033
General and Administrative Expense	9,651	9,562
Loss on Disposal of Asset	65	72
Impairment Expense	7,023	25
Exploration Expense	518	2,060
Depreciation, Depletion, Amortization and Accretion	26,126	19,723
Other Operating Expense (Income)	5,191	83
TOTAL OPERATING EXPENSES	77,626	51,558
INCOME (LOSS) FROM OPERATIONS	-23,504	29,785
OTHER EXPENSE
Interest Expense	-12,017	-6,933
Gain (Loss) on Derivatives, Net	17,119	-9,750
Other Income (Expense)	34	-37
Loss on Equity Method Investments	-203	-200
TOTAL OTHER INCOME (EXPENSE)	4,933	-16,920
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX	-18,571	12,865
Income Tax (Expense) Benefit	92	-4,110
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	-18,479	8,755
Income From Discontinued Operations, Net of Income Taxes	1,962	1,682
NET INCOME	-16,517	10,437
Net Income Attributable to Noncontrolling Interests	1,297	1,569
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	-17,814	8,868
Preferred Stock Dividends	2,415
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	($20,229)	$8,868
Earnings per common share:
Basic – Net Income (Loss) From Continuing Operations Attributable to Rex Energy Common Shareholders	($0.38)	$0.17
Basic – Net Income From Discontinued Operations Attributable to Rex Energy Common Shareholders	$0.01	$0
Basic – Net Income (Loss) Attributable to Rex Energy Common Shareholders	($0.37)	$0.17
Basic – Weighted Average Shares of Common Stock Outstanding	54,370	52,984
Diluted – Net Income (Loss) From Continuing Operations Attributable to Rex Energy Common Shareholders	($0.38)	$0.17
Diluted – Net Income From Discontinued Operations Attributable to Rex Energy Common Shareholders	$0.01	$0
Diluted – Net Income (Loss) Attributable to Rex Energy Common Shareholders	($0.37)	$0.17
Diluted – Weighted Average Shares of Common Stock Outstanding	54,370	53,503

Consolidated_Statements_of_Cha

Consolidated Statements of Changes in Noncontrolling Interests and Stockholders' Equity (USD $)	Total	Common Stock	Preferred Stock	Additional Paid-in Capital	Accumulated Deficit	Rex Energy Stockholders' Equity	Noncontrolling Interest
In Thousands
Balance at Dec. 31, 2014	$531,373	$54	$1	$617,826	($90,749)	$527,132	$4,241
Balance (in shares) at Dec. 31, 2014		54,175	16
Non-Cash Compensation	2,956			2,956		2,956
Issuance of Restricted Stock, Net of Forfeitures (in shares)		1,092
Dividends Declared on Preferred Stock ($150.00 per preferred share)	-2,415				-2,415	-2,415
Capital Distributions	-531						-531
Net Income (Loss)	-16,517				-17,814	-17,814	1,297
Balance at Mar. 31, 2015	$514,866	$54	$1	$620,782	($110,978)	$509,859	$5,007
Balance (in shares) at Mar. 31, 2015		55,267	16

Consolidated_Statements_of_Cha1

Consolidated Statements of Changes in Noncontrolling Interests and Stockholders' Equity (Parenthetical) (USD $)	3 Months Ended
	Mar. 31, 2015
Statement Of Stockholders Equity [Abstract]
Dividend declared, per preferred share	$150

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	($16,517)	$10,437
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Loss from Equity Method Investments	203	200
Non-cash Expenses	3,377	1,998
Depreciation, Depletion, Amortization and Accretion	26,165	20,424
(Gain) Loss on Derivatives	-17,119	9,750
Cash Settlements of Derivatives	11,079	-4,877
Dry Hole Expense	-1	86
Deferred Income Tax Expense		4,151
Impairment Expense	7,023	25
Loss on Sale of Asset	33	71
Changes in operating assets and liabilities
Accounts Receivable	10,029	-15,921
Inventory, Prepaid Expenses and Other Assets	328	-144
Accounts Payable and Accrued Liabilities	-12,929	-9,792
Other Assets and Liabilities	-305	-348
NET CASH PROVIDED BY OPERATING ACTIVITIES	11,366	16,060
CASH FLOWS FROM INVESTING ACTIVITIES
Proceeds from Joint Venture Acreage Management	39	67
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets	672	15
Proceeds from Joint Venture	16,611
Acquisitions of Undeveloped Acreage	-17,459	-15,534
Capital Expenditures for Development of Oil & Gas Properties and Equipment	-67,013	-66,481
NET CASH USED IN INVESTING ACTIVITIES	-67,150	-81,933
CASH FLOWS FROM FINANCING ACTIVITIES
Repayments of Long-Term Debt and Line of Credit	-25,761	-19
Proceeds from Long-Term Debt and Line of Credit	72,826	66,922
Repayments of Loans and Other Notes Payable	-686	-528
Debt Issuance Costs	-459	-252
Dividends Paid on Preferred Stock	-2,415
Distributions by the Partners of Consolidated Joint Ventures	-531	-360
NET CASH PROVIDED BY FINANCING ACTIVITIES	42,974	65,763
NET DECREASE IN CASH	-12,810	-110
CASH – BEGINNING	18,096	1,900
CASH – ENDING	5,286	1,790
CASH AND CASH EQUIVALENTS ATTRIBUTABLE TO CONTINUING OPERATIONS	4,964	1,123
CASH AND CASH EQUIVALENTS ATTRIBUTABLE TO ASSETS HELD FOR SALE	322	667
SUPPLEMENTAL DISCLOSURES
Interest Paid, net of capitalized interest	9,895	739
Cash Paid (Received) for Income Taxes	-502	32
NON-CASH ACTIVITIES
Increase (Decrease) in Accrued Liabilities for Capital Expenditures	($602)	$29,153

Basis_of_Presentation_and_Prin

Basis of Presentation and Principles of Consolidation	3 Months Ended
	Mar. 31, 2015
Organization Consolidation And Presentation Of Financial Statements [Abstract]
Basis of Presentation and Principles of Consolidation	1. BASIS OF PRESENTATION AND PRINCIPLES OF CONSOLIDATION
	Rex Energy Corporation, together with our subsidiaries (the “Company”), is an independent oil, natural gas liquid (“NGL”) and natural gas company with operations currently focused in the Appalachian and Illinois Basins. In the Appalachian Basin, we are focused on our Marcellus Shale, Utica Shale and Upper Devonian (“Burkett”) Shale drilling and exploration activities. In the Illinois Basin, we are focused on developmental oil drilling and the implementation of enhanced oil recovery (“EOR”) on our properties. We pursue a balanced growth strategy of exploiting our sizable inventory of high potential exploration drilling prospects while actively seeking to acquire complementary oil and natural gas properties.
	The accompanying Consolidated Financial Statements have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) and include the accounts of all of our wholly owned subsidiaries. All material intercompany balances and transactions have been eliminated. Unless otherwise indicated, all references to “Rex Energy Corporation,” “our,” “we,” “us” and similar terms refer to Rex Energy Corporation and its subsidiaries together. In preparing the accompanying financial statements, management has made certain estimates and assumptions that affect reported amounts in the financial statements and disclosures of contingencies.
	The interim Consolidated Financial Statements of the Company are unaudited and contain all adjustments (consisting primarily of normal recurring accruals) necessary for a fair statement of the results for the interim periods presented. Actual results may differ from those estimates and results for interim periods are not necessarily indicative of results to be expected for a full year or for previously reported periods due in part, but not limited to, the volatility in prices for crude oil, NGLs and natural gas, future impact of financial derivative instruments, interest rates, estimates of reserves, drilling risks, geological risks, transportation restrictions, the timing of acquisitions, product demand, market consumption, interruption in production, our ability to obtain additional capital, and the success of oil, NGL and natural gas recovery techniques.
	Certain amounts and disclosures have been condensed or omitted from these Consolidated Financial Statements pursuant to the rules and regulations of the Securities and Exchange Commission (“SEC”). Therefore, these interim financial statements should be read in conjunction with the audited Consolidated Financial Statements and related notes thereto included in our Annual Report on Form 10-K for the year ended December 31, 2014.
	Discontinued Operations
	Unless otherwise noted, all disclosures and tables reflect the results of continuing operations and exclude any assets, liabilities or results from our discontinued operations. For addition information see Note 3, Discontinued Operations/Assets Held for Sale, to our Consolidated Financial Statements.
	During December 2014, our board of directors approved and committed to a plan to sell Water Solutions Holdings, LLC and its related subsidiaries (“Water Solutions”), of which we own a 60% interest. As a result, the assets and liabilities of Water Solutions have been classified as held for sale in the accompanying Consolidated Balance Sheets as of March 31, 2015 and December 31, 2014, and the results of operations have been classified as discontinued operations in the accompanying Consolidated Statements of Operations as of March 31, 2015 and 2014.

Future_Abandonment_Cost

Future Abandonment Cost	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Future Abandonment Cost	2. FUTURE ABANDONMENT COST
	Future abandonment costs are recognized as obligations associated with the retirement of tangible long-lived assets that result from the acquisition and development of the asset. We recognize the fair value of a liability for a retirement obligation in the period in which the liability is incurred. For natural gas and oil properties, this is the period in which the natural gas or oil well is acquired or drilled. The future abandonment cost is capitalized as part of the carrying amount of our natural gas and oil properties at its discounted fair value. The liability is then accreted each period until the liability is settled or the natural gas or oil well is sold, at which time the liability is reversed. If the fair value of a recorded future abandonment cost changes, a revision is recorded to both the asset retirement obligation and the asset retirement cost.
	Accretion expense for the three-month periods ended March 31, 2015 and 2014 totaled approximately $0.9 million and $0.8 million, respectively. These amounts are recorded as depreciation, depletion, amortization and accretion (“DD&A”) expense on our Consolidated Statements of Operations. We account for future abandonment costs that relate to wells that are drilled jointly based on our working interest in those wells.
	($ in Thousands)	Three Months Ended March 31, 2015
	Beginning Balance at January 1, 2015	$	40,099
	Future Abandonment Obligation Incurred		249
	Future Abandonment Obligation Settled		(266	)
	Future Abandonment Obligation Cancelled or Sold		(34	)
	Future Abandonment Obligation Revision of Estimated Obligation		(2	)
	Future Abandonment Obligation Accretion Expense		921
	Total Future Abandonment Cost1	$	40,967
	1 Includes approximately $1.9 million of short-term future abandonment costs, which are classified as Accrued Liabilities on our Consolidated Balance Sheet.

Discontinued_OperationsAssets_

Discontinued Operations/Assets Held For Sale	3 Months Ended
	Mar. 31, 2015
Discontinued Operations And Disposal Groups [Abstract]
Discontinued Operations/Assets Held For Sale	3. DISCONTINUED OPERATIONS/ASSETS HELD FOR SALE
	In December 2014, our board of directors approved a formal plan to sell Water Solutions, of which we own a 60% interest. The sale of Water Solutions is being actively marketed and we believe the sale will take place within the next 12 months. Water Solutions operates and manages water sourcing, water transfer, equipment rental, trucking and water disposal services, primarily in the Appalachian Basin.
	The carrying value of the assets and liabilities of Water Solutions that are classified as held for sale in the accompanying Consolidated Balance Sheets at March 31, 2015 and December 31, 2014 are as follows:
		March 31,			December 31,
	($ in Thousands)	2015			2014
	Assets:
	Cash and Cash Equivalents	$	322		$	118
	Accounts Receivable		14,223			13,226
	Inventory, Prepaid Expenses and Other		484			163
	Total Current Assets		15,029			13,507
	Other Property and Equipment, Net		26,681			19,690
	Wells and Facilities in Progress		628			688
	Intangible Assets, Net		358			372
	Total Long-Term Assets		27,667			20,750
	Total Assets Held for Sale	$	42,696		$	34,257
	Liabilities:
	Accounts Payable	$	3,475		$	3,694
	Current Maturities of Long-Term Debt		14,344			6,236
	Accrued Liabilities		3,892			6,304
	Total Current Liabilities		21,711			16,234
	Senior Secured Line of Credit and Long-Term Debt		9,808			8,881
	Total Long-Term Liabilities		9,808			8,881
	Total Liabilities Related to Assets Held for Sale	$	31,519		$	25,115
	Net Assets Held for Sale	$	11,177		$	9,142
	Summarized financial information for Discontinued Operations related to Water Solutions is set forth in the table below, and does not reflect the costs of certain services provided. Such indirect costs, which were not allocated to the Discontinued Operations, were for services, including legal counsel, insurance, external audit fees, payroll processing, certain human resource services and information technology systems support.
		Three Months Ended March 31,
	($ in Thousands)	2015			2014
	Revenues:
	Field Services Revenue	$	14,964		$	15,304
	Total Operating Revenue		14,964			15,304
	Costs and Expenses:
	General and Administrative Expense		977			830
	Depreciation, Depletion, Amortization and Accretion		39			701
	Field Services Operating Expense		11,289			11,796
	Gain on Sale of Asset		(32	)		—
	Interest Expense		191			202
	Other Expense		103			11
	Total Costs and Expenses		12,567			13,540
	Income from Discontinued Operations Before Income Taxes		2,397			1,764
	Income Tax Expense		(435	)		(82	)
	Income from Discontinued Operations, net of taxes	$	1,962		$	1,682

Business_and_Oil_and_Gas_Prope

Business and Oil and Gas Property Acquisitions and Dispositions	3 Months Ended
	Mar. 31, 2015
Business Combinations [Abstract]
Business and Oil and Gas Property Acquisitions and Dispositions	4. BUSINESS AND OIL AND GAS PROPERTY ACQUISITIONS AND DISPOSITIONS
	On March 31, 2015, we entered into a joint venture agreement with an affiliate of ArcLight Capital Partners, LLC (“ArcLight”) to jointly develop 32 specifically designated wells in our Butler County, Pennsylvania operated area. ArcLight will participate and fund 35.0% of the estimated well costs for the designated wells. Total consideration for the transaction will total approximately $67.0 million, with $16.6 million received at closing for wells that had previously been completed or are in the process of being drilled and completed. Upon the attainment of certain return on investment and internal rate of return thresholds, 50.0% of ArcLight’s 35.0% working interest will revert back to us, leaving ArcLight with a 17.5% working interest.
	The ArcLight transaction constitutes a pooling of assets in a joint undertaking to develop these specific properties for which there is substantial uncertainty about the ability to recover the costs applicable to our interest in the properties. Under the terms of the agreement, we hold a substantial obligation for future performance, which may not be proportionally reimbursed by ArcLight. Due to the uncertainty that exists on the recoverability of costs associated with our retained interest, proceeds received from ArcLight are considered a recovery of costs and no gain or loss is recognized.

Recently_Issued_Accounting_Pro

Recently Issued Accounting Pronouncements	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Recently Issued Accounting Pronouncements	5. RECENTLY ISSUED ACCOUNTING PRONOUNCEMENTS
	In April 2014, the FASB issued ASU 2014-08, Presentation of Financial Statements and Property, Plant, and Equipment: Reporting Discontinued Operations and Disclosures of Disposal of Components of an Entity. The amendments in this ASU change the criteria for reporting discontinued operations while enhancing the disclosures in this area. Under the new guidance, only disposals representing a strategic shift in operations should be presented as discontinued operations. Those strategic shifts should have a major effect on the organization’s operations and financial results. In addition, the new guidance requires expanded disclosures about discontinued operations that will provide financial statement users with more information about the assets, liabilities, income and expenses of discontinued operations. The amendments in this ASU are effective in the first quarter of 2015 for public organizations with calendar year ends. We adopted this ASU on January 1, 2015.
	In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis. The amendments in this ASU intend to improve targeted areas of consolidation guidance for legal entities such as limited partnerships, limited liability corporations and securitization structures. The ASU focuses on the consolidation evaluation for reporting organizations that are required to evaluate whether they should consolidate certain legal entities. In addition to reducing the number of consolidation models from four to two, the new standard places more emphasis on risk of loss when determining a controlling financial interest, reduces the frequency of the application of related-party guidance when determining a controlling financial interest in a variable interest entity and changes consolidation conclusions in several industries that typically make use of limited partnerships or variable interest entities. This ASU will be effective for periods beginning after December 15, 2015, for public companies, and early adoption is permitted, including adoption in an interim period. We are currently evaluating the potential effect of this ASU but do not believe that it will have a material impact on our Consolidated Financial Statements.
	In April 2015, the FASB issued ASU 2015-03, Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The standard requires an entity to present debt issuance costs related to a recognized liability as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The guidance in the ASU is effective for public entities for annual reporting periods beginning after December 15, 2015, including interim periods therein. Early adoption is permitted. We are currently evaluating the potential effect of this ASU and the related impact on our Consolidated Financial Statements. As of March 31, 2015, we had approximately $14.6 million in net deferred financing costs that would be potentially reclassified to reduce the debt carrying balance.

Concentrations_of_Credit_Risk

Concentrations of Credit Risk	3 Months Ended
	Mar. 31, 2015
Risks And Uncertainties [Abstract]
Concentrations of Credit Risk	6. CONCENTRATIONS OF CREDIT RISK
	By using derivative instruments to hedge exposure to changes in commodity prices, we are exposed to credit risk and market risk. Credit risk is the failure of the counterparties to perform under the terms of the derivative contract. When the fair value of the derivative is positive, the counterparty owes us, which creates repayment risk. We minimize the credit or repayment risk in derivative instruments by entering into transactions with high-quality counterparties. Our counterparties are investment grade financial institutions and lenders in our Senior Credit Facility (see Note 7, Long-Term Debt, to our Consolidated Financial Statements). We have a master netting agreement in place with our counterparties that provides for the offsetting of payables against receivables from separate derivative contracts. None of our derivative contracts have a collateral provision that would require funding prior to the scheduled cash settlement date. For additional information, see Note 8, Fair Value of Financial and Derivative Instruments, to our Consolidated Financial Statements.
	We also depend on a relatively small number of purchasers for a substantial portion of our revenue. For the three months ended March 31, 2015, approximately 92.7% of our commodity sales came from five purchasers, with the largest single purchaser accounting for 45.2% of commodity sales. We believe the continued growth in our Appalachian Basin operations will help us to minimize our future risks by diversifying our ratio of oil, NGLs and natural gas sales as well as the quantity of purchasers.

LongTerm_Debt

Long-Term Debt	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Long-Term Debt	7. LONG-TERM DEBT
	Senior Credit Facility
	We maintain a revolving credit facility evidenced by a credit agreement, dated March 27, 2013 and most recently amended on March 27, 2015 (the “Senior Credit Facility”). As of March 31, 2015, the borrowing base under the Senior Credit Facility was $350.0 million; however, the Senior Credit Facility may be increased to up to $500.0 million upon re-determinations of the borrowing base, consent of the lenders and other conditions prescribed by the agreement. Within the Senior Credit Facility, a letter of credit subfacility exists for up to $60.0 million of letters of credit. As of March 31, 2015, loans made under the Senior Credit Facility were set to mature on September 12, 2019. In certain circumstances, we may be required to prepay the loans. Management does not believe that a prepayment will be required within the next twelve months. As of March 31, 2015, we had $38.0 million in outstanding borrowings, and at December 31, 2014, we had no outstanding borrowings under the Senior Credit Facility.
	The Senior Credit Facility requires we meet, on a quarterly basis, minimum financial requirements of consolidated current ratio and net senior secured debt to EBITDAX. EBITDAX is a non-GAAP financial measure used by our management team and by other users of our financial statements, such as our commercial bank lenders, which adds to or subtracts from net income the following expenses or income for a given period to the extent deducted from or added to net income in such period: interest, income taxes, depreciation, depletion, amortization, unrealized gains and losses from derivatives, exploration expense and other similar non-cash activity. The Senior Credit Facility requires that as of the last day of any fiscal quarter, our ratio of consolidated current assets, which includes the unused portion of our borrowing base, as of such day to consolidated current liabilities as of such day, known as our current ratio, must not be less than 1.0 to 1.0. Our current ratio as of March 31, 2015 was approximately 2.7 to 1.0.  Additionally, as of the last day of any fiscal quarter, our ratio of net senior secured debt to EBITDAX for the trailing twelve months must not exceed 3.0 to 1.0. Our ratio of net senior secured debt to EBITDAX as of March 31, 2015 was approximately 0.4 to 1.0. Prior to our most recent re-determination, our net senior secured debt to EBITDAX for the trailing twelve months was not allowed to exceed 1.75 to 1.0.
	2020 Senior Notes and 2022 Senior Notes
	As of March 31, 2015 and December 31, 2014, we had recorded on our Consolidated Balance Sheets approximately $350.0 million of 8.875% senior notes due 2020 (the “2020 Senior Notes”) and approximately $325.0 million of 6.25% senior notes due 2022 (the “2022 Senior Notes”) (collectively, the “Senior Notes”). As of March 31, 2015 and December 31, 2014, we had recorded on our Consolidated Balance Sheets approximately $2.6 million and $2.7 million of a net premium related to the Senior Notes. The amortization of our net premium during the first three months of 2015, which follows the effective interest method, was approximately $0.1 million and was recorded as a credit to Interest Expense on our Consolidated Statement of Operations. Interest is payable semi-annually on our Senior Notes. The 2020 Senior Notes are paid at a rate of 8.875% per annum on June 1 and December 1 of each year while the 2022 Senior Notes are paid at a rate of 6.25% per annum on February 1 and August 1 of each year.
	In addition to the Senior Credit Facility and the Senior Notes, we may, from time to time in the normal course of business finance assets such as vehicles, office equipment and leasehold improvements through debt financing at favorable terms. Long-term debt and other obligations consisted of the following at March 31, 2015 and December 31, 2014:
	($ in Thousands)	March 31, 2015 (Unaudited)			31-Dec-14
	8.875% Senior Notes Due 2020	$	350,000		$	350,000
	6.25% Senior Notes Due 2022		325,000			325,000
	Premium on Senior Notes, Net		2,632			2,725
	Senior Line of Credit(a)		38,000			—
	Capital Leases and Other Obligations(a)		1,193			1,427
	Total Debt		716,825			679,152
	Less Current Portion of Long-Term Debt		(1,056	)		(1,176	)
	Total Long-Term Debt	$	715,769		$	677,976
	(a)	The Senior Credit Facility requires us to make monthly payments of interest on the outstanding balance of loans made under the agreement. The weighted average interest rate on borrowings under our Senior Credit Facility for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 4.2% and 4.0%, respectively.
	The following is the principal maturity schedule for debt outstanding as of March 31, 2015:
	2015	$	868
	2016		325
	2017		—
	2018		—
	2019		38,000
	Thereafter		675,000
	Total(a)	$	714,193
	(a)	Excludes $2.6 million net premium on Senior Notes.

Fair_Value_Of_Financial_And_De

Fair Value Of Financial And Derivative Instruments	3 Months Ended
	Mar. 31, 2015
Fair Value Of Financial Instruments And Derivative Instruments [Abstract]
Fair Value Of Financial And Derivative Instruments	8. FAIR VALUE OF FINANCIAL AND DERIVATIVE INSTRUMENTS
	Our results of operations and operating cash flows are impacted by changes in market prices for oil, natural gas and NGLs. To mitigate a portion of the exposure to adverse market changes, we enter into oil, natural gas and NGL commodity derivative instruments to establish price floor protection. As such, when commodity prices decline to levels that are less than our average price floor, we receive payments that supplement our cash flows. Conversely, when commodity prices increase to levels that are above our average price ceiling, we make payments to our counterparties. We do not enter into these arrangements for speculative trading purposes. As of March 31, 2015 and December 31, 2014, our commodity derivative instruments consisted of fixed rate swap contracts, puts, collars, swaptions, deferred put spreads, cap swaps, calls, call protected swaps, basis swaps and three-way collars. We did not designate these instruments as cash flow hedges for accounting purposes. Accordingly, associated unrealized gains and losses are recorded directly as Gain (Loss) on Derivatives, Net.
	We enter into the majority of our derivative arrangements with five counterparties and have a netting agreement in place with these counterparties. We do not obtain collateral to support the agreements, but we believe our credit risk is currently minimal on these transactions. For additional information on the credit risk regarding our counterparties, see Note 6, Concentrations of Credit Risk, to our Consolidated Financial Statements.
	None of our commodity derivatives are designated for hedge accounting but are, to a degree, an economic offset to our commodity price exposure. We utilize the mark-to-market accounting method to account for these contracts. We recognize all gains and losses related to these contracts in the Consolidated Statements of Operations as Gain (Loss) on Derivatives, Net under Other Expense. We received net cash settlements of $10.6 million and paid net cash settlements of $5.2 million in relation to our commodity derivatives during the three months ended March 31, 2015 and 2014, respectively.
	As of March 31, 2015, we had over 75.0% of our annualized oil production hedged through the remainder of 2015, over 95.0% and 40.0% of our annualized  natural gas production hedged through the remainder of 2015 and 2016, respectively, and over 35.0% of our annualized  NGL production hedged through the remainder of 2015. These percentages exclude the effects of our basis swaps and do not include any estimated impact of increased production from future and completion or the natural decline of our oil and gas production.
	Interest Rate Derivatives
	We are exposed to interest rate risk on our long-term fixed and variable interest rate borrowings. Fixed rate debt, where the interest rate is fixed over the life of the instrument, exposes us to changes in the market interest rates which are lower than our current fixed rate. Variable rate debt, where the interest rate fluctuates, exposes us to changes in market interest rates, which may increase over time. As of March 31, 2015 and December 31, 2014, we had $38.0 million and none outstanding under our Senior Credit Facility, respectively, which is subject to variable rates of interest and $675.0 million of Senior Notes outstanding subject to fixed interest rates. See Note 7, Long-Term Debt, to our Consolidated Financial Statements for additional information on our Senior Credit Facility and Senior Notes.
	As of March 31, 2015, we had a $40.0 million notional fixed-to-variable interest rate swap to manage our interest rate exposure related to the Senior Notes in addition to $120.0 million notional fixed-to-variable interest rate swaptions outstanding. We did not have any interest rate derivatives in place as of December 31, 2014. During the second quarter of 2014, we terminated an interest rate swap for net proceeds of approximately $0.6 million. We utilized the mark-to-market accounting method to account for our interest rate swap and swaptions. We recognized all gains and losses related to this contract in the Consolidated Statements of Operations as Gain (Loss) on Derivatives, Net under Other Expense. During the three months ended March 31, 2015, we received cash payments of approximately $0.5 million related to our interest rate swaptions. The fair value of our interest rate swaps as of March 31, 2015, was a net liability of approximately $0.2 million.
	The following table summarizes the location and amounts of gains and losses on our derivative instruments from continuing operations, none of which are designated as hedges for accounting purposes, in our accompanying Consolidated Statements of Operations for the three months ended March 31, 2015 and 2014:
			For the Three Months Ended March 31,
	($ in Thousands)		2015				2014
	Oil		$	2,876			$	(1,168	)
	Natural Gas			13,600				(8,928	)
	NGLs			435				(343	)
	Refined Products			(55	)			—
	Interest Rate			263				689
	Gain (Loss) on Derivatives, Net		$	17,119			$	(9,750	)
	Our derivative instruments are recorded on the balance sheet as either an asset or a liability, in either case measured at fair value. The fair value associated with our derivative instruments was a net asset of approximately $37.4 million and $31.4 million at March 31, 2015 and December 31, 2014, respectively.
	Our open asset/(liability) financial commodity derivative instrument positions at March 31, 2015 consisted of:
	Period		Volume		Put Option				Floor				Ceiling				Swap			Long Call		Fair Market Value ($ in Thousands)
	Oil
	2015 - Deferred Put Spreads		90,000 Bbls		$	73.08			$	83.33			$	—			$	—		$	—	$	739
	2015 - Collars		180,000 Bbls			—				52.58				62.89				—			—		480
	2015 - Call Protected Swaps		15,000 Bbls			—				—				—				95.76			110		691
	2015 - Three-Way Collars		450,000 Bbls			50				65				72.5				—			—		4,232
	2016 - Collars		60,000 Bbls			—				53.75				63.81				—			—		144
	2016 - Deferred Put Spreads		120,000 Bbls			50				65				—				—			—		83
			915,000 Bbls																			$	6,369
	Natural Gas
	2015 - Swaps		17,275,000 Mcf		$	—			$	—			$	—			$	3.38		$	—	$	10,563
	2015 - Swaptions		2,650,000 Mcf			—				—				—				3.54			—		1,700
	2015 - Cap Swaps		5,850,000 Mcf			3.43				—				—				4.12			—		3,026
	2015 - Three-Way Collars		3,400,000 Mcf			2.64				3.32				3.88				—			—		769
	2015 - Put Spreads		4,550,000 Mcf			2.56				3.32				—				—			—		1,873
	2015 - Calls		2,850,000 Mcf			—				—				3.94				—			—		(99	)
	2015 - Basis Swaps - Dominion South		9,780,000 Mcf			—				—				—				(0.79	)		—		1,174
	2016 - Swaps		6,630,000 Mcf			—				—				—				3.69			—		3,679
	2016 - Swaptions		0 Mcf			—				—				—				—			—		(692	)
	2016 - Cap Swaps		3,600,000 Mcf			3.45				—				—				4.11			—		1,454
	2016 - Collars		900,000 Mcf			—				3.2				4.04				—			—		223
	2016 - Three-Way Collars		8,850,000 Mcf			2.66				3.42				4.29				—			—		1,845
	2016 - Put Spreads		2,100,000 Mcf			2.25				3				—				—			—		(18	)
	2016 - Calls		9,120,000 Mcf			—				—				4.23				—			—		(988	)
	2016 - Basis Swaps - Dominion South		7,320,000 Mcf			—				—				—				(0.83	)		—		(207	)
	2017 - Swaps		1,800,000 Mcf			—				—				—				3.64			—		577
	2017 - Cap Swaps		2,100,000 Mcf			3.34				—				—				4.07			—		811
	2017 - Three-Way Collars		6,600,000 Mcf			2.37				3.19				4.26				—			—		1,089
	2017 - Calls		1,440,000 Mcf			—				—				3.9				—			—		(283	)
	2017 - Basis Swaps - Dominion South		7,300,000 Mcf			—				—				—				(0.83	)		—		(207	)
	2017 - Basis Swaps - Texas Gas		14,600,000 Mcf			—				—				—				(0.13	)		—		(172	)
	2018 - Swaps		1,200,000 Mcf			—				—				—				3.61			—		273
	2018 - Cap Swaps		1,800,000 Mcf			3.3				—				—				4.05			—		683
	2018 - Basis Swaps - Dominion South		7,300,000 Mcf			—				—				—				(0.83	)		—		(207	)
	2018 - Basis Swaps - Texas Gas		14,600,000 Mcf			—				—				—				(0.13	)		—		(172	)
	2019 - Basis Swaps - Dominion South		7,300,000 Mcf			—				—				—				(0.83	)		—		(207	)
	2020 - Basis Swaps - Dominion South		7,320,000 Mcf			—				—				—				(0.83	)		—		(207	)
			158,235,000 Mcf																			$	26,280
	NGLs
	2015 - C3+ NGL Swaps		732,000 Bbls		$	—			$	—			$	—			$	32.9		$	—	$	3,934
	2015 - Ethane Swaps		277,500 Bbls			—				—				—				8.5			—		234
	2016 - C3+ NGL Swaps		375,000 Bbls			—				—				—				31.08			—		887
	2016 - Ethane Swaps		120,000 Bbls			—				—				—				8.09			—		(2	)
			1,504,500 Bbls																			$	5,053
	Refined Product (Heating Oil)
2016 - Swaps		12,000 Bbls		$	—			$	—			$	—			$	42		$	—		(55	)
		12,000 Bbls																			$	(55	)
The combined fair value of derivatives, none of which are designated or qualifying as hedges, included in our Consolidated Balance Sheets as of March 31, 2015 and December 31, 2014 is summarized below:
	March 31,				December 31,
($ in Thousands)	2015				2014
Short-Term Derivative Assets:
Crude Oil—Collars	$	552			$	—
Crude Oil—Deferred Put Spread		760				1,413
Crude Oil—Call Protected Swap		691				1,227
Crude Oil—Three-Way Collars		4,232				4,596
NGL—Swaps		5,008				6,181
Natural Gas—Swaps		11,232				4,522
Natural Gas—Cap Swaps		3,585				3,430
Natural Gas—Basis Swaps		1,329				2,815
Natural Gas—Three-Way Collars		1,263				5,081
Natural Gas—Swaption		1,755				—
Natural Gas—Collars		223				—
Natural Gas—Call		(80	)			—
Natural Gas—Put Spread		1,872				—
Interest Rate—Swap		427				—
Total Short-Term Derivative Assets	$	32,849			$	29,265
Long-Term Derivative Assets:
NGL—Swaps	$	838			$	—
Crude Oil—Collars		72				—
Crude Oil—Deferred Put Spread		62				—
Natural Gas—Cap Swaps		2,389				1,617
Natural Gas—Swaps		3,890				1,554
Natural Gas—Basis Swaps		41				—
Natural Gas—Three-Way Collars		2,440				1,733
Interest Rate—Swap		308				—
Total Long-Term Derivative Assets	$	10,040			$	4,904
Total Derivative Assets	$	42,889			$	34,169
Short-Term Derivative Liabilities:
NGL—Swaps	$	(791	)		$	—
Refined Product—Swaps		(13	)			—
Natural Gas—Call		(174	)			(74	)
Natural Gas—Swaps		(30	)			—
Natural Gas—Swaption		(55	)			(154	)
Natural Gas—Basis Swaps		(207	)			(193	)
Interest Rate—Swaption		(123	)			—
Total Short - Term Derivative Liabilities	$	(1,393	)		$	(421	)
Long-Term Derivative Liabilities:
NGL—Swaps	$	(2	)		$	—
Refined Product—Swaps		(42	)			—
Natural Gas—Put Spread		(17	)			—
Natural Gas—Basis Swaps		(1,368	)			(1,281	)
Natural Gas—Swaption		(692	)			—
Natural Gas—Call		(1,116	)			(1,096	)
Interest Rate—Swap		(849	)			—
Total Long-Term Derivative Liabilities	$	(4,086	)		$	(2,377	)
Total Derivative Liabilities	$	(5,479	)		$	(2,798	)
Fair value is 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 (exit price). We utilize market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk and the risks inherent in the inputs to the valuation technique. These inputs can be readily observable, market corroborated or generally unobservable. We primarily apply the market approach for recurring fair value measurements and attempt to utilize the best available information. We utilize a fair value hierarchy that gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurement) and lowest priority to unobservable inputs (Level 3 measurement). The three levels of fair value hierarchy are as follows:
Level 1—Observable inputs, such as quoted prices in active markets for identical assets or liabilities as of the reporting date.
Level 2—Observable inputs other than quoted prices within Level 1 for similar assets and liabilities. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Our derivatives, which consist primarily of commodity swaps and collars and other like derivative contracts, are valued using commodity market data which is derived by combining raw inputs and quantitative models and processes to generate forward curves. Where observable inputs are available, directly or indirectly, for substantially the full term of the asset or liability, the instrument is categorized in Level 2.
Level 3—Unobservable inputs that are supported by little or no market activity. Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value.
Our Level 2 fair value measurements are comprised of our derivative contracts, excluding our basis swap derivatives, and are based upon inputs that are either readily available in the public market, such as oil and natural gas futures prices, volatility factors, interest rates and discount rates, or can be confirmed from other active markets. The fair values recorded as of March 31 2015, and December 31, 2014, were based upon quotes obtained from the counterparties to these contracts and verified by an independent third party.
Our Level 3 fair value measurements are comprised of our natural gas basis swap contracts. The fair values recorded as of March 31, 2015 and December 31, 2014, were based upon quotes obtained from the counterparties to these contracts and verified by an independent third party. The significant unobservable input used in the fair value measurement of our natural gas basis swaps was the estimate of future natural gas basis differentials. Significant variations in price differentials could result in a significantly different fair value measurement. The significant unobservable inputs and the range and weighted average of these inputs used in the fair value measurements of our natural gas basis swaps as of March 31, 2015 and December 31, 2014 are included in the table below.
	As of March 31, 2015
	Range		Weighted Average				Fair Value
	(price per Mcf)		(price per Mcf)				(in thousands)
Natural Gas Basis Differential Forward Curve - Dominion South	($0.38) - ($1.23)		$	(0.82	)		$	139
Natural Gas Basis Differential Forward Curve - Texas Gas	($0.10) - ($0.13)		$	(0.11	)		$	(344	)
	As of December 31, 2014
	Range		Weighted Average				Fair Value
	(price per Mcf)		(price per Mcf)				(in thousands)
Natural Gas Basis Differential Forward Curve - Dominion South	($0.27) - ($1.39)		$	(0.84	)		$	1,341
The fair value of our derivative instruments may be different from the settlement value based on company-specific inputs, such as credit ratings, futures markets and forward curves, and readily available buyers and sellers for such assets and liabilities. During the three months ended March 31, 2015 and for the twelve months ended December 31, 2014, there were no transfers into or out of Level 1 or Level 2 measurements. The following table presents the fair value hierarchy table for assets and liabilities measured at fair value:
					Fair Value Measurements at March 31, 2015 Using:
($ in Thousands)	Total Carrying Value as of March 31, 2015				Quoted Prices in Active Markets for Identical Assets (Level 1)				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)
Commodity Derivatives	$	37,647			$	—			$	37,852			$	(205	)
Interest Rate Swap		(114	)			—				(114	)			—
Interest Rate Swaption		(123	)			—				(123	)			—
					Fair Value Measurements at December 31, 2014 Using:
($ in Thousands)	Total Carrying Value as of December 31, 2014				Quoted Prices in Active Markets for Identical Assets (Level 1)				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)
Commodity Derivatives	$	31,371			$	—			$	30,030			$	1,341
Net derivative asset values are determined primarily by quoted futures and options prices and utilization of the counterparties’ credit default risk and net derivative liabilities are determined primarily by quoted futures and options prices and utilization of our credit default risk. The credit default risk of our counterparties and us are based on metrics such as interest coverage, operating cash flow and leverage ratios that calculate the likelihood that a firm will be unable to repay its lenders or fulfill payment obligations.
The value of our oil derivatives are comprised of three-way collar, call protected swap and deferred put spread contracts for notional barrels of oil at interval New York Mercantile Exchange (“NYMEX”) West Texas Intermediate (“WTI”) oil prices. The fair value of our oil derivatives as of March 31, 2015 are based on (i) the contracted notional volumes, (ii) independent active NYMEX futures price quotes for WTI oil and (iii) the implied rate of volatility inherent in the contracts. The implied rates of volatility inherent in our contracts were determined based on market-quoted volatility factors. Our gas derivatives are comprised of swap, collars, swaption, three way collar, basis swap, cap swap, call and put spread contracts for notional volumes of gas contracted at NYMEX Henry Hub (“HH”). The fair values attributable to our gas derivative contracts as of March 31, 2015 are based on (i) the contracted notional volumes, (ii) independent active NYMEX futures price quotes for HH gas, (iii) independent market-quoted forward index prices and (iv) the implied rate of volatility inherent in the contracts. The implied rates of volatility inherent in our contracts were determined based on market-quoted volatility factors. Our NGL derivatives are comprised of swaps for notional volumes of NGLs contracted at NYMEX Mont Belvieu. The fair values attributable to our NGL derivative contracts as of March 31, 2015 are based on (i) the contracted notional volumes, (ii) independent active NYMEX futures price quotes for Mont Belvieu, (iii) independent market-quoted forward index prices and (iv) the implied rate of volatility inherent in the contracts. The implied rates of volatility inherent in our contracts were determined based on market-quoted volatility factors. We classify our derivatives as Level 2 if the inputs used in the valuation models are directly observable for substantially the full term of the instrument; however, if the significant inputs were not observable for substantially the full term of the instrument, we would classify those derivatives as Level 3. We categorize our measurements as Level 2 because the valuation of our derivative instruments are based on similar transactions observable in active markets or industry standard models that primarily rely on market observable inputs. Substantially all of the assumptions for industry standard models are observable in active markets throughout the full term of the instruments.
The table below sets forth a reconciliation of our commodity derivative contracts at fair value on a recurring basis using significant unobservable inputs (Level 3) during the three months ended March 31, 2015 and 2014:
	Three Months Ended March 31,
($ in Thousands)	2015				2014
Beginning Balance of Level 3	$	1,341			$	4,323
Changes in Fair Value		(1,955	)			(2,356	)
Purchases		—				—
Settlements Received		409				284
Ending Balance of Level 3	$	(205	)		$	2,251
Changes in fair value on our Level 3 commodity derivative contracts outstanding for the three months ended March 31, 2015 and 2014, resulted in losses of approximately $2.0 million and $2.4 million, respectively. This amount has been included in Gain (Loss) on Derivatives, Net in our Consolidated Statements of Operations.
Future Abandonment Cost
We report the fair value of asset retirement obligations on a nonrecurring basis in our Consolidated Balance Sheets. We estimate the fair value of asset retirement obligations based on discounted cash flow projections using numerous estimates, assumptions and judgments regarding such factors as the existence of a legal obligation for an asset retirement obligation;  amounts and timing of settlements; the credit-adjusted risk-free rate to be used; and inflation rates. These inputs are unobservable, and thus result in a Level 3 classification. See Note 2, Future Abandonment Costs, to our Consolidated Financial Statements for further information on asset retirement obligations, which includes a reconciliation of the beginning and ending balances.
Financial Instruments Not Recorded at Fair Value
The following table sets forth the fair values of financial instruments that are not recorded at fair value in our Consolidated Financial Statements:
	31-Mar-15								31-Dec-14
($ in Thousands)	Carrying Amount				Fair Value				Carrying Amount				Fair Value
8.875% Senior Notes due 2020	$	350,000			$	269,500			$	350,000			$	311,955
6.25% Senior Notes due 2022	$	325,000			$	217,360				325,000				241,313
Secured Lines of Credit		38,000				38,000				—				—
Capital Leases and Other Obligations		1,193				1,167				1,427				1,393
Total	$	714,193			$	526,027			$	676,427			$	554,661
The fair value of the secured lines of credit approximates carrying value based on borrowing rates available to us for bank loans with similar terms and maturities and would be classified as Level 2 in the fair value hierarchy.
The fair value of the Senior Notes uses pricing that is readily available in the public market. Accordingly, the fair value of the Senior Notes would be classified as Level 1 in the fair value hierarchy. The fair value of our capital leases and other obligations are determined using a discounted cash flow approach based on the interest rate and payment terms of the obligations and assumed discount rate. The fair values of the obligations could be significantly influenced by the discount rate assumptions, which is unobservable. Accordingly, the fair value of the capital leases and other obligations would be classified as Level 3 in the fair value hierarchy.
The carrying values of all classes of cash and cash equivalents, accounts receivables and accounts payables are considered to be representative of their respective fair values due to the short term maturities of those instruments.
Other Fair Value Measurements
We recorded an other than temporary impairment of $7.0 million related to proved properties and unproved properties. We utilize quoted futures prices and other observable market data in determining the fair value. The inputs used in determining fair value as a part of the impairment calculation are considered to be Level 2 within the fair value hierarchy. For additional information on our impairment, see Note 15, Impairment Expense, to our Consolidated Financial Statements.

Income_Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	9. INCOME TAXES
	We recognize deferred income taxes for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis and net operating loss and credit carryforwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of any tax rate change on deferred taxes is recognized in the period that includes the enactment date of the tax rate change. Realization of deferred tax assets is assessed and, if not more likely than not, a valuation allowance is recorded to write down the deferred tax assets to their net realizable value.
	Income tax included in continuing operations was as follows:
		Three Months Ended March 31,
	($ in Thousands)	2015			2014
	Income (Expense) Benefit	$	92		$	(4,110	)
	Effective Tax Rate		0.5	%		31.9	%
	For the three months ended March 31, 2015, our overall effective tax rate on pre-tax income from continuing operations was different than the statutory rate of 35% due to the recording of a valuation allowance. As of March 31, 2015, we had a significant level of estimated future tax benefits that, given our past and future expectations of net losses, we do not expect to be able to fully utilize, thus limiting our ability to recognize future tax benefits. For the three months ended March 31, 2014, our overall effective tax rate on pretax losses from continuing operations was different than the statutory rate of 35% due primarily to changes in state taxes, partially offset by section 162(m) limitations.
	Income tax payments made during the three months ended March 31, 2015 and 2014 were negligible.  We received tax refunds during the three months ended March 31, 2015 of approximately $0.5 million.

Capital_Stock

Capital Stock	3 Months Ended
	Mar. 31, 2015
Equity [Abstract]
Capital Stock	10. CAPITAL STOCK
	Common Stock
	We have authorized capital stock of 100,000,000 shares of common stock and 100,000 shares of preferred stock. As of March 31, 2015 and December 31, 2014, shares of common stock issued and outstanding totaled 55,266,519 and 54,174,763, respectively.
	Preferred Stock
	On August 18, 2014, we completed a registered offering of 16,100 shares of 6.0% Convertible Perpetual Preferred Stock, Series A, par value $0.001 per share (the “Series A Preferred Stock”) that are represented by 1,610,000 depositary shares. The net proceeds of the offering were approximately $155.0 million, after deducting underwriting discounts, commissions and other offering expenses. We utilized a portion of the net proceeds to fund the acquisition of assets from SWEPI, LP, an affiliate of Royal Dutch Shell, plc, and intend to use the remaining proceeds to fund our capital expenditures program and for general corporate purposes.
	The annual dividend on each share of the Series A Preferred Stock is 6.0% per annum on the liquidation preference of $10,000 per share and is payable quarterly, in arrears, on each February 15, May 15, August 15 and November 15 of each year, commencing on November 15, 2014.
	We will pay cumulative dividends, when and if declared, in cash, stock or a combination thereof, on a quarterly basis at a rate of $600 per share, or 6.0%, per year. In February 2015, we paid a quarterly cash dividend of $150.00 per share for the period of November 15, 2014 to February 15, 2015 in the amount of $2.4 million.

Employee_Benefit_and_Equity_Pl

Employee Benefit and Equity Plans	3 Months Ended
	Mar. 31, 2015
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Employee Benefit and Equity Plans	11. EMPLOYEE BENEFIT AND EQUITY PLANS
	Equity Plans
	We recognize all share-based payments to employees, including grants of employee stock options, in our Consolidated Statements of Operations based on their grant-date fair values, using prescribed option-pricing models where applicable. The fair value is expensed over the requisite service period of the individual grantees, which generally equals one vesting period. We report any benefits of income tax deductions in excess of recognized financial accounting compensation as cash flows from financing activities, rather than as cash flows from operating activities.
	Stock Options
	During the three-month period ended March 31, 2015, we issued 80,000 options to purchase shares of our common stock to three employees. We did not issue options to purchase shares of our common stock for the three-month period ended March 31, 2014. Stock-based compensation expense relating to stock options outstanding for the three months ended March 31, 2015 and 2014 was negligible. The expense related to stock option grants was recorded on our Consolidated Statements of Operations under the heading of General and Administrative Expense. There were no stock options exercised for the three months ended March 31, 2015 and 2014.  There was no total tax benefit for the three-month periods ended March 31, 2015 and 2014.
	A summary of the status of our issued and outstanding stock options as of March 31, 2015 is as follows:
					Outstanding						Exercisable
	Exercise Price				Number Outstanding At 3/31/15				Weighted-Average Exercise Price		Number Exercisable At 3/31/15		Weighted-Average Exercise Price
	$	4.05				40,000			$	4.05		—	$	—
	$	4.9				40,000			$	4.9		—	$	—
	$	5.04				46,041			$	5.04		46,041	$	5.04
	$	9.5				75,000			$	9.5		75,000	$	9.5
	$	9.99				149,333			$	9.99		149,333	$	9.99
	$	10.42				29,548			$	10.42		29,548	$	10.42
	$	11.87				3,500			$	11.87		3,500	$	11.87
	$	12.5				19,139			$	12.5		19,139	$	12.5
	$	13.19				50,000			$	13.19		50,000	$	13.19
	$	22.34				30,000			$	22.34		30,000	$	22.34
						482,561			$	9.77		402,561	$	10.82
	The weighted average remaining contractual term for options outstanding at March 31, 2015 were 3.3 years and there was no aggregate intrinsic value. The weighted average remaining contractual term for options exercisable at March 31, 2015 were 2.6 years and there was no aggregate intrinsic value. As of March 31, 2015, unrecognized compensation expense related to stock options was $0.1 million.
	Restricted Stock Awards
	During the three-month period ended March 31, 2015, the Compensation Committee approved the issuance of an aggregate of 1,336,295 shares of restricted common stock to 126 employees and one non-employee contractor. During the three-month period ended March 31, 2014, the Compensation Committee approved the issuance of an aggregate of 3,315 shares of restricted stock to three employees. Certain of our outstanding restricted stock awards granted in 2015, 2014 and 2013 are subject to market-based vesting through a calculation of total shareholder return (“TSR”) of our common stock relative to a pre-defined peer group over a three-year period.
	The weighted average fair value of the TSR awards granted as of March 31, 2015 and December 31, 2014 were $2.56 and $10.15 per share, respectively. Average fair values were estimated on the date of each grant using a Monte Carlo Simulation model that estimates the most likely outcome based on the terms of the award and used the following assumptions:
		Three Months Ended March 31, 2015				Year Ended December 31, 2014
	Expected Dividend Yield		0	%			0	%
	Risk-Free Interest Rate		1	%			0.8	%
	Expected Volatility – Rex Energy		58.6	%			50.4	%
	Expected Volatility – Peer Group	29.8%-85.0		%		28.4%-65.7		%
	Market Index		35.6	%			35.3	%
	Expected Life	Three Years				Three Years
	Compensation expense associated with restricted stock awards totaled $3.0 million and $1.6 million for the three-month periods ended March 31, 2015 and 2014, respectively. During the first quarter of 2015, the board of directors approved a waiver to certain performance factors for restricted stock awards that vested in March 2015. This waiver resulted in the vesting of approximately 189,872 restricted stock awards with associated expense of approximately $2.5 million. As of March 31, 2015, total unrecognized compensation cost related to restricted common stock grants was approximately $6.7 million, which will be recognized over a weighted average period of 1.9 years.
	A summary of the restricted stock activity for the three months ended March 31, 2015 is as follows:
		Number of Shares				Weighted-Average Grant Date Fair Value
	Restricted stock awards, as of December 31, 2014		1,519,301			$	14.05
	Awards		1,336,295				4.04
	Forfeitures		(244,539	)			12.55
	Vested		(202,492	)			12.52
	Restricted stock awards, as of March 31, 2015		2,408,565			$	8.65

Commitments_and_Contingencies

Commitments and Contingencies	3 Months Ended
	Mar. 31, 2015
Commitments And Contingencies Disclosure [Abstract]
Commitments and Contingencies	12. COMMITMENTS AND CONTINGENCIES
	Legal Reserves
	We are involved in various legal proceedings that arise in the ordinary course of our business. Although we cannot predict the outcome of these proceedings with certainty, we do not currently expect these matters to have a material adverse effect on our consolidated financial position or results of operations.
	The accrual of reserves for legal matters is included in Accrued Liabilities on our Consolidated Balance Sheets. The establishment of a reserve involves an estimation process that includes the advice of legal counsel and the subjective judgment of management. While we believe that these reserves are adequate, there are uncertainties associated with legal proceedings and we can give no assurance that our estimate of any related liability will not increase or decrease in the future. The reserved and unreserved exposures for our legal proceedings could change based upon developments in those proceedings or changes in the facts and circumstances. It is possible that we could incur losses in excess of the amounts currently accrued. Based on currently available information, we believe that it is remote that future costs related to known contingent liability exposures for legal proceedings will exceed our current accruals by an amount that would have a material adverse effect on our consolidated financial position, although cash flow could be significantly impacted in the reporting periods in which such costs are incurred.
	There have been no significant changes with respect to the legal matters disclosed in our Annual Report on Form 10-K for the year ended December 31, 2014.
	Environmental
	Due to the nature of the oil and natural gas business, we are exposed to possible environmental risks. We have implemented various policies and procedures to avoid environmental contamination and risks from environmental contamination. We conduct periodic reviews of our policies and properties to identify changes in the environmental risk profile. In these reviews we evaluate whether there is a probable liability, its amount and the likelihood that the liability will be incurred. The amount of any potential liability is determined by considering, among other matters, incremental direct costs of any likely remediation and the proportionate cost of employees who are expected to devote a significant amount of time directly to any remediation effort.
	We manage our exposure to environmental liabilities on properties to be acquired by identifying existing problems and assessing the potential liability. As of March 31, 2015, we know of no significant probable or possible environmental contingent liabilities.
	Letters of Credit
	At March 31, 2015, we had posted $7.0 million in various letters of credit to secure our drilling and related operations.
	Lease Commitments
	As of March 31, 2015, we have lease commitments for various real estate leases. Rent expense is recognized on a straight-line basis and has been recorded in General and Administrative expense on our Consolidated Statements of Operations. Rent expense for each of the three months ended March 31, 2015 and 2014 was approximately $0.2 million. Lease commitments by year for each of the next five years are presented in the table below:
	($ in Thousands)
	2015		$	848
	2016			1,129
	2017			1,143
	2018			721
	2019			721
	Thereafter			180
	Total		$	4,742
	Capacity Reservation
	We have a capacity reservation arrangement with a subsidiary of MarkWest Energy Partners, L.P. (“MarkWest”) to ensure sufficient capacity at the cryogenic gas processing plants owned by MarkWest in Butler County, Pennsylvania to process our produced natural gas. In the event that we do not process any gas through the cryogenic gas processing plants, we may be obligated to pay approximately $12.1 million in 2015, $25.8 million in 2016, $31.0 million in 2017, $31.0 million in 2018, $31.0 million in 2019 and $214.7 million thereafter, assuming our average working interest in the region of approximately 70%. Charges incurred for processing capacity with MarkWest were negligible during the three-month periods ended March 31, 2015 and 2014.
	Operational Commitments
	We have contracted drilling rig services on one rig to support our Appalachian Basin operations. The minimum cost to retain this rig would require gross payments of approximately $1.7 million in 2015, $2.2 million in 2016 and $2.2 million in 2017, which would be partially offset by other working interest owners, which vary from well to well. During the first quarter of 2015, we terminated two rig contracts earlier than their original term. To satisfy the early release, we incurred approximately $5.0 million in early termination fees, which were classified as Other Operating Expense in our Consolidated Statement of Operations as of March 31, 2015. Approximately $2.5 million of this amount was paid in January 2015 with the remaining amount due in January 2016. We also have agreements for contracted completion services in the Appalachian Basin. The minimum gross cost to retain the completion services is approximately $11.0 million in 2015, which would be partially offset by other working interest owners, which vary from well to well.
	Natural Gas Gathering, Processing and Sales Agreements
	During the normal course of business, we have entered into certain agreements to ensure the gathering, transportation, processing and sales of specified quantities of our oil, natural gas and NGLs. In some instances, we are obligated to pay shortfall fees, whereby we would pay a fee for any difference between actual volumes provided as compared to volumes that have been committed. In other instances, we are obligated to pay a fee on all volumes that are subject to the related agreement. In connection with our entry into certain of these agreements, we concurrently entered into a guaranty whereby we have guaranteed the payment of obligations under the specified agreements up to a maximum of $414.8 million, which is larger than our estimated minimum obligations due to certain contracts which have minimum commitment volumes and other contracts which contain provisions that require payment on all volumes delivered.
	For the three months ended March 31, 2015 and 2014, we incurred expenses related to the transportation, processing and marketing of our oil, natural gas and NGLs of approximately $18.8 million and $9.4 million, respectively. Expense related to these agreements makes up a substantial portion of our Lease Operating Expense, which we expect to continue as existing agreements commence and new transportation, processing and marketing agreements are entered that will enable us to sell our product. During the first quarter of 2015, we incurred approximately $0.9 million in fees related to unutilized capacity commitments. The unutilized commitment fees are related to undeveloped properties that we acquired during 2014. Minimum net obligations under these sales, gathering and transportation agreements for the next five years are as follows:
	($ in Thousands)		Total
	2015		$	16,516
	2016			32,656
	2017			51,581
	2018			54,267
	2019			53,181
	Thereafter			624,195
	Total		$	832,396
	Pennsylvania Impact Fee
	In 2012, Pennsylvania state legislators instituted a natural gas impact fee on producers of unconventional natural gas. The fee will be imposed on every producer of unconventional gas and applies to unconventional wells spud in Pennsylvania regardless of when spudding occurred. The fee for each unconventional gas well is determined using the following matrix, with vertical unconventional gas wells being charged 20% of the applicable rates:
		<$2.25(a)			$2.26 - $2.99(a)		$3.00 - $4.99(a)		$5.00 - $5.99(a)		>$5.99(a)
	Year One	$	40,200		$	45,300	$	50,300	$	55,300	$	60,400
	Year Two	$	30,200		$	35,000	$	40,200	$	45,300	$	55,300
	Year Three	$	25,200		$	30,200	$	30,200	$	40,200	$	50,300
	Year 4 – 10	$	10,100		$	15,100	$	20,100	$	20,100	$	20,100
	Year 11 – 15	$	5,000		$	5,000	$	10,100	$	10,100	$	10,100
	(a) Pricing utilized for determining annual fee is based on the arithmetic mean of the NYMEX settled price for the near-month contract as reported by the Wall Street Journal for the last trading day of each month of a calendar year for the 12-month period ending December 31.
	All fees owed will be due on April 1 of each year. For each of the three months ended March 31, 2015 and 2014, we recorded expense of approximately $0.6 million. We record expenses related to the impact fees as Production and Lease Operating Expense. As of March 31, 2015, approximately $6.2 million was accrued for the 2014 impact fees and a portion of the 2015 impact fees.

Earnings_Per_Common_Share

Earnings Per Common Share	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
Earnings Per Common Share	13. EARNINGS PER COMMON SHARE
	Basic income (loss) per common share is calculated based on the weighted average number of common shares outstanding at the end of the period, excluding restricted stock with performance-based and market-based vesting criteria. Diluted income per common share includes the speculative exercise of stock options and performance-based restricted stock which contain conditions that are not earnings or market-based, given that the hypothetical effect is not anti-dilutive. For the three months ended March 31, 2015, we excluded stock options to purchase 0.5 million shares due to our Net Loss from Continuing Operations. For the three months ended March 31, 2014, we excluded stock options to purchase 0.3 million shares of our common stock due to the estimate of shares that would be repurchased using the treasury method. For the three months ended March 31, 2015 and 2014, we excluded performance-based restricted stock of 1.3 million shares and 1.0 million shares due to performance metrics that have not yet been attained (for additional information on our non-cash compensation plans, see Note 11, Employee Benefit and Equity Plans, to our Consolidated Financial Statements). We utilize the if-converted method for calculating the impact of our 6.0% Convertible Perpetual Preferred Stock on diluted earnings per share. Under the if-converted method, convertible preferred stock is assumed as converted to common shares for the weighted average period outstanding. For the three months ended March 31, 2015, we excluded the assumed conversion of preferred stock equating to approximately 8.9 million shares due to our Net Loss from Continuing Operations. The following table sets forth the computation of basic and diluted earnings per common share:
	(in thousands, except per share amounts)	Three Months Ended March 31,
	Numerator:	2015			2014
	Net Income (Loss) From Continuing Operations	$	(18,479	)	$	8,755
	Net Income From Discontinued Operations, Less Noncontrolling Interests		665			113
	Less: Preferred Stock Dividends		(2,415	)		—
	Net Income (Loss) Attributable to Common Shareholders	$	(20,229	)	$	8,868
	Denominator:
	Weighted Average Common Shares Outstanding - Basic		54,370			52,984
	Effect of Dilutive Securities:
	Employee Stock Options		—			150
	Employee Performance-Based Restricted Stock Awards		—			369
	Effect of Assumed Conversions of Preferred Stock		—			—
	Weighted Average Common Shares Outstanding - Diluted		54,370			53,503
	Earnings per Common Share Attributable to Rex Energy Common Shareholders:
	Basic — Net Income (Loss) From Continuing Operations	$	(0.38	)	$	0.17
	— Net Income From Discontinued Operations		0.01			0
	— Net Income (Loss) Attributable to Rex Energy Common Shareholders	$	(0.37	)	$	0.17
	Diluted — Net Income (Loss) From Continuing Operations	$	(0.38	)	$	0.17
	— Net Income From Discontinued Operations		0.01			0
	— Net Income (Loss) Attributable to Rex Energy Common Shareholders	$	(0.37	)	$	0.17

Equity_Method_Investments

Equity Method Investments	3 Months Ended
	Mar. 31, 2015
Equity Method Investments And Joint Ventures [Abstract]
Equity Method Investments	14. EQUITY METHOD INVESTMENTS
	RW Gathering, LLC
	We own a 40% non-operated interest in RW Gathering, LLC (“RW Gathering”), which owns gas-gathering assets to facilitate development in our Appalachian Basin operations. We recorded our investment in RW Gathering of approximately $17.7 million and $17.9 million as of March 31, 2015 and December 31, 2014, respectively, on our Consolidated Balance Sheets as Equity Method Investments. We did not make any capital contributions to RW Gathering during the first three months of 2015 and 2014. RW Gathering recorded net losses from continuing operations of $0.5 million for each of the three-month periods ended March 31, 2015 and 2014. The losses incurred were due to insurance fees, bank fees, rent expenses and depreciation expense. Our share of the net loss is recorded on the Statements of Operations as Loss on Equity Method Investments.
	During each of the three-month periods ended March 31, 2015 and 2014, we incurred approximately $0.2 million in compression expenses that were charged to us from Williams Production Appalachia, LLC. These costs are in relation to compression costs incurred by RW Gathering and are recorded as Production and Lease Operating Expense on our Consolidated Statement of Operations. As of March 31, 2015 and December 31, 2014, there were no receivables due from RW Gathering to us.

Impairment_Expense

Impairment Expense	3 Months Ended
	Mar. 31, 2015
Goodwill And Intangible Assets Disclosure [Abstract]
Impairment Expense	15. IMPAIRMENT EXPENSE
	For the three months ended March 31, 2015, impairment expenses incurred were approximately $7.0 million while impairment expenses incurred during the three months ended March 31, 2014 were negligible. We continually monitor the carrying value of our oil and gas properties and make evaluations of their recoverability when circumstances arise that may contribute to impairment. The expense incurred during the first quarter of 2015 included approximately $4.0 million related to proved properties in our non-operated dry gas region of Clearfield County, Pennsylvania. This impairment was identified in relation to the continued decrease of natural gas prices since December 31, 2014. Approximately $3.0 million of impairment expense was incurred in relation to undeveloped leases that have expired or are expected to expire without development, primarily in the Appalachian Basin. As of March 31, 2015, we continued to carry the costs of undeveloped properties of approximately $335.3 million on our Consolidated Balance Sheet, which is primarily related to the Marcellus and Utica Shale in the Appalachian Basin and for which we have development, trade or lease extension plans.

Exploration_Expense

Exploration Expense	3 Months Ended
	Mar. 31, 2015
Extractive Industries [Abstract]
Exploration Expense	16. EXPLORATION EXPENSE
	For the three months ended March 31, 2015, we incurred approximately $0.5 million in exploration expenses as compared to $2.1 million in exploration expenses for the same period in 2014. The expense incurred in 2015 was primarily due to geological and geophysical type expenditures. Approximately $1.6 million of the expense incurred in 2014 was due to geological and geophysical type expenditures. An additional $0.4 million of expense was incurred through the payment of delay rentals, predominately in the Appalachian Basin.

Condensed_Consolidating_Financ

Condensed Consolidating Financial Information	3 Months Ended
	Mar. 31, 2015
Condensed Financial Information Of Parent Company Only Disclosure [Abstract]
Condensed Consolidating Financial Information	17. CONDENSED CONSOLIDATING FINANCIAL INFORMATION
	As of March 31, 2015, we had $675.0 million of outstanding Senior Notes, as shown in Note 7, Long-Term Debt, to our Consolidated Financial Statements. The Senior Notes are guaranteed by certain of our wholly-owned subsidiaries, or guarantor subsidiaries. Unless otherwise noted below, each of the following guarantor subsidiaries are wholly-owned by Rex Energy Corporation and have provided guarantees of the Senior Notes that are joint and several and full and unconditional as of March 31, 2015:
	—	Rex Energy I, LLC
	—	Rex Energy Operating Corporation
	—	Rex Energy IV, LLC
	—	PennTex Resources Illinois, Inc.
	—	R.E. Gas Development, LLC
	The non-guarantor subsidiaries include certain consolidated subsidiaries, including Water Solutions, R.E. Disposal, LLC, Rex Energy Marketing, LLC and R.E. Ventures Holdings, LLC. We derive much of our business through and derive much of our income through our subsidiaries. Therefore, our ability to make required payments with respect to indebtedness and other obligations depends on the financial results and condition of our subsidiaries and our ability to receive funds from our subsidiaries. As of March 31, 2015, there were no restrictions on the ability of any of the guarantor subsidiaries to transfer funds to us. There may be restrictions for certain non-guarantor subsidiaries.
	The following financial statements present condensed consolidating financial data for (i) Rex Energy Corporation, the issuer of the notes, (ii) the combined Guarantors, (iii) the combined other subsidiaries of the Company that did not guarantee the Notes, and (iv) eliminations necessary to arrive at our consolidated financial statements, which include condensed consolidated balance sheets as of March 31, 2015 and December 31, 2014, the condensed consolidating statements of operations for each of the three-month periods ended March 31, 2015 and 2014, and the condensed consolidating statements of cash flows for each of the three-month periods ended March 31, 2015 and 2014.
	REX ENERGY CORPORATION AND SUBSIDIARIES
	CONDENSED CONSOLIDATING BALANCE SHEETS
	AS OF MARCH 31, 2015
	($ in Thousands, Except Share and Per Share Data)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
	ASSETS
	Current Assets
	Cash and Cash Equivalents	$	5,014		$	(55	)	$	5		$	—		$	4,964
	Accounts Receivable		33,289			50			47			—			33,386
	Taxes Receivable		—			—			2			—			2
	Short-Term Derivative Instruments		32,422			—			427			—			32,849
	Assets Held for Sale					54,452						(11,756	)		42,696
	Inventory, Prepaid Expenses and Other		2,662			—			75			—			2,737
	Total Current Assets		73,387			54,447			556			(11,756	)		116,634
	Property and Equipment (Successful Efforts Method)
	Evaluated Oil and Gas Properties		1,153,433			524			—			(6,489	)		1,147,468
	Unevaluated Oil and Gas Properties		334,581			698			—			—			335,279
	Other Property and Equipment		45,837			895			—			—			46,732
	Wells and Facilities in Progress		102,236			428			—			(671	)		101,993
	Pipelines		17,555			—			—			(1,898	)		15,657
	Total Property and Equipment		1,653,642			2,545			—			(9,058	)		1,647,129
	Less: Accumulated Depreciation, Depletion and Amortization		(395,810	)		(798	)		—			1,271			(395,337	)
	Net Property and Equipment		1,257,832			1,747			—			(7,787	)		1,251,792
	Deferred Financing Costs and Other Assets—Net		2,421			—			14,637			—			17,058
	Equity Method Investments		17,692			—			—			—			17,692
	Long-Term Deferred Tax Asset		—			—			8,301			—			8,301
	Intercompany Receivables		—			—			978,279			(978,279	)		—
	Investment in Subsidiaries – Net		(1,909	)		—			249,967			(248,058	)		—
	Long-Term Derivative Instruments		9,732			—			308			—			10,040
	Total Assets	$	1,359,155		$	56,194		$	1,252,048		$	(1,245,880	)	$	1,421,517
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Current Liabilities
	Accounts Payable	$	47,472		$	55		$	—		$	(2,411	)	$	45,116
	Current Maturities of Long-Term Debt		1,056			—			—			—			1,056
	Accrued Liabilities		41,799			274			14,486			—			56,559
	Short-Term Derivative Instruments		1,271			—			122			—			1,393
	Current Deferred Tax Liability		—			—			8,301			—			8,301
	Liabilities Related to Assets Held for Sale		—			31,895			—			(376	)		31,519
	Total Current Liabilities		91,598			32,224			22,909			(2,787	)		143,944
	Long-Term Derivative Instruments		3,237			—			849			—			4,086
	Senior Secured Line of Credit and Other Long-Term Debt		137			—			38,000			—			38,137
	8.875% Senior Notes Due 2020		—			—			350,000			—			350,000
	6.25% Senior Notes Due 2022		—			—			325,000			—			325,000
	Premium on Senior Notes – Net		—			—			2,632			—			2,632
	Other Deposits and Liabilities		3,812			—			—			—			3,812
	Future Abandonment Cost		38,987			53			—			—			39,040
	Intercompany Payables		974,363			3,916			—			(978,279	)		—
	Total Liabilities		1,112,134			36,193			739,390			(981,066	)		906,651
	Stockholders’ Equity
	Preferred Stock		—			—			1			—			1
	Common Stock		—			—			54			—			54
	Additional Paid-In Capital		177,143			15,511			620,782			(192,654	)		620,782
	Accumulated Earnings (Deficit)		69,878			(517	)		(108,179	)		(72,160	)		(110,978	)
	Rex Energy Stockholders’ Equity		247,021			14,994			512,658			(264,814	)		509,859
	Noncontrolling Interests		—			5,007			—			—			5,007
Total Stockholders’ Equity		247,021			20,001			512,658			(264,814	)		514,866
Total Liabilities and Stockholders’ Equity	$	1,359,155		$	56,194		$	1,252,048		$	(1,245,880	)	$	1,421,517
REX ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
FOR THE THREE MONTHS ENDED MARCH 31, 2015
($ in Thousands)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
OPERATING REVENUE
Oil, Natural Gas and NGL Sales	$	54,000		$	111		$	—		$	—		$	54,111
Other Revenue		11			—			—			—			11
TOTAL OPERATING REVENUE		54,011			111			—			—			54,122
OPERATING EXPENSES
Production and Lease Operating Expense		29,014			38			—			—			29,052
General and Administrative Expense		6,659			16			2,976			—			9,651
Loss on Disposal of Asset		65			—			—			—			65
Impairment Expense		7,012			11			—			—			7,023
Exploration Expense		518			—			—			—			518
Depreciation, Depletion, Amortization and Accretion		26,292			69			—			(235	)		26,126
Other Operating Expense		5,191			—			—			—			5,191
TOTAL OPERATING EXPENSES		74,751			134			2,976			(235	)		77,626
INCOME (LOSS) FROM OPERATIONS		(20,740	)		(23	)		(2,976	)		235			(23,504	)
OTHER INCOME (EXPENSE)
Interest Expense		(58	)		—			(11,959	)		—			(12,017	)
Gain on Derivatives, Net		16,856			—			263			—			17,119
Other Expense		34			—			—			—			34
Loss From Equity Method Investments		(203	)		—			—			—			(203	)
Income (Loss) From Equity in Consolidated Subsidiaries		(23	)		23			(3,214	)		3,214			—
TOTAL OTHER INCOME (EXPENSE)		16,606			23			(14,910	)		3,214			4,933
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME		(4,134	)		—			(17,886	)		3,449			(18,571	)
TAX
Income Tax Benefit		20			—			72			—			92
INCOME (LOSS) FROM CONTINUING OPERATIONS		(4,114	)		—			(17,814	)		3,449			(18,479	)
Income From Discontinued Operations, Net of Income Tax		—			2,826			—			(864	)		1,962
Net Income (Loss)		(4,114	)		2,826			(17,814	)		2,585			(16,517	)
Net Income Attributable to Noncontrolling Interests of Discontinued Operations		—			1,297			—			—			1,297
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	$	(4,114	)	$	1,529		$	(17,814	)	$	2,585		$	(17,814	)
REX ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
FOR THE THREE MONTHS ENDING MARCH 31, 2015
($ in Thousands)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	$	(4,114	)	$	2,826		$	(17,814	)	$	2,585		$	(16,517	)
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating
Activities
Loss From Equity Method Investments		203			—			—			—			203
Non-Cash Expenses (Income)		(70	)		44			3,403			—			3,377
Depreciation, Depletion, Amortization and Accretion		26,292			1,480			—			(1,607	)		26,165
Gain on Derivatives		(16,856	)		—			(263	)		—			(17,119	)
Cash Settlements of Derivatives		10,579			—			500			—			11,079
Dry Hole Expense		(1	)		—			—			—			(1	)
(Gain) Loss on Sale of Asset		65			(32	)		—			—			33
Impairment Expense		7,012			11			—			—			7,023
Changes in operating assets and liabilities
Accounts Receivable		10,437			(1,087	)		428			251			10,029
Inventory, Prepaid Expenses and Other Assets		712			(322	)		(62	)		—			328
Accounts Payable and Accrued Liabilities		(12,518	)		(2,496	)		2,336			(251	)		(12,929	)
Other Assets and Liabilities		(199	)		(133	)		27			—			(305	)
NET CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES		21,542			291			(11,445	)		978			11,366
CASH FLOWS FROM INVESTING ACTIVITIES
Intercompany loans to subsidiaries		27,192			(1,688	)		(23,681	)		(1,823	)		—
Proceeds from Joint Venture Acreage Management		39			—			—			—			39
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets		217			455			—			—			672
Proceeds from Joint Venture		16,611			—			—			—			16,611
Acquisitions of Undeveloped Acreage		(17,454	)		(5	)		—			—			(17,459	)
Capital Expenditures for Development of Oil and Gas Properties and Equipment		(60,719	)		(7,139	)		—			845			(67,013	)
NET CASH USED IN INVESTING ACTIVITIES		(34,114	)		(8,377	)		(23,681	)		(978	)		(67,150	)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from Long-Term Debt and Lines of Credit		—			18,826			54,000			—			72,826
Repayments of Long-Term Debt and Lines of Credit		—			(9,761	)		(16,000	)		—			(25,761	)
Repayments of Loans and Other Long-Term Debt		(392	)		(294	)		—			—			(686	)
Debt Issuance Costs		—			—			(459	)		—			(459	)
Dividends Paid		—			—			(2,415	)		—			(2,415	)
Distributions by the Partners of Consolidated Subsidiaries		—			(531	)		—			—			(531	)
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES		(392	)		8,240			35,126			—			42,974
NET INCREASE (DECREASE) IN CASH		(12,964	)		154			—			—			(12,810	)
CASH – BEGINNING		17,978			113			5			—			18,096
CASH - ENDING	$	5,014		$	267		$	5		$	—		$	5,286
REX ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING BALANCE SHEETS
AS OF DECEMBER 31, 2014
($ in Thousands, Except Share and Per Share Data)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
ASSETS
Current Assets
Cash and Cash Equivalents	$	17,978		$	—		$	—		$	—		$	17,978
Accounts Receivable		43,726			210			—			—			43,936
Taxes Receivable		—			—			504			—			504
Short-Term Derivative Instruments		29,265			—			—			—			29,265
Assets Held for Sale		—			36,794			—			(2,537	)		34,257
Inventory, Prepaid Expenses and Other		3,374			—			29			—			3,403
Total Current Assets		94,343			37,004			533			(2,537	)		129,343
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties		1,084,332			467			—			(5,760	)		1,079,039
Unevaluated Oil and Gas Properties		321,708			705			—			—			322,413
Other Property and Equipment		45,466			895			—			—			46,361
Wells and Facilities in Progress		127,759			456			—			(560	)		127,655
Pipelines		17,555			—			—			(1,898	)		15,657
Total Property and Equipment		1,596,820			2,523			—			(8,218	)		1,591,125
Less: Accumulated Depreciation, Depletion and Amortization		(367,224	)		(730	)		—			1,037			(366,917	)
Net Property and Equipment		1,229,596			1,793			—			(7,181	)		1,224,208
Deferred Financing Costs and Other Assets—Net		2,421			—			14,649			—			17,070
Equity Method Investments		17,895			—			—			—			17,895
Long-Term Deferred Tax Asset		—			—			8,301			—			8,301
Intercompany Receivables		—			—			951,025			(951,025	)		—
Investment in Subsidiaries – Net		4,161			1,541			258,448			(264,150	)		—
Long-Term Derivative Instruments		4,904			—			—			—			4,904
Total Assets	$	1,353,320		$	40,338		$	1,232,956		$	(1,224,893	)	$	1,401,721
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Accounts Payable	$	55,877		$	—		$	—		$	(2,537	)	$	53,340
Current Maturities of Long-Term Debt		1,176			—			—			—			1,176
Accrued Liabilities		46,783			571			12,124			—			59,478
Short-Term Derivative Instruments		421			—			—			—			421
Current Deferred Tax Liability		—			—			8,301			—			8,301
Liabilities Related to Assets Held for Sale		—			25,115			—			—			25,115
Total Current Liabilities		104,257			25,686			20,425			(2,537	)		147,831
Long-Term Derivative Instruments		2,377			—			—			—			2,377
Senior Secured Line of Credit and Other Long-Term Debt		251			—			—			—			251
8.875% Senior Notes Due 2020		—			—			350,000			—			350,000
6.25% Senior Notes Due 2022		—			—			325,000			—			325,000
Premium (Discount) on Senior Notes – Net		—			—			2,725			—			2,725
Other Deposits and Liabilities		4,018			—			—			—			4,018
Future Abandonment Cost		38,097			49			—			—			38,146
Intercompany Payables		947,114			3,911			—			(951,025	)		—
Total Liabilities		1,096,114			29,646			698,150			(953,562	)		870,348
Stockholders’ Equity
Preferred Stock		—			—			1			—			1
Common Stock		—			—			54			—			54
Additional Paid-In Capital		177,144			79,743			617,826			(256,887	)		617,826
Accumulated Earnings (Deficit)		80,062			(69,253	)		(83,075	)		(18,483	)		(90,749	)
Rex Energy Stockholders’ Equity		257,206			10,490			534,806			(275,370	)		527,132
Noncontrolling Interests		—			202			—			4,039			4,241
Total Stockholders’ Equity		257,206			10,692			534,806			(271,331	)		531,373
Total Liabilities and Stockholders’ Equity	$	1,353,320		$	40,338		$	1,232,956		$	(1,224,893	)	$	1,401,721
REX ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
FOR THE THREE MONTHS ENDED MARCH 31, 2014
($ in Thousands)
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
OPERATING REVENUE
Oil, Natural Gas and NGL Sales	$	81,299		$	—		$	—		$	—		$	81,299
Other Revenue		44			—			—			—			44
TOTAL OPERATING REVENUE		81,343			—			—			—			81,343
OPERATING EXPENSES
Production and Lease Operating Expense		20,030			3			—			—			20,033
General and Administrative Expense		7,880			23			1,659			—			9,562
Loss on Disposal of Asset		72			—			—			—			72
Impairment Expense		25			—			—			—			25
Exploration Expense		2,060			—			—			—			2,060
Depreciation, Depletion, Amortization and Accretion		19,823			11			—			(111	)		19,723
Other Operating Expense		83			—			—			—			83
TOTAL OPERATING EXPENSES		49,973			37			1,659			(111	)		51,558
INCOME (LOSS) FROM OPERATIONS		31,370			(37	)		(1,659	)		111			29,785
OTHER INCOME (EXPENSE)
Interest Expense		(15	)		—			(6,918	)		—			(6,933	)
Gain (Loss) on Derivatives, Net		(10,439	)		—			689			—			(9,750	)
Other Expense		(37	)		—			—			—			(37	)
Loss From Equity Method Investments		(200	)		—			—			—			(200	)
Income (Loss) From Equity in Consolidated Subsidiaries		(25	)		25			13,567			(13,567	)		—
TOTAL OTHER INCOME (EXPENSE)		(10,716	)		25			7,338			(13,567	)		(16,920	)
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE		20,654			(12	)		5,679			(13,456	)		12,865
INCOME TAX
Income Tax (Expense) Benefit		(6,637	)		(662	)		3,189			—			(4,110	)
INCOME (LOSS) FROM CONTINUING OPERATIONS		14,017			(674	)		8,868			(13,456	)		8,755
Loss From Discontinued Operations, Net of Income Tax		—			3,840			—			(2,158	)		1,682
Net Income (Loss)		14,017			3,166			8,868			(15,614	)		10,437
Net Income Attributable to Noncontrolling Interests of Discontinued Operations		—			1,569			—			—			1,569
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	$	14,017		$	1,597		$	8,868		$	(15,614	)	$	8,868
Preferred Stock Dividends		—			—			—			—			—
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	$	14,017		$	1,597		$	8,868		$	(15,614	)	$	8,868
REX ENERGY CORPORATION AND SUBSIDIARIES
CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
FOR THE THREE MONTHS ENDING MARCH 31, 2014
	Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	$	14,017		$	3,166		$	8,868		$	(15,614	)	$	10,437
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by
Operating Activities
Loss From Equity Method Investments		200			—			—			—			200
Non-Cash Expenses		(63	)		139			1,922			—			1,998
Depreciation, Depletion, Amortization and Accretion		19,823			712			—			(111	)		20,424
Deferred Income Tax Expense (Benefit)		6,597			743			(3,189	)		—			4,151
Gain on Derivatives		10,439			—			(689	)		—			9,750
Cash Settlements of Derivatives		(5,245	)		—			368			—			(4,877	)
Dry Hole Expense		86			—			—			—			86
(Gain) Loss on Sale of Asset		71			—			—			—			71
Impairment Expense		25			—			—			—			25
Changes in operating assets and liabilities
Accounts Receivable		(8,921	)		(10,439	)		(50	)		3,489			(15,921	)
Inventory, Prepaid Expenses and Other Assets		31			14			(189	)		—			(144	)
Accounts Payable and Accrued Liabilities		(16,986	)		2,878			7,805			(3,489	)		(9,792	)
Other Assets and Liabilities		(307	)		—			(41	)		—			(348	)
NET CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES		19,767			(2,787	)		14,805			(15,725	)		16,060
CASH FLOWS FROM INVESTING ACTIVITIES
Intercompany loans to subsidiaries		62,160			(175	)		(75,553	)		13,568			—
Proceeds from Joint Venture Acreage Management		67			—			—			—			67
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets		15			—			—			—			15
Acquisitions of Undeveloped Acreage		(15,077	)		(457	)		—			—			(15,534	)
Capital Expenditures for Development of Oil and Gas Properties and Equipment		(66,618	)		(2,020	)		—			2,157			(66,481	)
NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES		(19,453	)		(2,652	)		(75,553	)		15,725			(81,933	)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from Long-Term Debt and Lines of Credit		—			5,922			61,000			—			66,922
Repayments of Long-Term Debt and Lines of Credit		—			(19	)		—			—			(19	)
Repayments of Loans and Other Notes Payable		(399	)		(129	)		—			—			(528	)
Debt Issuance Costs		—			—			(252	)		—			(252	)
Distributions by the Partners of Consolidated Subsidiaries		—			(360	)		—			—			(360	)
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES		(399	)		5,414			60,748			—			65,763
NET INCREASE (DECREASE) IN CASH		(85	)		(25	)		—			—			(110	)
CASH – BEGINNING		1,386			509			5			—			1,900
CASH - ENDING	$	1,301		$	484		$	5		$	—		$	1,790

Recently_Issued_Accounting_Pro1

Recently Issued Accounting Pronouncements (Policies)	3 Months Ended
	Mar. 31, 2015
Accounting Policies [Abstract]
Recently Issued Accounting Pronouncements	In April 2014, the FASB issued ASU 2014-08, Presentation of Financial Statements and Property, Plant, and Equipment: Reporting Discontinued Operations and Disclosures of Disposal of Components of an Entity. The amendments in this ASU change the criteria for reporting discontinued operations while enhancing the disclosures in this area. Under the new guidance, only disposals representing a strategic shift in operations should be presented as discontinued operations. Those strategic shifts should have a major effect on the organization’s operations and financial results. In addition, the new guidance requires expanded disclosures about discontinued operations that will provide financial statement users with more information about the assets, liabilities, income and expenses of discontinued operations. The amendments in this ASU are effective in the first quarter of 2015 for public organizations with calendar year ends. We adopted this ASU on January 1, 2015.
	In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis. The amendments in this ASU intend to improve targeted areas of consolidation guidance for legal entities such as limited partnerships, limited liability corporations and securitization structures. The ASU focuses on the consolidation evaluation for reporting organizations that are required to evaluate whether they should consolidate certain legal entities. In addition to reducing the number of consolidation models from four to two, the new standard places more emphasis on risk of loss when determining a controlling financial interest, reduces the frequency of the application of related-party guidance when determining a controlling financial interest in a variable interest entity and changes consolidation conclusions in several industries that typically make use of limited partnerships or variable interest entities. This ASU will be effective for periods beginning after December 15, 2015, for public companies, and early adoption is permitted, including adoption in an interim period. We are currently evaluating the potential effect of this ASU but do not believe that it will have a material impact on our Consolidated Financial Statements.
	In April 2015, the FASB issued ASU 2015-03, Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs. The standard requires an entity to present debt issuance costs related to a recognized liability as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The guidance in the ASU is effective for public entities for annual reporting periods beginning after December 15, 2015, including interim periods therein. Early adoption is permitted. We are currently evaluating the potential effect of this ASU and the related impact on our Consolidated Financial Statements. As of March 31, 2015, we had approximately $14.6 million in net deferred financing costs that would be potentially reclassified to reduce the debt carrying balance.

Future_Abandonment_Cost_Tables

Future Abandonment Cost (Tables)	3 Months Ended
	Mar. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Future Abandonment Costs	We account for future abandonment costs that relate to wells that are drilled jointly based on our working interest in those wells.
	($ in Thousands)	Three Months Ended March 31, 2015
	Beginning Balance at January 1, 2015	$	40,099
	Future Abandonment Obligation Incurred		249
	Future Abandonment Obligation Settled		(266	)
	Future Abandonment Obligation Cancelled or Sold		(34	)
	Future Abandonment Obligation Revision of Estimated Obligation		(2	)
	Future Abandonment Obligation Accretion Expense		921
	Total Future Abandonment Cost1	$	40,967
	1 Includes approximately $1.9 million of short-term future abandonment costs, which are classified as Accrued Liabilities on our Consolidated Balance Sheet.

Discontinued_OperationsAssets_1

Discontinued Operations/Assets Held For Sale (Tables)	3 Months Ended
	Mar. 31, 2015
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Summary of Financial Information for Discontinued Operations	The carrying value of the assets and liabilities of Water Solutions that are classified as held for sale in the accompanying Consolidated Balance Sheets at March 31, 2015 and December 31, 2014 are as follows:
		March 31,			December 31,
	($ in Thousands)	2015			2014
	Assets:
	Cash and Cash Equivalents	$	322		$	118
	Accounts Receivable		14,223			13,226
	Inventory, Prepaid Expenses and Other		484			163
	Total Current Assets		15,029			13,507
	Other Property and Equipment, Net		26,681			19,690
	Wells and Facilities in Progress		628			688
	Intangible Assets, Net		358			372
	Total Long-Term Assets		27,667			20,750
	Total Assets Held for Sale	$	42,696		$	34,257
	Liabilities:
	Accounts Payable	$	3,475		$	3,694
	Current Maturities of Long-Term Debt		14,344			6,236
	Accrued Liabilities		3,892			6,304
	Total Current Liabilities		21,711			16,234
	Senior Secured Line of Credit and Long-Term Debt		9,808			8,881
	Total Long-Term Liabilities		9,808			8,881
	Total Liabilities Related to Assets Held for Sale	$	31,519		$	25,115
	Net Assets Held for Sale	$	11,177		$	9,142
Water Solutions Holdings, LLC
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Summary of Financial Information for Discontinued Operations	Summarized financial information for Discontinued Operations related to Water Solutions is set forth in the table below, and does not reflect the costs of certain services provided. Such indirect costs, which were not allocated to the Discontinued Operations, were for services, including legal counsel, insurance, external audit fees, payroll processing, certain human resource services and information technology systems support.
		Three Months Ended March 31,
	($ in Thousands)	2015			2014
	Revenues:
	Field Services Revenue	$	14,964		$	15,304
	Total Operating Revenue		14,964			15,304
	Costs and Expenses:
	General and Administrative Expense		977			830
	Depreciation, Depletion, Amortization and Accretion		39			701
	Field Services Operating Expense		11,289			11,796
	Gain on Sale of Asset		(32	)		—
	Interest Expense		191			202
	Other Expense		103			11
	Total Costs and Expenses		12,567			13,540
	Income from Discontinued Operations Before Income Taxes		2,397			1,764
	Income Tax Expense		(435	)		(82	)
	Income from Discontinued Operations, net of taxes	$	1,962		$	1,682

LongTerm_Debt_Tables

Long-Term Debt (Tables)	3 Months Ended
	Mar. 31, 2015
Debt Disclosure [Abstract]
Components of Long-Term Debt and Lines of Credit	In addition to the Senior Credit Facility and the Senior Notes, we may, from time to time in the normal course of business finance assets such as vehicles, office equipment and leasehold improvements through debt financing at favorable terms. Long-term debt and other obligations consisted of the following at March 31, 2015 and December 31, 2014:
	($ in Thousands)	March 31, 2015 (Unaudited)			31-Dec-14
	8.875% Senior Notes Due 2020	$	350,000		$	350,000
	6.25% Senior Notes Due 2022		325,000			325,000
	Premium on Senior Notes, Net		2,632			2,725
	Senior Line of Credit(a)		38,000			—
	Capital Leases and Other Obligations(a)		1,193			1,427
	Total Debt		716,825			679,152
	Less Current Portion of Long-Term Debt		(1,056	)		(1,176	)
	Total Long-Term Debt	$	715,769		$	677,976
	(a)	The Senior Credit Facility requires us to make monthly payments of interest on the outstanding balance of loans made under the agreement. The weighted average interest rate on borrowings under our Senior Credit Facility for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 4.2% and 4.0%, respectively.
Principal Maturity Schedule for Total Debt Outstanding	The following is the principal maturity schedule for debt outstanding as of March 31, 2015:
	2015	$	868
	2016		325
	2017		—
	2018		—
	2019		38,000
	Thereafter		675,000
	Total(a)	$	714,193
	—	Excludes $2.6 million net premium on Senior Notes.

Fair_Value_Of_Financial_And_De1

Fair Value Of Financial And Derivative Instruments (Tables)	3 Months Ended
	Mar. 31, 2015
Fair Value Of Financial Instruments And Derivative Instruments [Abstract]
Schedule of Location and Amounts of Gains and Losses on Derivative Instruments	The following table summarizes the location and amounts of gains and losses on our derivative instruments from continuing operations, none of which are designated as hedges for accounting purposes, in our accompanying Consolidated Statements of Operations for the three months ended March 31, 2015 and 2014:
			For the Three Months Ended March 31,
	($ in Thousands)		2015				2014
	Oil		$	2,876			$	(1,168	)
	Natural Gas			13,600				(8,928	)
	NGLs			435				(343	)
	Refined Products			(55	)			—
	Interest Rate			263				689
	Gain (Loss) on Derivatives, Net		$	17,119			$	(9,750	)
Asset or Liability Financial Commodity Derivative Instrument Positions	Our open asset/(liability) financial commodity derivative instrument positions at March 31, 2015 consisted of:
	Period		Volume		Put Option				Floor				Ceiling				Swap			Long Call		Fair Market Value ($ in Thousands)
	Oil
	2015 - Deferred Put Spreads		90,000 Bbls		$	73.08			$	83.33			$	—			$	—		$	—	$	739
	2015 - Collars		180,000 Bbls			—				52.58				62.89				—			—		480
	2015 - Call Protected Swaps		15,000 Bbls			—				—				—				95.76			110		691
	2015 - Three-Way Collars		450,000 Bbls			50				65				72.5				—			—		4,232
	2016 - Collars		60,000 Bbls			—				53.75				63.81				—			—		144
	2016 - Deferred Put Spreads		120,000 Bbls			50				65				—				—			—		83
			915,000 Bbls																			$	6,369
	Natural Gas
	2015 - Swaps		17,275,000 Mcf		$	—			$	—			$	—			$	3.38		$	—	$	10,563
	2015 - Swaptions		2,650,000 Mcf			—				—				—				3.54			—		1,700
	2015 - Cap Swaps		5,850,000 Mcf			3.43				—				—				4.12			—		3,026
	2015 - Three-Way Collars		3,400,000 Mcf			2.64				3.32				3.88				—			—		769
	2015 - Put Spreads		4,550,000 Mcf			2.56				3.32				—				—			—		1,873
	2015 - Calls		2,850,000 Mcf			—				—				3.94				—			—		(99	)
	2015 - Basis Swaps - Dominion South		9,780,000 Mcf			—				—				—				(0.79	)		—		1,174
	2016 - Swaps		6,630,000 Mcf			—				—				—				3.69			—		3,679
	2016 - Swaptions		0 Mcf			—				—				—				—			—		(692	)
	2016 - Cap Swaps		3,600,000 Mcf			3.45				—				—				4.11			—		1,454
	2016 - Collars		900,000 Mcf			—				3.2				4.04				—			—		223
	2016 - Three-Way Collars		8,850,000 Mcf			2.66				3.42				4.29				—			—		1,845
	2016 - Put Spreads		2,100,000 Mcf			2.25				3				—				—			—		(18	)
	2016 - Calls		9,120,000 Mcf			—				—				4.23				—			—		(988	)
	2016 - Basis Swaps - Dominion South		7,320,000 Mcf			—				—				—				(0.83	)		—		(207	)
	2017 - Swaps		1,800,000 Mcf			—				—				—				3.64			—		577
	2017 - Cap Swaps		2,100,000 Mcf			3.34				—				—				4.07			—		811
	2017 - Three-Way Collars		6,600,000 Mcf			2.37				3.19				4.26				—			—		1,089
	2017 - Calls		1,440,000 Mcf			—				—				3.9				—			—		(283	)
	2017 - Basis Swaps - Dominion South		7,300,000 Mcf			—				—				—				(0.83	)		—		(207	)
	2017 - Basis Swaps - Texas Gas		14,600,000 Mcf			—				—				—				(0.13	)		—		(172	)
	2018 - Swaps		1,200,000 Mcf			—				—				—				3.61			—		273
	2018 - Cap Swaps		1,800,000 Mcf			3.3				—				—				4.05			—		683
	2018 - Basis Swaps - Dominion South		7,300,000 Mcf			—				—				—				(0.83	)		—		(207	)
	2018 - Basis Swaps - Texas Gas		14,600,000 Mcf			—				—				—				(0.13	)		—		(172	)
	2019 - Basis Swaps - Dominion South		7,300,000 Mcf			—				—				—				(0.83	)		—		(207	)
	2020 - Basis Swaps - Dominion South		7,320,000 Mcf			—				—				—				(0.83	)		—		(207	)
			158,235,000 Mcf																			$	26,280
	NGLs
	2015 - C3+ NGL Swaps		732,000 Bbls		$	—			$	—			$	—			$	32.9		$	—	$	3,934
	2015 - Ethane Swaps		277,500 Bbls			—				—				—				8.5			—		234
	2016 - C3+ NGL Swaps		375,000 Bbls			—				—				—				31.08			—		887
	2016 - Ethane Swaps		120,000 Bbls			—				—				—				8.09			—		(2	)
			1,504,500 Bbls																			$	5,053
	Refined Product (Heating Oil)
	2016 - Swaps		12,000 Bbls		$	—			$	—			$	—			$	42		$	—		(55	)
			12,000 Bbls																			$	(55	)
Combined Fair Value of Derivatives	The combined fair value of derivatives, none of which are designated or qualifying as hedges, included in our Consolidated Balance Sheets as of March 31, 2015 and December 31, 2014 is summarized below:
		March 31,				December 31,
	($ in Thousands)	2015				2014
	Short-Term Derivative Assets:
	Crude Oil—Collars	$	552			$	—
	Crude Oil—Deferred Put Spread		760				1,413
	Crude Oil—Call Protected Swap		691				1,227
	Crude Oil—Three-Way Collars		4,232				4,596
	NGL—Swaps		5,008				6,181
	Natural Gas—Swaps		11,232				4,522
	Natural Gas—Cap Swaps		3,585				3,430
	Natural Gas—Basis Swaps		1,329				2,815
	Natural Gas—Three-Way Collars		1,263				5,081
	Natural Gas—Swaption		1,755				—
	Natural Gas—Collars		223				—
	Natural Gas—Call		(80	)			—
	Natural Gas—Put Spread		1,872				—
	Interest Rate—Swap		427				—
	Total Short-Term Derivative Assets	$	32,849			$	29,265
	Long-Term Derivative Assets:
	NGL—Swaps	$	838			$	—
	Crude Oil—Collars		72				—
	Crude Oil—Deferred Put Spread		62				—
	Natural Gas—Cap Swaps		2,389				1,617
	Natural Gas—Swaps		3,890				1,554
	Natural Gas—Basis Swaps		41				—
	Natural Gas—Three-Way Collars		2,440				1,733
	Interest Rate—Swap		308				—
	Total Long-Term Derivative Assets	$	10,040			$	4,904
	Total Derivative Assets	$	42,889			$	34,169
	Short-Term Derivative Liabilities:
	NGL—Swaps	$	(791	)		$	—
	Refined Product—Swaps		(13	)			—
	Natural Gas—Call		(174	)			(74	)
	Natural Gas—Swaps		(30	)			—
	Natural Gas—Swaption		(55	)			(154	)
	Natural Gas—Basis Swaps		(207	)			(193	)
	Interest Rate—Swaption		(123	)			—
	Total Short - Term Derivative Liabilities	$	(1,393	)		$	(421	)
	Long-Term Derivative Liabilities:
	NGL—Swaps	$	(2	)		$	—
	Refined Product—Swaps		(42	)			—
	Natural Gas—Put Spread		(17	)			—
	Natural Gas—Basis Swaps		(1,368	)			(1,281	)
	Natural Gas—Swaption		(692	)			—
	Natural Gas—Call		(1,116	)			(1,096	)
	Interest Rate—Swap		(849	)			—
	Total Long-Term Derivative Liabilities	$	(4,086	)		$	(2,377	)
	Total Derivative Liabilities	$	(5,479	)		$	(2,798	)
Significant Unobservable Inputs Used in Fair Value Measurements of Natural Gas Basis Swaps	The significant unobservable inputs and the range and weighted average of these inputs used in the fair value measurements of our natural gas basis swaps as of March 31, 2015 and December 31, 2014 are included in the table below.
		As of March 31, 2015
		Range		Weighted Average				Fair Value
		(price per Mcf)		(price per Mcf)				(in thousands)
	Natural Gas Basis Differential Forward Curve - Dominion South	($0.38) - ($1.23)		$	(0.82	)		$	139
	Natural Gas Basis Differential Forward Curve - Texas Gas	($0.10) - ($0.13)		$	(0.11	)		$	(344	)
		As of December 31, 2014
		Range		Weighted Average				Fair Value
		(price per Mcf)		(price per Mcf)				(in thousands)
	Natural Gas Basis Differential Forward Curve - Dominion South	($0.27) - ($1.39)		$	(0.84	)		$	1,341
Fair Value Hierarchy Table for Assets and Liabilities Measured at Fair Value	The following table presents the fair value hierarchy table for assets and liabilities measured at fair value:
						Fair Value Measurements at March 31, 2015 Using:
	($ in Thousands)	Total Carrying Value as of March 31, 2015				Quoted Prices in Active Markets for Identical Assets (Level 1)				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)
	Commodity Derivatives	$	37,647			$	—			$	37,852			$	(205	)
	Interest Rate Swap		(114	)			—				(114	)			—
	Interest Rate Swaption		(123	)			—				(123	)			—
						Fair Value Measurements at December 31, 2014 Using:
	($ in Thousands)	Total Carrying Value as of December 31, 2014				Quoted Prices in Active Markets for Identical Assets (Level 1)				Significant Other Observable Inputs (Level 2)				Significant Unobservable Inputs (Level 3)
	Commodity Derivatives	$	31,371			$	—			$	30,030			$	1,341
Reconciliation of Commodity Derivative Contracts Measured at Fair Value on Recurring Basis Using Significant Unobservable Inputs (Level 3)	The table below sets forth a reconciliation of our commodity derivative contracts at fair value on a recurring basis using significant unobservable inputs (Level 3) during the three months ended March 31, 2015 and 2014:
		Three Months Ended March 31,
	($ in Thousands)	2015				2014
	Beginning Balance of Level 3	$	1,341			$	4,323
	Changes in Fair Value		(1,955	)			(2,356	)
	Purchases		—				—
	Settlements Received		409				284
	Ending Balance of Level 3	$	(205	)		$	2,251
Financial Instruments Not Recorded at Fair Value	The following table sets forth the fair values of financial instruments that are not recorded at fair value in our Consolidated Financial Statements:
		31-Mar-15								31-Dec-14
	($ in Thousands)	Carrying Amount				Fair Value				Carrying Amount				Fair Value
	8.875% Senior Notes due 2020	$	350,000			$	269,500			$	350,000			$	311,955
	6.25% Senior Notes due 2022	$	325,000			$	217,360				325,000				241,313
	Secured Lines of Credit		38,000				38,000				—				—
	Capital Leases and Other Obligations		1,193				1,167				1,427				1,393
	Total	$	714,193			$	526,027			$	676,427			$	554,661

Income_Taxes_Tables

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2015
Income Tax Disclosure [Abstract]
Schedule of Income Tax Included in Continuing Operations	Income tax included in continuing operations was as follows:
		Three Months Ended March 31,
	($ in Thousands)	2015			2014
	Income (Expense) Benefit	$	92		$	(4,110	)
	Effective Tax Rate		0.5	%		31.9	%

Recovered_Sheet1

Employee Benefit And Equity Plans (Tables)	3 Months Ended
	Mar. 31, 2015
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Summary of Issued and Outstanding Stock Options	A summary of the status of our issued and outstanding stock options as of March 31, 2015 is as follows:
					Outstanding						Exercisable
	Exercise Price				Number Outstanding At 3/31/15				Weighted-Average Exercise Price		Number Exercisable At 3/31/15		Weighted-Average Exercise Price
	$	4.05				40,000			$	4.05		—	$	—
	$	4.9				40,000			$	4.9		—	$	—
	$	5.04				46,041			$	5.04		46,041	$	5.04
	$	9.5				75,000			$	9.5		75,000	$	9.5
	$	9.99				149,333			$	9.99		149,333	$	9.99
	$	10.42				29,548			$	10.42		29,548	$	10.42
	$	11.87				3,500			$	11.87		3,500	$	11.87
	$	12.5				19,139			$	12.5		19,139	$	12.5
	$	13.19				50,000			$	13.19		50,000	$	13.19
	$	22.34				30,000			$	22.34		30,000	$	22.34
						482,561			$	9.77		402,561	$	10.82
Monte Carlo Simulation Model Assumptions Used to Estimate Fair Value of Restricted Stock	Average fair values were estimated on the date of each grant using a Monte Carlo Simulation model that estimates the most likely outcome based on the terms of the award and used the following assumptions:
		Three Months Ended March 31, 2015				Year Ended December 31, 2014
	Expected Dividend Yield		0	%			0	%
	Risk-Free Interest Rate		1	%			0.8	%
	Expected Volatility – Rex Energy		58.6	%			50.4	%
	Expected Volatility – Peer Group	29.8%-85.0		%		28.4%-65.7		%
	Market Index		35.6	%			35.3	%
	Expected Life	Three Years				Three Years
Summary of Nonvested Restricted Stock Activity	A summary of the restricted stock activity for the three months ended March 31, 2015 is as follows:
		Number of Shares				Weighted-Average Grant Date Fair Value
	Restricted stock awards, as of December 31, 2014		1,519,301			$	14.05
	Awards		1,336,295				4.04
	Forfeitures		(244,539	)			12.55
	Vested		(202,492	)			12.52
	Restricted stock awards, as of March 31, 2015		2,408,565			$	8.65

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	3 Months Ended
	Mar. 31, 2015
Commitments And Contingencies Disclosure [Abstract]
Lease Commitments for Each of Next Five Years	As of March 31, 2015, we have lease commitments for various real estate leases. Rent expense is recognized on a straight-line basis and has been recorded in General and Administrative expense on our Consolidated Statements of Operations. Rent expense for each of the three months ended March 31, 2015 and 2014 was approximately $0.2 million. Lease commitments by year for each of the next five years are presented in the table below:
	($ in Thousands)
	2015		$	848
	2016			1,129
	2017			1,143
	2018			721
	2019			721
	Thereafter			180
	Total		$	4,742
Minimum Net Obligations under Sales, Gathering and Transportation Agreements	Minimum net obligations under these sales, gathering and transportation agreements for the next five years are as follows:
	($ in Thousands)		Total
	2015		$	16,516
	2016			32,656
	2017			51,581
	2018			54,267
	2019			53,181
	Thereafter			624,195
	Total		$	832,396
Fee for Unconventional Gas Wells	In 2012, Pennsylvania state legislators instituted a natural gas impact fee on producers of unconventional natural gas. The fee will be imposed on every producer of unconventional gas and applies to unconventional wells spud in Pennsylvania regardless of when spudding occurred. The fee for each unconventional gas well is determined using the following matrix, with vertical unconventional gas wells being charged 20% of the applicable rates:
		<$2.25(a)			$2.26 - $2.99(a)		$3.00 - $4.99(a)		$5.00 - $5.99(a)		>$5.99(a)
	Year One	$	40,200		$	45,300	$	50,300	$	55,300	$	60,400
	Year Two	$	30,200		$	35,000	$	40,200	$	45,300	$	55,300
	Year Three	$	25,200		$	30,200	$	30,200	$	40,200	$	50,300
	Year 4 – 10	$	10,100		$	15,100	$	20,100	$	20,100	$	20,100
	Year 11 – 15	$	5,000		$	5,000	$	10,100	$	10,100	$	10,100
	(a) Pricing utilized for determining annual fee is based on the arithmetic mean of the NYMEX settled price for the near-month contract as reported by the Wall Street Journal for the last trading day of each month of a calendar year for the 12-month period ending December 31.

Earnings_Per_Common_Share_Tabl

Earnings Per Common Share (Tables)	3 Months Ended
	Mar. 31, 2015
Earnings Per Share [Abstract]
Computation of Basic and Diluted Earning Per Common Share	The following table sets forth the computation of basic and diluted earnings per common share:
	(in thousands, except per share amounts)	Three Months Ended March 31,
	Numerator:	2015			2014
	Net Income (Loss) From Continuing Operations	$	(18,479	)	$	8,755
	Net Income From Discontinued Operations, Less Noncontrolling Interests		665			113
	Less: Preferred Stock Dividends		(2,415	)		—
	Net Income (Loss) Attributable to Common Shareholders	$	(20,229	)	$	8,868
	Denominator:
	Weighted Average Common Shares Outstanding - Basic		54,370			52,984
	Effect of Dilutive Securities:
	Employee Stock Options		—			150
	Employee Performance-Based Restricted Stock Awards		—			369
	Effect of Assumed Conversions of Preferred Stock		—			—
	Weighted Average Common Shares Outstanding - Diluted		54,370			53,503
	Earnings per Common Share Attributable to Rex Energy Common Shareholders:
	Basic — Net Income (Loss) From Continuing Operations	$	(0.38	)	$	0.17
	— Net Income From Discontinued Operations		0.01			0
	— Net Income (Loss) Attributable to Rex Energy Common Shareholders	$	(0.37	)	$	0.17
	Diluted — Net Income (Loss) From Continuing Operations	$	(0.38	)	$	0.17
	— Net Income From Discontinued Operations		0.01			0
	— Net Income (Loss) Attributable to Rex Energy Common Shareholders	$	(0.37	)	$	0.17

Condensed_Consolidating_Financ1

Condensed Consolidating Financial Information (Tables)	3 Months Ended
	Mar. 31, 2015
Condensed Financial Information Of Parent Company Only Disclosure [Abstract]
Condensed Consolidating Balance Sheets	REX ENERGY CORPORATION AND SUBSIDIARIES
	CONDENSED CONSOLIDATING BALANCE SHEETS
	AS OF MARCH 31, 2015
	($ in Thousands, Except Share and Per Share Data)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
	ASSETS
	Current Assets
	Cash and Cash Equivalents	$	5,014		$	(55	)	$	5		$	—		$	4,964
	Accounts Receivable		33,289			50			47			—			33,386
	Taxes Receivable		—			—			2			—			2
	Short-Term Derivative Instruments		32,422			—			427			—			32,849
	Assets Held for Sale					54,452						(11,756	)		42,696
	Inventory, Prepaid Expenses and Other		2,662			—			75			—			2,737
	Total Current Assets		73,387			54,447			556			(11,756	)		116,634
	Property and Equipment (Successful Efforts Method)
	Evaluated Oil and Gas Properties		1,153,433			524			—			(6,489	)		1,147,468
	Unevaluated Oil and Gas Properties		334,581			698			—			—			335,279
	Other Property and Equipment		45,837			895			—			—			46,732
	Wells and Facilities in Progress		102,236			428			—			(671	)		101,993
	Pipelines		17,555			—			—			(1,898	)		15,657
	Total Property and Equipment		1,653,642			2,545			—			(9,058	)		1,647,129
	Less: Accumulated Depreciation, Depletion and Amortization		(395,810	)		(798	)		—			1,271			(395,337	)
	Net Property and Equipment		1,257,832			1,747			—			(7,787	)		1,251,792
	Deferred Financing Costs and Other Assets—Net		2,421			—			14,637			—			17,058
	Equity Method Investments		17,692			—			—			—			17,692
	Long-Term Deferred Tax Asset		—			—			8,301			—			8,301
	Intercompany Receivables		—			—			978,279			(978,279	)		—
	Investment in Subsidiaries – Net		(1,909	)		—			249,967			(248,058	)		—
	Long-Term Derivative Instruments		9,732			—			308			—			10,040
	Total Assets	$	1,359,155		$	56,194		$	1,252,048		$	(1,245,880	)	$	1,421,517
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Current Liabilities
	Accounts Payable	$	47,472		$	55		$	—		$	(2,411	)	$	45,116
	Current Maturities of Long-Term Debt		1,056			—			—			—			1,056
	Accrued Liabilities		41,799			274			14,486			—			56,559
	Short-Term Derivative Instruments		1,271			—			122			—			1,393
	Current Deferred Tax Liability		—			—			8,301			—			8,301
	Liabilities Related to Assets Held for Sale		—			31,895			—			(376	)		31,519
	Total Current Liabilities		91,598			32,224			22,909			(2,787	)		143,944
	Long-Term Derivative Instruments		3,237			—			849			—			4,086
	Senior Secured Line of Credit and Other Long-Term Debt		137			—			38,000			—			38,137
	8.875% Senior Notes Due 2020		—			—			350,000			—			350,000
	6.25% Senior Notes Due 2022		—			—			325,000			—			325,000
	Premium on Senior Notes – Net		—			—			2,632			—			2,632
	Other Deposits and Liabilities		3,812			—			—			—			3,812
	Future Abandonment Cost		38,987			53			—			—			39,040
	Intercompany Payables		974,363			3,916			—			(978,279	)		—
	Total Liabilities		1,112,134			36,193			739,390			(981,066	)		906,651
	Stockholders’ Equity
	Preferred Stock		—			—			1			—			1
	Common Stock		—			—			54			—			54
	Additional Paid-In Capital		177,143			15,511			620,782			(192,654	)		620,782
	Accumulated Earnings (Deficit)		69,878			(517	)		(108,179	)		(72,160	)		(110,978	)
	Rex Energy Stockholders’ Equity		247,021			14,994			512,658			(264,814	)		509,859
	Noncontrolling Interests		—			5,007			—			—			5,007
	Total Stockholders’ Equity		247,021			20,001			512,658			(264,814	)		514,866
	Total Liabilities and Stockholders’ Equity	$	1,359,155		$	56,194		$	1,252,048		$	(1,245,880	)	$	1,421,517
	REX ENERGY CORPORATION AND SUBSIDIARIES
	CONDENSED CONSOLIDATING BALANCE SHEETS
	AS OF DECEMBER 31, 2014
	($ in Thousands, Except Share and Per Share Data)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
	ASSETS
	Current Assets
Cash and Cash Equivalents	$	17,978		$	—		$	—		$	—		$	17,978
Accounts Receivable		43,726			210			—			—			43,936
Taxes Receivable		—			—			504			—			504
Short-Term Derivative Instruments		29,265			—			—			—			29,265
Assets Held for Sale		—			36,794			—			(2,537	)		34,257
Inventory, Prepaid Expenses and Other		3,374			—			29			—			3,403
Total Current Assets		94,343			37,004			533			(2,537	)		129,343
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties		1,084,332			467			—			(5,760	)		1,079,039
Unevaluated Oil and Gas Properties		321,708			705			—			—			322,413
Other Property and Equipment		45,466			895			—			—			46,361
Wells and Facilities in Progress		127,759			456			—			(560	)		127,655
Pipelines		17,555			—			—			(1,898	)		15,657
Total Property and Equipment		1,596,820			2,523			—			(8,218	)		1,591,125
Less: Accumulated Depreciation, Depletion and Amortization		(367,224	)		(730	)		—			1,037			(366,917	)
Net Property and Equipment		1,229,596			1,793			—			(7,181	)		1,224,208
Deferred Financing Costs and Other Assets—Net		2,421			—			14,649			—			17,070
Equity Method Investments		17,895			—			—			—			17,895
Long-Term Deferred Tax Asset		—			—			8,301			—			8,301
Intercompany Receivables		—			—			951,025			(951,025	)		—
Investment in Subsidiaries – Net		4,161			1,541			258,448			(264,150	)		—
Long-Term Derivative Instruments		4,904			—			—			—			4,904
Total Assets	$	1,353,320		$	40,338		$	1,232,956		$	(1,224,893	)	$	1,401,721
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current Liabilities
Accounts Payable	$	55,877		$	—		$	—		$	(2,537	)	$	53,340
Current Maturities of Long-Term Debt		1,176			—			—			—			1,176
Accrued Liabilities		46,783			571			12,124			—			59,478
Short-Term Derivative Instruments		421			—			—			—			421
Current Deferred Tax Liability		—			—			8,301			—			8,301
Liabilities Related to Assets Held for Sale		—			25,115			—			—			25,115
Total Current Liabilities		104,257			25,686			20,425			(2,537	)		147,831
Long-Term Derivative Instruments		2,377			—			—			—			2,377
Senior Secured Line of Credit and Other Long-Term Debt		251			—			—			—			251
8.875% Senior Notes Due 2020		—			—			350,000			—			350,000
6.25% Senior Notes Due 2022		—			—			325,000			—			325,000
Premium (Discount) on Senior Notes – Net		—			—			2,725			—			2,725
Other Deposits and Liabilities		4,018			—			—			—			4,018
Future Abandonment Cost		38,097			49			—			—			38,146
Intercompany Payables		947,114			3,911			—			(951,025	)		—
Total Liabilities		1,096,114			29,646			698,150			(953,562	)		870,348
Stockholders’ Equity
Preferred Stock		—			—			1			—			1
Common Stock		—			—			54			—			54
Additional Paid-In Capital		177,144			79,743			617,826			(256,887	)		617,826
Accumulated Earnings (Deficit)		80,062			(69,253	)		(83,075	)		(18,483	)		(90,749	)
Rex Energy Stockholders’ Equity		257,206			10,490			534,806			(275,370	)		527,132
Noncontrolling Interests		—			202			—			4,039			4,241
Total Stockholders’ Equity		257,206			10,692			534,806			(271,331	)		531,373
Total Liabilities and Stockholders’ Equity	$	1,353,320		$	40,338		$	1,232,956		$	(1,224,893	)	$	1,401,721
Condensed Consolidating Statements of Operations	REX ENERGY CORPORATION AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
	FOR THE THREE MONTHS ENDED MARCH 31, 2015
	($ in Thousands)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
	OPERATING REVENUE
	Oil, Natural Gas and NGL Sales	$	54,000		$	111		$	—		$	—		$	54,111
	Other Revenue		11			—			—			—			11
	TOTAL OPERATING REVENUE		54,011			111			—			—			54,122
	OPERATING EXPENSES
	Production and Lease Operating Expense		29,014			38			—			—			29,052
	General and Administrative Expense		6,659			16			2,976			—			9,651
	Loss on Disposal of Asset		65			—			—			—			65
	Impairment Expense		7,012			11			—			—			7,023
	Exploration Expense		518			—			—			—			518
	Depreciation, Depletion, Amortization and Accretion		26,292			69			—			(235	)		26,126
	Other Operating Expense		5,191			—			—			—			5,191
	TOTAL OPERATING EXPENSES		74,751			134			2,976			(235	)		77,626
	INCOME (LOSS) FROM OPERATIONS		(20,740	)		(23	)		(2,976	)		235			(23,504	)
	OTHER INCOME (EXPENSE)
	Interest Expense		(58	)		—			(11,959	)		—			(12,017	)
	Gain on Derivatives, Net		16,856			—			263			—			17,119
	Other Expense		34			—			—			—			34
	Loss From Equity Method Investments		(203	)		—			—			—			(203	)
	Income (Loss) From Equity in Consolidated Subsidiaries		(23	)		23			(3,214	)		3,214			—
	TOTAL OTHER INCOME (EXPENSE)		16,606			23			(14,910	)		3,214			4,933
	INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME		(4,134	)		—			(17,886	)		3,449			(18,571	)
	TAX
	Income Tax Benefit		20			—			72			—			92
	INCOME (LOSS) FROM CONTINUING OPERATIONS		(4,114	)		—			(17,814	)		3,449			(18,479	)
	Income From Discontinued Operations, Net of Income Tax		—			2,826			—			(864	)		1,962
	Net Income (Loss)		(4,114	)		2,826			(17,814	)		2,585			(16,517	)
	Net Income Attributable to Noncontrolling Interests of Discontinued Operations		—			1,297			—			—			1,297
	NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	$	(4,114	)	$	1,529		$	(17,814	)	$	2,585		$	(17,814	)
	REX ENERGY CORPORATION AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS
	FOR THE THREE MONTHS ENDED MARCH 31, 2014
	($ in Thousands)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
	OPERATING REVENUE
	Oil, Natural Gas and NGL Sales	$	81,299		$	—		$	—		$	—		$	81,299
	Other Revenue		44			—			—			—			44
	TOTAL OPERATING REVENUE		81,343			—			—			—			81,343
	OPERATING EXPENSES
	Production and Lease Operating Expense		20,030			3			—			—			20,033
	General and Administrative Expense		7,880			23			1,659			—			9,562
	Loss on Disposal of Asset		72			—			—			—			72
	Impairment Expense		25			—			—			—			25
	Exploration Expense		2,060			—			—			—			2,060
	Depreciation, Depletion, Amortization and Accretion		19,823			11			—			(111	)		19,723
	Other Operating Expense		83			—			—			—			83
	TOTAL OPERATING EXPENSES		49,973			37			1,659			(111	)		51,558
	INCOME (LOSS) FROM OPERATIONS		31,370			(37	)		(1,659	)		111			29,785
	OTHER INCOME (EXPENSE)
	Interest Expense		(15	)		—			(6,918	)		—			(6,933	)
	Gain (Loss) on Derivatives, Net		(10,439	)		—			689			—			(9,750	)
	Other Expense		(37	)		—			—			—			(37	)
	Loss From Equity Method Investments		(200	)		—			—			—			(200	)
	Income (Loss) From Equity in Consolidated Subsidiaries		(25	)		25			13,567			(13,567	)		—
	TOTAL OTHER INCOME (EXPENSE)		(10,716	)		25			7,338			(13,567	)		(16,920	)
	INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE		20,654			(12	)		5,679			(13,456	)		12,865
	INCOME TAX
	Income Tax (Expense) Benefit		(6,637	)		(662	)		3,189			—			(4,110	)
	INCOME (LOSS) FROM CONTINUING OPERATIONS		14,017			(674	)		8,868			(13,456	)		8,755
Loss From Discontinued Operations, Net of Income Tax		—			3,840			—			(2,158	)		1,682
Net Income (Loss)		14,017			3,166			8,868			(15,614	)		10,437
Net Income Attributable to Noncontrolling Interests of Discontinued Operations		—			1,569			—			—			1,569
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	$	14,017		$	1,597		$	8,868		$	(15,614	)	$	8,868
Preferred Stock Dividends		—			—			—			—			—
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	$	14,017		$	1,597		$	8,868		$	(15,614	)	$	8,868
Condensed Consolidating Statements of Cash Flows	REX ENERGY CORPORATION AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
	FOR THE THREE MONTHS ENDING MARCH 31, 2015
	($ in Thousands)
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
	CASH FLOWS FROM OPERATING ACTIVITIES
	Net Income (Loss)	$	(4,114	)	$	2,826		$	(17,814	)	$	2,585		$	(16,517	)
	Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating
	Activities
	Loss From Equity Method Investments		203			—			—			—			203
	Non-Cash Expenses (Income)		(70	)		44			3,403			—			3,377
	Depreciation, Depletion, Amortization and Accretion		26,292			1,480			—			(1,607	)		26,165
	Gain on Derivatives		(16,856	)		—			(263	)		—			(17,119	)
	Cash Settlements of Derivatives		10,579			—			500			—			11,079
	Dry Hole Expense		(1	)		—			—			—			(1	)
	(Gain) Loss on Sale of Asset		65			(32	)		—			—			33
	Impairment Expense		7,012			11			—			—			7,023
	Changes in operating assets and liabilities
	Accounts Receivable		10,437			(1,087	)		428			251			10,029
	Inventory, Prepaid Expenses and Other Assets		712			(322	)		(62	)		—			328
	Accounts Payable and Accrued Liabilities		(12,518	)		(2,496	)		2,336			(251	)		(12,929	)
	Other Assets and Liabilities		(199	)		(133	)		27			—			(305	)
	NET CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES		21,542			291			(11,445	)		978			11,366
	CASH FLOWS FROM INVESTING ACTIVITIES
	Intercompany loans to subsidiaries		27,192			(1,688	)		(23,681	)		(1,823	)		—
	Proceeds from Joint Venture Acreage Management		39			—			—			—			39
	Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets		217			455			—			—			672
	Proceeds from Joint Venture		16,611			—			—			—			16,611
	Acquisitions of Undeveloped Acreage		(17,454	)		(5	)		—			—			(17,459	)
	Capital Expenditures for Development of Oil and Gas Properties and Equipment		(60,719	)		(7,139	)		—			845			(67,013	)
	NET CASH USED IN INVESTING ACTIVITIES		(34,114	)		(8,377	)		(23,681	)		(978	)		(67,150	)
	CASH FLOWS FROM FINANCING ACTIVITIES
	Proceeds from Long-Term Debt and Lines of Credit		—			18,826			54,000			—			72,826
	Repayments of Long-Term Debt and Lines of Credit		—			(9,761	)		(16,000	)		—			(25,761	)
	Repayments of Loans and Other Long-Term Debt		(392	)		(294	)		—			—			(686	)
	Debt Issuance Costs		—			—			(459	)		—			(459	)
	Dividends Paid		—			—			(2,415	)		—			(2,415	)
	Distributions by the Partners of Consolidated Subsidiaries		—			(531	)		—			—			(531	)
	NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES		(392	)		8,240			35,126			—			42,974
	NET INCREASE (DECREASE) IN CASH		(12,964	)		154			—			—			(12,810	)
	CASH – BEGINNING		17,978			113			5			—			18,096
	CASH - ENDING	$	5,014		$	267		$	5		$	—		$	5,286
	REX ENERGY CORPORATION AND SUBSIDIARIES
	CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS
	FOR THE THREE MONTHS ENDING MARCH 31, 2014
		Guarantor Subsidiaries			Non-Guarantor Subsidiaries			Rex Energy Corporation (Note Issuer)			Eliminations			Consolidated Balance
	CASH FLOWS FROM OPERATING ACTIVITIES
	Net Income (Loss)	$	14,017		$	3,166		$	8,868		$	(15,614	)	$	10,437
	Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by
	Operating Activities
	Loss From Equity Method Investments		200			—			—			—			200
	Non-Cash Expenses		(63	)		139			1,922			—			1,998
	Depreciation, Depletion, Amortization and Accretion		19,823			712			—			(111	)		20,424
	Deferred Income Tax Expense (Benefit)		6,597			743			(3,189	)		—			4,151
	Gain on Derivatives		10,439			—			(689	)		—			9,750
	Cash Settlements of Derivatives		(5,245	)		—			368			—			(4,877	)
	Dry Hole Expense		86			—			—			—			86
	(Gain) Loss on Sale of Asset		71			—			—			—			71
	Impairment Expense		25			—			—			—			25
	Changes in operating assets and liabilities
	Accounts Receivable		(8,921	)		(10,439	)		(50	)		3,489			(15,921	)
	Inventory, Prepaid Expenses and Other Assets		31			14			(189	)		—			(144	)
	Accounts Payable and Accrued Liabilities		(16,986	)		2,878			7,805			(3,489	)		(9,792	)
	Other Assets and Liabilities		(307	)		—			(41	)		—			(348	)
NET CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES		19,767			(2,787	)		14,805			(15,725	)		16,060
CASH FLOWS FROM INVESTING ACTIVITIES
Intercompany loans to subsidiaries		62,160			(175	)		(75,553	)		13,568			—
Proceeds from Joint Venture Acreage Management		67			—			—			—			67
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets		15			—			—			—			15
Acquisitions of Undeveloped Acreage		(15,077	)		(457	)		—			—			(15,534	)
Capital Expenditures for Development of Oil and Gas Properties and Equipment		(66,618	)		(2,020	)		—			2,157			(66,481	)
NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES		(19,453	)		(2,652	)		(75,553	)		15,725			(81,933	)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from Long-Term Debt and Lines of Credit		—			5,922			61,000			—			66,922
Repayments of Long-Term Debt and Lines of Credit		—			(19	)		—			—			(19	)
Repayments of Loans and Other Notes Payable		(399	)		(129	)		—			—			(528	)
Debt Issuance Costs		—			—			(252	)		—			(252	)
Distributions by the Partners of Consolidated Subsidiaries		—			(360	)		—			—			(360	)
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES		(399	)		5,414			60,748			—			65,763
NET INCREASE (DECREASE) IN CASH		(85	)		(25	)		—			—			(110	)
CASH – BEGINNING		1,386			509			5			—			1,900
CASH - ENDING	$	1,301		$	484		$	5		$	—		$	1,790

Basis_of_Presentation_and_Prin1

Basis of Presentation and Principles of Consolidation - Additional Information (Details) (Water Solutions Holdings, LLC)	Dec. 31, 2014
Water Solutions Holdings, LLC
Organization Consolidation And Presentation Of Financial Statements [Line Items]
Ownership percentage by parent	60.00%

Future_Abandonment_Cost_Additi

Future Abandonment Cost - Additional Information (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Accretion expense	$921	$800

Future_Abandonment_Cost_Detail

Future Abandonment Cost (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015		Mar. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Beginning Balance at January 1, 2015	$40,099
Future Abandonment Obligation Incurred	249
Future Abandonment Obligation Settled	-266
Future Abandonment Obligation Cancelled or Sold	-34
Future Abandonment Obligation Revision of Estimated Obligation	-2
Future Abandonment Obligation Accretion Expense	921		800
Total Future Abandonment Cost	$40,967	[1]
[1]	Includes approximately $1.9 million of short-term future abandonment costs, which are classified as Accrued Liabilities on our Consolidated Balance Sheet.

Future_Abandonment_Cost_Parent

Future Abandonment Cost (Parenthetical) (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Asset Retirement Obligations [Line Items]
Accrued Liabilities	$56,559	$59,478
Remediation Property for Sale, Abandonment or Disposal
Asset Retirement Obligations [Line Items]
Accrued Liabilities	$1,900

Discontinued_Operations_Assets

Discontinued Operations/ Assets Held for Sale - Additional Information (Details) (Water Solutions Holdings, LLC)	Dec. 31, 2014
Water Solutions Holdings, LLC
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Ownership percentage by parent	60.00%

Summary_of_Carrying_Value_of_A

Summary of Carrying Value of Assets and Liabilities (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014
In Thousands, unless otherwise specified
Assets:
Cash and Cash Equivalents	$322		$667
Total Current Assets	42,696	34,257
Liabilities:
Total Liabilities Related to Assets Held for Sale	31,519	25,115
Water Solutions Holdings, LLC
Assets:
Cash and Cash Equivalents	322	118
Accounts Receivable	14,223	13,226
Inventory, Prepaid Expenses and Other	484	163
Total Current Assets	15,029	13,507
Other Property and Equipment, Net	26,681	19,690
Wells and Facilities in Progress	628	688
Intangible Assets, Net	358	372
Total Long-Term Assets	27,667	20,750
Total Assets Held for Sale	42,696	34,257
Liabilities:
Accounts Payable	3,475	3,694
Current Maturities of Long-Term Debt	14,344	6,236
Accrued Liabilities	3,892	6,304
Total Current Liabilities	21,711	16,234
Senior Secured Line of Credit and Long-Term Debt	9,808	8,881
Total Long-Term Liabilities	9,808	8,881
Total Liabilities Related to Assets Held for Sale	31,519	25,115
Net Assets Held for Sale	$11,177	$9,142

Summary_of_Financial_Informati

Summary of Financial Information for Discontinued Operations (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Revenues:
Total Operating Revenue	$54,122	$81,343
Costs and Expenses:
General and Administrative Expense	9,651	9,562
Depreciation, Depletion, Amortization and Accretion	26,126	19,723
Gain on Sale of Asset	65	72
Interest Expense	12,017	6,933
Other Expense	-34	37
Income from Discontinued Operations, net of taxes	1,962	1,682
Discontinued Operations Assets Held For Sale | Water Solutions Holdings, LLC
Revenues:
Field Services Revenue	14,964	15,304
Total Operating Revenue	14,964	15,304
Costs and Expenses:
General and Administrative Expense	977	830
Depreciation, Depletion, Amortization and Accretion	39	701
Field Services Operating Expense	11,289	11,796
Gain on Sale of Asset	-32
Interest Expense	191	202
Other Expense	103	11
Total Costs and Expenses	12,567	13,540
Income from Discontinued Operations Before Income Taxes	2,397	1,764
Income Tax Expense	-435	-82
Income from Discontinued Operations, net of taxes	$1,962	$1,682

Business_and_Oil_and_Gas_Prope1

Business and Oil and Gas Property Acquisitions and Dispositions - Additional Information (Details) (USD $)	3 Months Ended	0 Months Ended
	Mar. 31, 2015	Mar. 31, 2015
Significant Acquisitions And Disposals [Line Items]
Total consideration for the transaction	($16,611,000)
ArcLight Capital Partners, LLC
Significant Acquisitions And Disposals [Line Items]
Percentage of estimated well costs		35.00%
Total consideration for the transaction		67,000,000
Amount received at closing of wells		$16,600,000
Percentage of working interest		50.00%
Percentage of working interest attained through return on investment and internal rate of return		35.00%
Percentage of remaining working interest		17.50%
ArcLight Capital Partners, LLC | Butler County, Pennsylvania
Significant Acquisitions And Disposals [Line Items]
Number of specifically designated wells for development		32

Recently_Issued_Accounting_Pro2

Recently Issued Accounting Pronouncements - Additional Information (Details) (USD $)	Mar. 31, 2015
In Millions, unless otherwise specified
Accounting Policies [Abstract]
Net deferred financing costs	$14.60

Concentrations_of_Credit_Risk_

Concentrations of Credit Risk - Additional Information (Details) (Sales, Customer Concentration Risk)	3 Months Ended
	Mar. 31, 2015
	Customer
Purchaser
Concentration Risk [Line Items]
Percentage of revenue from major customers	92.70%
Number of major customers	5
Largest single purchaser
Concentration Risk [Line Items]
Percentage of revenue from major customers	45.20%

Long_Term_Debt_Senior_Credit_F

Long Term Debt - Senior Credit Facility - Additional Information (Details) (USD $)	3 Months Ended
	Mar. 31, 2015		Dec. 31, 2014
Debt Instrument [Line Items]
Line of credit facility, amount outstanding	$38,000,000	[1]	$0
Senior Credit Facility
Debt Instrument [Line Items]
Line of credit facility, current borrowing capacity	350,000,000
Line of credit facility, maturity date	12-Sep-19
Current ratio	2.70%
Net senior secured to EBITAX	0.40%
Senior Credit Facility | Minimum
Debt Instrument [Line Items]
Criteria Current ratio	1.00%
Senior Credit Facility | Maximum
Debt Instrument [Line Items]
Criteria Total debt to EBITAX"	3.00%
Senior Credit Facility | Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	500,000,000
Senior Credit Facility | Letter of Credit
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	$60,000,000
Prior to redetermination | Maximum
Debt Instrument [Line Items]
Criteria Total debt to EBITAX"	1.75%
[1]	The Senior Credit Facility requires us to make monthly payments of interest on the outstanding balance of loans made under the agreement. The weighted average interest rate on borrowings under our Senior Credit Facility for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 4.2% and 4.0%, respectively.

LongTerm_Debt_Senior_Notes_Due

Long-Term Debt - Senior Notes Due Twenty Twenty and Senior Notes Due Twenty Twenty Two - Additional Information (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Premium on Senior Notes, Net	$2,632,000	$2,725,000
Amortization of net premium	100,000
8.875% Senior Notes
Debt Instrument [Line Items]
Senior notes	350,000,000
Interest rate	8.88%	8.88%
6.25% Senior Notes
Debt Instrument [Line Items]
Senior notes		$325,000,000
Interest rate	6.25%	6.25%

Components_of_LongTerm_Debt_an

Components of Long-Term Debt and Lines of Credit (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
Debt Instrument [Line Items]
Senior Notes	$675,000,000
Premium on Senior Notes, Net	2,632,000		2,725,000
Senior Line of Credit	38,000,000	[1]	0
Capital Leases and Other Obligations	1,193,000	[1]	1,427,000	[1]
Total Debt	716,825,000		679,152,000
Less Current Portion of Long-Term Debt	-1,056,000		-1,176,000
Total Long-Term Debt	715,769,000		677,976,000
8.875% Senior Notes
Debt Instrument [Line Items]
Senior Notes	350,000,000		350,000,000
6.25% Senior Notes
Debt Instrument [Line Items]
Senior Notes	$325,000,000		$325,000,000
[1]	The Senior Credit Facility requires us to make monthly payments of interest on the outstanding balance of loans made under the agreement. The weighted average interest rate on borrowings under our Senior Credit Facility for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 4.2% and 4.0%, respectively.

Components_of_LongTerm_Debt_an1

Components of Long-Term Debt and Lines of Credit (Parenthetical) (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Senior Credit Facility
Debt Instrument [Line Items]
Average interest rate	1.70%	2.20%
Other Loans and Notes Payable
Debt Instrument [Line Items]
Average interest rate	4.20%	4.00%
8.875% Senior Notes
Debt Instrument [Line Items]
Interest rate	8.88%	8.88%
Debt instrument maturity date	1-Dec-20	1-Dec-20
6.25% Senior Notes
Debt Instrument [Line Items]
Interest rate	6.25%	6.25%
Debt instrument maturity date	1-Aug-22	1-Aug-22

Principal_Maturity_Schedule_fo

Principal Maturity Schedule for Debt Outstanding (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
In Thousands, unless otherwise specified
Debt Disclosure [Abstract]
2015	$868
2016	325
2019	38,000
Thereafter	675,000
Total	$714,193	[1]	$676,427
[1]	Excludes $2.6 million net premium on Senior Notes

Principal_Maturity_Schedule_fo1

Principal Maturity Schedule for Debt Outstanding (Parenthetical) (Details) (USD $)	Mar. 31, 2015
In Millions, unless otherwise specified
Debt Disclosure [Abstract]
Senior notes, net premium	$2.60

Recovered_Sheet2

Fair Value of Financial and Derivative Instruments - Additional Information (Details) (USD $)	3 Months Ended
	Mar. 31, 2015		Mar. 31, 2014	Jun. 30, 2014	Dec. 31, 2014
Derivatives Fair Value [Line Items]
Cash Settlements of Derivatives	($11,079,000)		$4,877,000
Senior Line of Credit	38,000,000	[1]			0
Senior Notes	675,000,000
Fair value of interest rate swap, net liability	200,000
Derivatives asset (liability)	37,400,000				31,400,000
Unrealized loss on commodity derivative contracts	-2,000,000		-2,400,000
Impairment Expense	7,023,000		25,000
Other Than Temporary Impairment
Derivatives Fair Value [Line Items]
Impairment Expense	7,000,000
Crude Oil
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	6,369,000
Crude Oil | Minimum
Derivatives Fair Value [Line Items]
Commodity hedged on annualized basis hedge through 2015	75.00%
Natural Gas
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	26,280,000
Natural Gas | Minimum
Derivatives Fair Value [Line Items]
Commodity hedged on annualized basis hedge through 2015	95.00%
Commodity hedged on annualized basis hedge through 2016	40.00%
Natural Gas Liquids
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	5,053,000
Natural Gas Liquids | Minimum
Derivatives Fair Value [Line Items]
Commodity hedged on annualized basis hedge through 2015	35.00%
Commodity derivatives
Derivatives Fair Value [Line Items]
Cash Settlements of Derivatives	-10,600,000		5,200,000
Derivatives asset (liability)	37,647,000				31,371,000
Fixed To Floating Interest Rate Swap
Derivatives Fair Value [Line Items]
Derivative, amount of hedged item	40,000,000
Fixed-To-Variable Interest Rate Swaptions
Derivatives Fair Value [Line Items]
Derivative, amount of hedged item	120,000,000
Interest Rate Swap
Derivatives Fair Value [Line Items]
Proceeds from interest rate swaps				600,000
Derivatives asset (liability)	-114,000
Interest Rate Swaption
Derivatives Fair Value [Line Items]
Cash Settlements of Derivatives	500,000
Derivatives asset (liability)	($123,000)
[1]	The Senior Credit Facility requires us to make monthly payments of interest on the outstanding balance of loans made under the agreement. The weighted average interest rate on borrowings under our Senior Credit Facility for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 4.2% and 4.0%, respectively.

Schedule_of_Location_and_Amoun

Schedule of Location and Amounts of Gains and Losses on Derivative Instruments (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) on Derivatives, Net	$17,119	($9,750)
Crude Oil
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) on Derivatives, Net	2,876	-1,168
Natural Gas
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) on Derivatives, Net	13,600	-8,928
Natural Gas Liquids
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) on Derivatives, Net	435	-343
Interest Rate Swap
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) on Derivatives, Net	263	689
Refined Products
Derivative Instruments Gain Loss [Line Items]
Gain (Loss) on Derivatives, Net	($55)

Asset_or_Liability_Financial_C

Asset or Liability Financial Commodity Derivative Instrument Positions (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
	bbl
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	$37,400	$31,400
Crude Oil
Derivatives Fair Value [Line Items]
Volume	915,000
Derivatives asset (liability)	6,369
Crude Oil | 2015 | Deferred Put Spreads
Derivatives Fair Value [Line Items]
Volume	90,000
Put Option	73.08
Floor	83.33
Derivatives asset (liability)	739
Crude Oil | 2015 | Collars
Derivatives Fair Value [Line Items]
Volume	180,000
Floor	52.58
Ceiling	62.89
Derivatives asset (liability)	480
Crude Oil | 2015 | Call Protected Swaps
Derivatives Fair Value [Line Items]
Volume	15,000
Swap	95.76
Long Call	110
Derivatives asset (liability)	691
Crude Oil | 2015 | Three Way Collars
Derivatives Fair Value [Line Items]
Volume	450,000
Put Option	50
Floor	65
Ceiling	72.5
Derivatives asset (liability)	4,232
Crude Oil | 2016 | Deferred Put Spreads
Derivatives Fair Value [Line Items]
Volume	120,000
Put Option	50
Floor	65
Derivatives asset (liability)	83
Crude Oil | 2016 | Collars
Derivatives Fair Value [Line Items]
Volume	60,000
Floor	53.75
Ceiling	63.81
Derivatives asset (liability)	144
Natural Gas
Derivatives Fair Value [Line Items]
Volume	158,235,000
Derivatives asset (liability)	26,280
Natural Gas | Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	139	1,341
Natural Gas | Basis Swaps Texas Gas
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	-344
Natural Gas | 2015 | Three Way Collars
Derivatives Fair Value [Line Items]
Volume	3,400,000
Put Option	2.64
Floor	3.32
Ceiling	3.88
Derivatives asset (liability)	769
Natural Gas | 2015 | Swaps
Derivatives Fair Value [Line Items]
Volume	17,275,000
Swap	3.38
Derivatives asset (liability)	10,563
Natural Gas | 2015 | Swaptions
Derivatives Fair Value [Line Items]
Volume	2,650,000
Swap	3.54
Derivatives asset (liability)	1,700
Natural Gas | 2015 | Cap Swaps
Derivatives Fair Value [Line Items]
Volume	5,850,000
Put Option	3.43
Swap	4.12
Derivatives asset (liability)	3,026
Natural Gas | 2015 | Put Spreads
Derivatives Fair Value [Line Items]
Volume	4,550,000
Put Option	2.56
Floor	3.32
Derivatives asset (liability)	1,873
Natural Gas | 2015 | Calls Option
Derivatives Fair Value [Line Items]
Volume	2,850,000
Ceiling	3.94
Derivatives asset (liability)	-99
Natural Gas | 2015 | Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume	9,780,000
Swap	-0.79
Derivatives asset (liability)	1,174
Natural Gas | 2016 | Collars
Derivatives Fair Value [Line Items]
Volume	900,000
Floor	3.2
Ceiling	4.04
Derivatives asset (liability)	223
Natural Gas | 2016 | Three Way Collars
Derivatives Fair Value [Line Items]
Volume	8,850,000
Put Option	2.66
Floor	3.42
Ceiling	4.29
Derivatives asset (liability)	1,845
Natural Gas | 2016 | Swaps
Derivatives Fair Value [Line Items]
Volume	6,630,000
Swap	3.69
Derivatives asset (liability)	3,679
Natural Gas | 2016 | Swaptions
Derivatives Fair Value [Line Items]
Volume	0
Derivatives asset (liability)	-692
Natural Gas | 2016 | Cap Swaps
Derivatives Fair Value [Line Items]
Volume	3,600,000
Put Option	3.45
Swap	4.11
Derivatives asset (liability)	1,454
Natural Gas | 2016 | Put Spreads
Derivatives Fair Value [Line Items]
Volume	2,100,000
Put Option	2.25
Floor	3
Derivatives asset (liability)	-18
Natural Gas | 2016 | Calls Option
Derivatives Fair Value [Line Items]
Volume	9,120,000
Ceiling	4.23
Derivatives asset (liability)	-988
Natural Gas | 2016 | Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume	7,320,000
Swap	-0.83
Derivatives asset (liability)	-207
Natural Gas | 2017 | Three Way Collars
Derivatives Fair Value [Line Items]
Volume	6,600,000
Put Option	2.37
Floor	3.19
Ceiling	4.26
Derivatives asset (liability)	1,089
Natural Gas | 2017 | Swaps
Derivatives Fair Value [Line Items]
Volume	1,800,000
Swap	3.64
Derivatives asset (liability)	577
Natural Gas | 2017 | Cap Swaps
Derivatives Fair Value [Line Items]
Volume	2,100,000
Put Option	3.34
Swap	4.07
Derivatives asset (liability)	811
Natural Gas | 2017 | Calls Option
Derivatives Fair Value [Line Items]
Volume	1,440,000
Ceiling	3.9
Derivatives asset (liability)	-283
Natural Gas | 2017 | Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume	7,300,000
Swap	-0.83
Derivatives asset (liability)	-207
Natural Gas | 2017 | Basis Swaps Texas Gas
Derivatives Fair Value [Line Items]
Volume	14,600,000
Swap	-0.13
Derivatives asset (liability)	-172
Natural Gas | 2018 | Swaps
Derivatives Fair Value [Line Items]
Volume	1,200,000
Swap	3.61
Derivatives asset (liability)	273
Natural Gas | 2018 | Cap Swaps
Derivatives Fair Value [Line Items]
Volume	1,800,000
Put Option	3.3
Swap	4.05
Derivatives asset (liability)	683
Natural Gas | 2018 | Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume	7,300,000
Swap	-0.83
Derivatives asset (liability)	-207
Natural Gas | 2018 | Basis Swaps Texas Gas
Derivatives Fair Value [Line Items]
Volume	14,600,000
Swap	-0.13
Derivatives asset (liability)	-172
Natural Gas | 2019 | Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume	7,300,000
Swap	-0.83
Derivatives asset (liability)	-207
Natural Gas | 2020 | Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume	7,320,000
Swap	-0.83
Derivatives asset (liability)	-207
Natural Gas Liquids
Derivatives Fair Value [Line Items]
Volume	1,504,500
Derivatives asset (liability)	5,053
Natural Gas Liquids | 2015 | C3+ NGL Swaps
Derivatives Fair Value [Line Items]
Volume	732,000
Swap	32.9
Derivatives asset (liability)	3,934
Natural Gas Liquids | 2015 | Ethane Swaps
Derivatives Fair Value [Line Items]
Volume	277,500
Swap	8.5
Derivatives asset (liability)	234
Natural Gas Liquids | 2016 | C3+ NGL Swaps
Derivatives Fair Value [Line Items]
Volume	375,000
Swap	31.08
Derivatives asset (liability)	887
Natural Gas Liquids | 2016 | Ethane Swaps
Derivatives Fair Value [Line Items]
Volume	120,000
Swap	8.09
Derivatives asset (liability)	-2
Refined Product (Heating Oil)
Derivatives Fair Value [Line Items]
Volume	12,000
Derivatives asset (liability)	-55
Refined Product (Heating Oil) | 2016 | Swaps
Derivatives Fair Value [Line Items]
Volume	12,000
Swap	42
Derivatives asset (liability)	($55)

Combined_Fair_Value_of_Derivat

Combined Fair Value of Derivatives (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	$32,849	$29,265
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	10,040	4,904
Total Derivative Assets	42,889	34,169
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	-1,393	-421
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	-4,086	-2,377
Total Derivative Liabilities	-5,479	-2,798
Interest Rate Swap
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	427
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	308
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	-123
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	-849
Crude Oil | Collars
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	552
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	72
Crude Oil | Deferred Put Spreads
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	760	1,413
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	62
Crude Oil | Call Protected Swaps
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	691	1,227
Crude Oil | Three Way Collars
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	4,232	4,596
Natural Gas Liquids | Swaps
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	5,008	6,181
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	838
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	-791
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	-2
Natural Gas | Collars
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	223
Natural Gas | Three Way Collars
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	1,263	5,081
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	2,440	1,733
Natural Gas | Swaps
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	11,232	4,522
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	3,890	1,554
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	-30
Natural Gas | Cap Swaps
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	3,585	3,430
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	2,389	1,617
Natural Gas | Basis Swaps
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	1,329	2,815
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	41
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	-207	-193
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	-1,368	-1,281
Natural Gas | Swaptions
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	1,755
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	-55	-154
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	-692
Natural Gas | Calls Option
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	-80
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	-174	-74
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	-1,116	-1,096
Natural Gas | Put Spreads
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	1,872
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	-17
Refined Product (Heating Oil) | Swaps
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	-13
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	($42)

Significant_Unobservable_Input

Significant Unobservable Inputs Used in Fair Value Measurements of Natural Gas Basis Swaps (Details) (USD $)	3 Months Ended	12 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Dec. 31, 2014
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Derivatives asset (liability)	$37,400	$31,400
Natural Gas
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Derivatives asset (liability)	26,280
Natural Gas | Basis Swaps Dominion South
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Weighted Average (price per Mcf)	-0.82	-0.84
Derivatives asset (liability)	139	1,341
Natural Gas | Basis Swaps Dominion South | Minimum
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range (price per Mcf)	-0.38	-0.27
Natural Gas | Basis Swaps Dominion South | Maximum
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range (price per Mcf)	-1.23	-1.39
Natural Gas | Basis Swaps Texas Gas
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Weighted Average (price per Mcf)	-0.11
Derivatives asset (liability)	($344)
Natural Gas | Basis Swaps Texas Gas | Minimum
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range (price per Mcf)	-0.1
Natural Gas | Basis Swaps Texas Gas | Maximum
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range (price per Mcf)	-0.13

Fair_Value_Hierarchy_Table_for

Fair Value Hierarchy Table for Assets and Liabilities Measured at Fair Value (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014
In Thousands, unless otherwise specified
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivatives asset (liability)	$37,400	$31,400
Commodity derivatives
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivatives asset (liability)	37,647	31,371
Commodity derivatives | Significant Other Observable Inputs (Level 2)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivatives asset (liability)	37,852	30,030
Commodity derivatives | Significant Unobservable Inputs (Level 3)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivatives asset (liability)	-205	1,341
Interest Rate Swap
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivatives asset (liability)	-114
Interest Rate Swap | Significant Other Observable Inputs (Level 2)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivatives asset (liability)	-114
Interest Rate Swaption
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivatives asset (liability)	-123
Interest Rate Swaption | Significant Other Observable Inputs (Level 2)
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivatives asset (liability)	($123)

Reconciliation_of_Commodity_De

Reconciliation of Commodity Derivative Contracts Measured at Fair Value on Recurring Basis Using Significant Unobservable Inputs (Level 3) (Details) (Commodity derivatives, USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Commodity derivatives
Fair Value Net Derivative Asset Liability Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Beginning Balance of Level 3	$1,341	$4,323
Changes in Fair Value	-1,955	-2,356
Settlements Received	409	284
Ending Balance of Level 3	($205)	$2,251

Financial_Instruments_Not_Reco

Financial Instruments Not Recorded at Fair Value (Details) (USD $)	Mar. 31, 2015		Dec. 31, 2014
Derivatives Fair Value [Line Items]
Senior Notes	$675,000,000
Senior Line of Credit	38,000,000	[1]	0
Capital Leases and Other Obligations	1,193,000	[1]	1,427,000	[1]
Total	714,193,000	[2]	676,427,000
Fair Value
Derivatives Fair Value [Line Items]
Secured Lines of Credit	38,000,000
Capital Leases and Other Obligations	1,167,000		1,393,000
Total	526,027,000		554,661,000
8.875% Senior Notes
Derivatives Fair Value [Line Items]
Senior Notes	350,000,000		350,000,000
8.875% Senior Notes | Fair Value
Derivatives Fair Value [Line Items]
Senior Notes	269,500,000		311,955,000
6.25% Senior Notes
Derivatives Fair Value [Line Items]
Senior Notes	325,000,000		325,000,000
6.25% Senior Notes | Fair Value
Derivatives Fair Value [Line Items]
Senior Notes	$217,360,000		$241,313,000
[1]	The Senior Credit Facility requires us to make monthly payments of interest on the outstanding balance of loans made under the agreement. The weighted average interest rate on borrowings under our Senior Credit Facility for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three months ended March 31, 2015 and the year ended December 31, 2014, was approximately 4.2% and 4.0%, respectively.
[2]	Excludes $2.6 million net premium on Senior Notes

Financial_Instruments_Not_Reco1

Financial Instruments Not Recorded at Fair Value (Parenthetical) (Detail)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
8.875% Senior Notes
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	8.88%	8.88%
Due date	2020	2020
8.875% Senior Notes | Carrying Amount
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	8.88%	8.88%
Due date	2020	2020
8.875% Senior Notes | Fair Value
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	8.88%	8.88%
Due date	2020	2020
6.25% Senior Notes
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	6.25%	6.25%
Due date	2022	2022
6.25% Senior Notes | Carrying Amount
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	6.25%	6.25%
Due date	2022	2022
6.25% Senior Notes | Fair Value
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	6.25%	6.25%
Due date	2022	2022

Schedule_of_Income_Tax_Include

Schedule of Income Tax Included in Continuing Operations (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Income Tax Disclosure [Abstract]
Income Tax (Expense) Benefit	$92	($4,110)
Effective Tax Rate	0.50%	31.90%

Income_Taxes_Additional_Inform

Income Taxes - Additional Information (Details) (USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Income Tax Disclosure [Abstract]
Statutory rate	35.00%	35.00%
Income tax refunds	$0.50

Capital_Stock_Additional_Infor

Capital Stock - Additional Information (Details) (USD $)	3 Months Ended	0 Months Ended	1 Months Ended
	Mar. 31, 2015	Aug. 18, 2014	Feb. 28, 2015	Dec. 31, 2014
Schedule Of Capitalization Equity [Line Items]
Common stock, shares authorized	100,000,000			100,000,000
Preferred Stock, shares authorized	100,000			100,000
Common Stock, shares issued	55,266,519			54,174,763
Common Stock, shares outstanding	55,266,519			54,174,763
Preferred Stock, shares issued	16,100			16,100
Preferred Stock, par value	$0.00			$0.00
Dividend declared, per preferred share	$150
Dividends declared on preferred stock	$2,415,000
6.0% convertible perpetual preferred stock, Series A
Schedule Of Capitalization Equity [Line Items]
Preferred Stock, shares issued		16,100
Preferred Stock, par value		$0.00
Proceeds from the Issuance of Preferred Stock, Net		155,000,000
Dividend per share in amount	$600
Dividend per share percentage	6.00%
Dividend declared, per preferred share			$150
Dividends declared on preferred stock	$2,400,000
Depositary shares
Schedule Of Capitalization Equity [Line Items]
Preferred Stock, shares issued		1,610,000
Liquidation preference per share	$10,000

Employee_Benefit_and_Equity_Pl1

Employee Benefit and Equity Plans - Additional Information (Details) (USD $)	3 Months Ended		12 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of option issued to purchase common stock	80,000	0
Stock options exercised	0	0
Total tax benefit	$0	$0
Outstanding weighted average remaining term (in years)	3 years 3 months 18 days
Weighted average remaining term of options exercisable (in years)	2 years 7 months 6 days
Aggregate intrinsic value of options outstanding	0
Aggregate intrinsic value of options exercisable	0
Unrecognized compensation expense	100,000
Restricted Stock or Unit Expense	2,500,000
Employee Stock Options
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of employees	3
Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Unrecognized compensation expense	6,700,000
Common stock issued by compensation committee	1,336,295	3,315
Number of employees subjected to issuance of common stock	126	3
Fair value of TSR awards of per share estimated on date of grant	$4.04
Share-based compensation	$3,000,000	$1,600,000
Unrecognized compensation expense weighted average period, in years	1 year 10 months 24 days
Vested stock	202,492
Restricted Stock | TSR
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Fair value of TSR awards of per share estimated on date of grant	$2.56		$10.15
Restricted Stock | Certain Performance Factors Waived
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vested stock	189,872

Summary_of_Issued_and_Outstand

Summary of Issued and Outstanding Stock Options (Details) (USD $)	Mar. 31, 2015
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Number Outstanding	482,561
Weighted-Average Exercise Price, Outstanding	$9.77
Number Exercisable	402,561
Weighted-Average Exercise Price, Exercisable	$10.82
Exercise Price Range 4.05
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Exercise Price	$4.05
Number Outstanding	40,000
Weighted-Average Exercise Price, Outstanding	$4.05
Exercise Price Range 4.90
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Exercise Price	$4.90
Number Outstanding	40,000
Weighted-Average Exercise Price, Outstanding	$4.90
Exercise Price Range 5.04
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Exercise Price	$5.04
Number Outstanding	46,041
Weighted-Average Exercise Price, Outstanding	$5.04
Number Exercisable	46,041
Weighted-Average Exercise Price, Exercisable	$5.04
Exercise Price Range 9.50
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Exercise Price	$9.50
Number Outstanding	75,000
Weighted-Average Exercise Price, Outstanding	$9.50
Number Exercisable	75,000
Weighted-Average Exercise Price, Exercisable	$9.50
Exercise Price Range 9.99
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Exercise Price	$9.99
Number Outstanding	149,333
Weighted-Average Exercise Price, Outstanding	$9.99
Number Exercisable	149,333
Weighted-Average Exercise Price, Exercisable	$9.99
Exercise Price Range 10.42
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Exercise Price	$10.42
Number Outstanding	29,548
Weighted-Average Exercise Price, Outstanding	$10.42
Number Exercisable	29,548
Weighted-Average Exercise Price, Exercisable	$10.42
Exercise Price Range 11.87
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Exercise Price	$11.87
Number Outstanding	3,500
Weighted-Average Exercise Price, Outstanding	$11.87
Number Exercisable	3,500
Weighted-Average Exercise Price, Exercisable	$11.87
Exercise Price Range 12.50
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Exercise Price	$12.50
Number Outstanding	19,139
Weighted-Average Exercise Price, Outstanding	$12.50
Number Exercisable	19,139
Weighted-Average Exercise Price, Exercisable	$12.50
Exercise Price Range 13.19
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Exercise Price	$13.19
Number Outstanding	50,000
Weighted-Average Exercise Price, Outstanding	$13.19
Number Exercisable	50,000
Weighted-Average Exercise Price, Exercisable	$13.19
Exercise Price Range 22.34
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Exercise Price	$22.34
Number Outstanding	30,000
Weighted-Average Exercise Price, Outstanding	$22.34
Number Exercisable	30,000
Weighted-Average Exercise Price, Exercisable	$22.34

Monte_Carlo_Simulation_Model_A

Monte Carlo Simulation Model Assumptions Used to Estimate Fair Value of Restricted Stock (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Expected Dividend Yield	0.00%	0.00%
Risk-Free Interest Rate	1.00%	0.80%
Expected Volatility	58.60%	50.40%
Market Index	35.60%	35.30%
Expected Life	3 years	3 years
Peer Group | Minimum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Expected Volatility	29.80%	28.40%
Peer Group | Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Expected Volatility	85.00%	65.70%

Summary_of_Nonvested_Stock_Act

Summary of Nonvested Stock Activity (Details) (Restricted Stock, USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock awards, beginning balance, Number of Shares	1,519,301
Awards, Number of Shares	1,336,295	3,315
Forfeitures, Number of Shares	-244,539
Vested, Number of Shares	-202,492
Stock awards, ending balance, Number of Shares	2,408,565
Stock awards, beginning balance, Weighted Average Grant Date Fair Value	$14.05
Awards, Weighted Average Grant Date Fair Value	$4.04
Forfeitures, Weighted Average Grant Date Fair Value	$12.55
Vested, Weighted Average Grant Date Fair Value	$12.52
Stock awards, ending balance, Weighted Average Grant Date Fair Value	$8.65

Commitments_and_Contingencies_1

Commitments and Contingencies - Additional Information (Details) (USD $)	3 Months Ended		1 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Jan. 31, 2015	Dec. 31, 2014
Loss Contingencies [Line Items]
Significant probable or possible environmental contingent liabilities	$0
Letters of credit	7,000,000
Rent expense	200,000	200,000
Termination fees incurred	5,000,000
Maximum guarantee of payment of obligations	414,800,000
Transportation, processing and marketing expenses of oil natural gas and natural gas liquids	18,800,000	9,400,000
Fees related to unutilized capacity commitments	900,000
Production and Lease Operating Expense	29,052,000	20,033,000
Accrued Liabilities	56,559,000			59,478,000
Forecast
Loss Contingencies [Line Items]
Termination fees paid			2,500,000
Capacity Reservation
Loss Contingencies [Line Items]
Estimated working interest	70.00%
Capacity Reservation | 2015
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed	12,100,000
Capacity Reservation | 2016
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed	25,800,000
Capacity Reservation | 2017
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed	31,000,000
Capacity Reservation | 2018
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed	31,000,000
Capacity Reservation | 2019
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed	31,000,000
Capacity Reservation | Thereafter
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed	214,700,000
Drilling Commitments
Loss Contingencies [Line Items]
Number of rigs to support Appalachian Basin operations	1
Number of contracts terminated	2
Drilling Commitments | 2015
Loss Contingencies [Line Items]
Minimum cost to retain drilling rigs	1,700,000
Minimum gross cost to retain the completion services	11,000,000
Drilling Commitments | 2016
Loss Contingencies [Line Items]
Minimum cost to retain drilling rigs	2,200,000
Drilling Commitments | 2017
Loss Contingencies [Line Items]
Minimum cost to retain drilling rigs	2,200,000
Pennsylvania Impact Fee
Loss Contingencies [Line Items]
Rate in which unconventional wells are charged	20.00%
Production and Lease Operating Expense	600,000	600,000
Pennsylvania Impact Fee | 2014 Impact Fees
Loss Contingencies [Line Items]
Accrued Liabilities	$6,200,000

Lease_Commitments_for_Each_of_

Lease Commitments for Each of Next Five Years (Details) (USD $)	Mar. 31, 2015
In Thousands, unless otherwise specified
Commitments And Contingencies Disclosure [Abstract]
2015	$848
2016	1,129
2017	1,143
2018	721
2019	721
Thereafter	180
Total	$4,742

Minimum_Net_Obligations_under_

Minimum Net Obligations under Sales, Gathering and Transportation Agreements (Details) (USD $)	Mar. 31, 2015
In Thousands, unless otherwise specified
Commitments And Contingencies Disclosure [Abstract]
2015	$16,516
2016	32,656
2017	51,581
2018	54,267
2019	53,181
Thereafter	624,195
Total	$832,396

Fee_for_Unconventional_Gas_Wel

Fee for Unconventional Gas Wells (Details) (Pennsylvania Impact Fee, USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015
Less than $2.25
Unconventional Gas Wells [Line Items]
Year One	$40,200	[1]
Year Two	30,200	[1]
Year Three	25,200	[1]
Year 4 – 10	10,100	[1]
Year 11 – 15	5,000	[1]
$2.26 - $2.99
Unconventional Gas Wells [Line Items]
Year One	45,300	[1]
Year Two	35,000	[1]
Year Three	30,200	[1]
Year 4 – 10	15,100	[1]
Year 11 – 15	5,000	[1]
$3.00 - $4.99
Unconventional Gas Wells [Line Items]
Year One	50,300	[1]
Year Two	40,200	[1]
Year Three	30,200	[1]
Year 4 – 10	20,100	[1]
Year 11 – 15	10,100	[1]
$5.00 - $5.99
Unconventional Gas Wells [Line Items]
Year One	55,300	[1]
Year Two	45,300	[1]
Year Three	40,200	[1]
Year 4 – 10	20,100	[1]
Year 11 – 15	10,100	[1]
More than $5.99
Unconventional Gas Wells [Line Items]
Year One	60,400	[1]
Year Two	55,300	[1]
Year Three	50,300	[1]
Year 4 – 10	20,100	[1]
Year 11 – 15	$10,100	[1]
[1]	Pricing utilized for determining annual fee is based on the arithmetic mean of the NYMEX settled price for the near-month contract as reported by the Wall Street Journal for the last trading day of each month of a calendar year for the 12-month period ending December 31.

Earnings_Per_Common_Share_Addi

Earnings Per Common Share - Additional Information (Details)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
6.0% convertible perpetual preferred stock, Series A
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Dividend per share percentage	6.00%
Conversion of Preferred Stock
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Anti-dilutive securities excluded from computation of earnings per share	8.9
Stock Options
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Anti-dilutive securities excluded from computation of earnings per share	0.5	0.3
Performance Based Restricted Stock Awards
Antidilutive Securities Excluded From Computation Of Earnings Per Share [Line Items]
Anti-dilutive securities excluded from computation of earnings per share	1.3	1

Earnings_Per_Share_Computation

Earnings Per Share - Computation of Basic and Diluted Earning Per Common Share (Details) (USD $)	3 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Numerator:
Net Income (Loss) From Continuing Operations	($18,479)	$8,755
Net Income From Discontinued Operations, Less Noncontrolling Interests	665	113
Less: Preferred Stock Dividends	-2,415
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	($20,229)	$8,868
Denominator:
Weighted Average Common Shares Outstanding - Basic	54,370	52,984
Effect of Dilutive Securities:
Employee Stock Options		150
Employee Performance-Based Restricted Stock Awards		369
Weighted Average Common Shares Outstanding - Diluted	54,370	53,503
Earnings per Common Share Attributable to Rex Energy Common Shareholders:
Basic — Net Income (Loss) From Continuing Operations	($0.38)	$0.17
Basic — Net Income From Discontinued Operations	$0.01	$0
Basic – Net Income (Loss) Attributable to Rex Energy Common Shareholders	($0.37)	$0.17
Diluted — Net Income (Loss) From Continuing Operations	($0.38)	$0.17
Diluted — Net Income From Discontinued Operations	$0.01	$0
Diluted – Net Income (Loss) Attributable to Rex Energy Common Shareholders	($0.37)	$0.17

Equity_Method_Investments_Addi

Equity Method Investments - Additional Information (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014	Dec. 31, 2014
Schedule Of Equity Method Investments [Line Items]
Equity Method Investments	$17,692,000		$17,895,000
Loss on Equity Method Investments	-203,000	-200,000
Production and Lease Operating Expense	29,052,000	20,033,000
RW Gathering, LLC
Schedule Of Equity Method Investments [Line Items]
Ownership percentage	40.00%
Contributions to Equity Method Investments	0	0
Loss on Equity Method Investments	-500,000	-500,000
Production and Lease Operating Expense	200,000	200,000
Receivables	$0		$0

Impairment_Expense_Additional_

Impairment Expense - Additional Information (Details) (USD $)	3 Months Ended
	Mar. 31, 2015	Mar. 31, 2014
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Impairment Expense	$7,023,000	$25,000
Proved Properties in Clearfield Country, Pennsylvania
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Impairment Expense	4,000,000
Appalachian Basin
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Undeveloped properties, cost	335,300,000
Appalachian Basin | Undeveloped Leases
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Impairment Expense	$3,000,000

Exploration_Expense_Additional

Exploration Expense - Additional Information (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
Exploration Expense [Line Items]
Exploration Expense	$518	$2,060
Geological and Geophysical Type Expenditures
Exploration Expense [Line Items]
Exploration Expense		1,600
Payment of Delay Rentals | Appalachian Basin
Exploration Expense [Line Items]
Exploration Expense		$400

Condensed_Consolidating_Financ2

Condensed Consolidating Financial Information - Additional Information (Details) (USD $)	Mar. 31, 2015
In Millions, unless otherwise specified
Condensed Financial Information Of Parent Company Only Disclosure [Abstract]
Senior Notes	$675

Condensed_Consolidating_Balanc

Condensed Consolidating Balance Sheets (Details) (USD $)	Mar. 31, 2015	Dec. 31, 2014	Mar. 31, 2014
In Thousands, unless otherwise specified
Current Assets
Cash and Cash Equivalents	$4,964	$17,978	$1,123
Accounts Receivable	33,386	43,936
Taxes Receivable	2	504
Total Short-Term Derivative Assets	32,849	29,265
Assets Held for Sale	42,696	34,257
Inventory, Prepaid Expenses and Other	2,737	3,403
Total Current Assets	116,634	129,343
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties	1,147,468	1,079,039
Unevaluated Oil and Gas Properties	335,279	322,413
Other Property and Equipment	46,732	46,361
Wells and Facilities in Progress	101,993	127,655
Pipelines	15,657	15,657
Total Property and Equipment	1,647,129	1,591,125
Less: Accumulated Depreciation, Depletion and Amortization	-395,337	-366,917
Net Property and Equipment	1,251,792	1,224,208
Deferred Financing Costs and Other Assets—Net	17,058	17,070
Equity Method Investments	17,692	17,895
Long-Term Deferred Tax Asset	8,301	8,301
Long-Term Derivative Instruments	10,040	4,904
Total Assets	1,421,517	1,401,721
Current Liabilities
Accounts Payable	45,116	53,340
Current Maturities of Long-Term Debt	1,056	1,176
Accrued Liabilities	56,559	59,478
Short-Term Derivative Instruments	1,393	421
Current Deferred Tax Liability	8,301	8,301
Liabilities Related to Assets Held for Sale	31,519	25,115
Total Current Liabilities	143,944	147,831
Long-Term Derivative Instruments	4,086	2,377
Senior Secured Line of Credit and Long-Term Debt	38,137	251
Senior Notes	675,000
Premium on Senior Notes, Net	2,632	2,725
Other Deposits and Liabilities	3,812	4,018
Future Abandonment Cost	39,040	38,146
Total Liabilities	906,651	870,348
Stockholders’ Equity
Preferred Stock	1	1
Common Stock	54	54
Additional Paid-In Capital	620,782	617,826
Accumulated Earnings (Deficit)	-110,978	-90,749
Rex Energy Stockholders’ Equity	509,859	527,132
Noncontrolling Interests	5,007	4,241
Total Stockholders’ Equity	514,866	531,373
Total Liabilities and Stockholders’ Equity	1,421,517	1,401,721
Eliminations
Current Assets
Assets Held for Sale	-11,756	-2,537
Total Current Assets	-11,756	-2,537
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties	-6,489	-5,760
Wells and Facilities in Progress	-671	-560
Pipelines	-1,898	-1,898
Total Property and Equipment	-9,058	-8,218
Less: Accumulated Depreciation, Depletion and Amortization	1,271	1,037
Net Property and Equipment	-7,787	-7,181
Intercompany Receivables	-978,279	-951,025
Investment in Subsidiaries – Net	-248,058	-264,150
Total Assets	-1,245,880	-1,224,893
Current Liabilities
Accounts Payable	-2,411	-2,537
Liabilities Related to Assets Held for Sale	-376
Total Current Liabilities	-2,787	-2,537
Intercompany Payables	-978,279	-951,025
Total Liabilities	-981,066	-953,562
Stockholders’ Equity
Additional Paid-In Capital	-192,654	-256,887
Accumulated Earnings (Deficit)	-72,160	-18,483
Rex Energy Stockholders’ Equity	-264,814	-275,370
Noncontrolling Interests		4,039
Total Stockholders’ Equity	-264,814	-271,331
Total Liabilities and Stockholders’ Equity	-1,245,880	-1,224,893
Guarantor Subsidiaries
Current Assets
Cash and Cash Equivalents	5,014	17,978
Accounts Receivable	33,289	43,726
Total Short-Term Derivative Assets	32,422	29,265
Inventory, Prepaid Expenses and Other	2,662	3,374
Total Current Assets	73,387	94,343
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties	1,153,433	1,084,332
Unevaluated Oil and Gas Properties	334,581	321,708
Other Property and Equipment	45,837	45,466
Wells and Facilities in Progress	102,236	127,759
Pipelines	17,555	17,555
Total Property and Equipment	1,653,642	1,596,820
Less: Accumulated Depreciation, Depletion and Amortization	-395,810	-367,224
Net Property and Equipment	1,257,832	1,229,596
Deferred Financing Costs and Other Assets—Net	2,421	2,421
Equity Method Investments	17,692	17,895
Investment in Subsidiaries – Net	-1,909	4,161
Long-Term Derivative Instruments	9,732	4,904
Total Assets	1,359,155	1,353,320
Current Liabilities
Accounts Payable	47,472	55,877
Current Maturities of Long-Term Debt	1,056	1,176
Accrued Liabilities	41,799	46,783
Short-Term Derivative Instruments	1,271	421
Total Current Liabilities	91,598	104,257
Long-Term Derivative Instruments	3,237	2,377
Senior Secured Line of Credit and Long-Term Debt	137	251
Other Deposits and Liabilities	3,812	4,018
Future Abandonment Cost	38,987	38,097
Intercompany Payables	974,363	947,114
Total Liabilities	1,112,134	1,096,114
Stockholders’ Equity
Additional Paid-In Capital	177,143	177,144
Accumulated Earnings (Deficit)	69,878	80,062
Rex Energy Stockholders’ Equity	247,021	257,206
Total Stockholders’ Equity	247,021	257,206
Total Liabilities and Stockholders’ Equity	1,359,155	1,353,320
Non-Guarantor Subsidiaries
Current Assets
Cash and Cash Equivalents	-55
Accounts Receivable	50	210
Assets Held for Sale	54,452	36,794
Total Current Assets	54,447	37,004
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties	524	467
Unevaluated Oil and Gas Properties	698	705
Other Property and Equipment	895	895
Wells and Facilities in Progress	428	456
Total Property and Equipment	2,545	2,523
Less: Accumulated Depreciation, Depletion and Amortization	-798	-730
Net Property and Equipment	1,747	1,793
Investment in Subsidiaries – Net		1,541
Total Assets	56,194	40,338
Current Liabilities
Accounts Payable	55
Accrued Liabilities	274	571
Liabilities Related to Assets Held for Sale	31,895	25,115
Total Current Liabilities	32,224	25,686
Future Abandonment Cost	53	49
Intercompany Payables	3,916	3,911
Total Liabilities	36,193	29,646
Stockholders’ Equity
Additional Paid-In Capital	15,511	79,743
Accumulated Earnings (Deficit)	-517	-69,253
Rex Energy Stockholders’ Equity	14,994	10,490
Noncontrolling Interests	5,007	202
Total Stockholders’ Equity	20,001	10,692
Total Liabilities and Stockholders’ Equity	56,194	40,338
Parent Company
Current Assets
Cash and Cash Equivalents	5
Accounts Receivable	47
Taxes Receivable	2	504
Total Short-Term Derivative Assets	427
Inventory, Prepaid Expenses and Other	75	29
Total Current Assets	556	533
Property and Equipment (Successful Efforts Method)
Deferred Financing Costs and Other Assets—Net	14,637	14,649
Long-Term Deferred Tax Asset	8,301	8,301
Intercompany Receivables	978,279	951,025
Investment in Subsidiaries – Net	249,967	258,448
Long-Term Derivative Instruments	308
Total Assets	1,252,048	1,232,956
Current Liabilities
Accrued Liabilities	14,486	12,124
Short-Term Derivative Instruments	122
Current Deferred Tax Liability	8,301	8,301
Total Current Liabilities	22,909	20,425
Long-Term Derivative Instruments	849
Senior Secured Line of Credit and Long-Term Debt	38,000
Premium on Senior Notes, Net	2,632	2,725
Total Liabilities	739,390	698,150
Stockholders’ Equity
Preferred Stock	1	1
Common Stock	54	54
Additional Paid-In Capital	620,782	617,826
Accumulated Earnings (Deficit)	-108,179	-83,075
Rex Energy Stockholders’ Equity	512,658	534,806
Total Stockholders’ Equity	512,658	534,806
Total Liabilities and Stockholders’ Equity	1,252,048	1,232,956
8.875% Senior Notes
Current Liabilities
Senior Notes	350,000	350,000
8.875% Senior Notes | Parent Company
Current Liabilities
Senior Notes	350,000	350,000
6.25% Senior Notes
Current Liabilities
Senior Notes	325,000	325,000
6.25% Senior Notes | Parent Company
Current Liabilities
Senior Notes	$325,000	$325,000

Condensed_Consolidating_Balanc1

Condensed Consolidating Balance Sheets (Parenthetical) (Details)	3 Months Ended	12 Months Ended
	Mar. 31, 2015	Dec. 31, 2014
8.875% Senior Notes
Condensed Balance Sheet Statements Captions [Line Items]
Interest rate	8.88%	8.88%
Due date	2020	2020
6.25% Senior Notes
Condensed Balance Sheet Statements Captions [Line Items]
Interest rate	6.25%	6.25%
Due date	2022	2022

Condensed_Consolidating_Statem

Condensed Consolidating Statements of Operations (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
OPERATING REVENUE
Oil, Natural Gas and NGL Sales	$54,111	$81,299
Other Revenue	11	44
TOTAL OPERATING REVENUE	54,122	81,343
OPERATING EXPENSES
Production and Lease Operating Expense	29,052	20,033
General and Administrative Expense	9,651	9,562
Loss on Disposal of Asset	65	72
Impairment Expense	7,023	25
Exploration Expense	518	2,060
Depreciation, Depletion, Amortization and Accretion	26,126	19,723
Other Operating Expense (Income)	5,191	83
TOTAL OPERATING EXPENSES	77,626	51,558
INCOME (LOSS) FROM OPERATIONS	-23,504	29,785
OTHER INCOME (EXPENSE)
Interest Expense	-12,017	-6,933
Gain (Loss) on Derivatives, Net	17,119	-9,750
Other Expense	34	-37
Loss on Equity Method Investments	-203	-200
TOTAL OTHER INCOME (EXPENSE)	4,933	-16,920
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX	-18,571	12,865
Income Tax (Expense) Benefit	92	-4,110
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	-18,479	8,755
Income (Loss) From Discontinued Operations, Net of Income Tax	1,962	1,682
NET INCOME	-16,517	10,437
Net Income Attributable to Noncontrolling Interests	1,297	1,569
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	-17,814	8,868
Preferred Stock Dividends	2,415
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	-20,229	8,868
Eliminations
OPERATING EXPENSES
Depreciation, Depletion, Amortization and Accretion	-235	-111
TOTAL OPERATING EXPENSES	-235	-111
INCOME (LOSS) FROM OPERATIONS	235	111
OTHER INCOME (EXPENSE)
Income (Loss) From Equity in Consolidated Subsidiaries	3,214	-13,567
TOTAL OTHER INCOME (EXPENSE)	3,214	-13,567
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX	3,449	-13,456
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	3,449	-13,456
Income (Loss) From Discontinued Operations, Net of Income Tax	-864	-2,158
NET INCOME	2,585	-15,614
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	2,585	-15,614
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS		-15,614
Guarantor Subsidiaries
OPERATING REVENUE
Oil, Natural Gas and NGL Sales	54,000	81,299
Other Revenue	11	44
TOTAL OPERATING REVENUE	54,011	81,343
OPERATING EXPENSES
Production and Lease Operating Expense	29,014	20,030
General and Administrative Expense	6,659	7,880
Loss on Disposal of Asset	65	72
Impairment Expense	7,012	25
Exploration Expense	518	2,060
Depreciation, Depletion, Amortization and Accretion	26,292	19,823
Other Operating Expense (Income)	5,191	83
TOTAL OPERATING EXPENSES	74,751	49,973
INCOME (LOSS) FROM OPERATIONS	-20,740	31,370
OTHER INCOME (EXPENSE)
Interest Expense	-58	-15
Gain (Loss) on Derivatives, Net	16,856	-10,439
Other Expense	34	-37
Loss on Equity Method Investments	-203	-200
Income (Loss) From Equity in Consolidated Subsidiaries	-23	-25
TOTAL OTHER INCOME (EXPENSE)	16,606	-10,716
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX	-4,134	20,654
Income Tax (Expense) Benefit	20	-6,637
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	-4,114	14,017
NET INCOME	-4,114	14,017
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	-4,114	14,017
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS		14,017
Non-Guarantor Subsidiaries
OPERATING REVENUE
Oil, Natural Gas and NGL Sales	111
TOTAL OPERATING REVENUE	111
OPERATING EXPENSES
Production and Lease Operating Expense	38	3
General and Administrative Expense	16	23
Impairment Expense	11
Depreciation, Depletion, Amortization and Accretion	69	11
TOTAL OPERATING EXPENSES	134	37
INCOME (LOSS) FROM OPERATIONS	-23	-37
OTHER INCOME (EXPENSE)
Income (Loss) From Equity in Consolidated Subsidiaries	23	25
TOTAL OTHER INCOME (EXPENSE)	23	25
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX		-12
Income Tax (Expense) Benefit		-662
NET INCOME (LOSS) FROM CONTINUING OPERATIONS		-674
Income (Loss) From Discontinued Operations, Net of Income Tax	2,826	3,840
NET INCOME	2,826	3,166
Net Income Attributable to Noncontrolling Interests	1,297	1,569
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	1,529	1,597
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS		1,597
Parent Company
OPERATING EXPENSES
General and Administrative Expense	2,976	1,659
TOTAL OPERATING EXPENSES	2,976	1,659
INCOME (LOSS) FROM OPERATIONS	-2,976	-1,659
OTHER INCOME (EXPENSE)
Interest Expense	-11,959	-6,918
Gain (Loss) on Derivatives, Net	263	689
Income (Loss) From Equity in Consolidated Subsidiaries	-3,214	13,567
TOTAL OTHER INCOME (EXPENSE)	-14,910	7,338
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX	-17,886	5,679
Income Tax (Expense) Benefit	72	3,189
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	-17,814	8,868
NET INCOME	-17,814	8,868
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	-17,814	8,868
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS		$8,868

Condensed_Consolidating_Statem1

Condensed Consolidating Statements of Cash Flows (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2015	Mar. 31, 2014
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	($16,517)	$10,437
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Loss from Equity Method Investments	203	200
Non-cash Expenses	3,377	1,998
Depreciation, Depletion, Amortization and Accretion	26,165	20,424
Deferred Income Tax Expense (Benefit)		4,151
(Gain) Loss on Derivatives	-17,119	9,750
Cash Settlements of Derivatives	11,079	-4,877
Dry Hole Expense	-1	86
(Gain) Loss on Sale of Asset	33	71
Impairment Expense	7,023	25
Changes in operating assets and liabilities
Accounts Receivable	10,029	-15,921
Inventory, Prepaid Expenses and Other Assets	328	-144
Accounts Payable and Accrued Liabilities	-12,929	-9,792
Other Assets and Liabilities	-305	-348
NET CASH PROVIDED BY OPERATING ACTIVITIES	11,366	16,060
CASH FLOWS FROM INVESTING ACTIVITIES
Proceeds from Joint Venture Acreage Management	39	67
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets	672	15
Proceeds from Joint Venture	16,611
Acquisitions of Undeveloped Acreage	-17,459	-15,534
Capital Expenditures for Development of Oil & Gas Properties and Equipment	-67,013	-66,481
NET CASH USED IN INVESTING ACTIVITIES	-67,150	-81,933
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from Long-Term Debt and Line of Credit	72,826	66,922
Repayments of Long-Term Debt and Line of Credit	-25,761	-19
Repayments of Loans and Other Notes Payable	-686	-528
Debt Issuance Costs	-459	-252
Dividends Paid	-2,415
Distributions by the Partners of Consolidated Joint Ventures	-531	-360
NET CASH PROVIDED BY FINANCING ACTIVITIES	42,974	65,763
NET DECREASE IN CASH	-12,810	-110
CASH – BEGINNING	18,096	1,900
CASH – ENDING	5,286	1,790
Eliminations
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	2,585	-15,614
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Depreciation, Depletion, Amortization and Accretion	-1,607	-111
Changes in operating assets and liabilities
Accounts Receivable	251	3,489
Accounts Payable and Accrued Liabilities	-251	-3,489
NET CASH PROVIDED BY OPERATING ACTIVITIES	978	-15,725
CASH FLOWS FROM INVESTING ACTIVITIES
Intercompany loans to subsidiaries	-1,823	13,568
Capital Expenditures for Development of Oil & Gas Properties and Equipment	845	2,157
NET CASH USED IN INVESTING ACTIVITIES	-978	15,725
Guarantor Subsidiaries
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	-4,114	14,017
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Loss from Equity Method Investments	203	200
Non-cash Expenses	-70	-63
Depreciation, Depletion, Amortization and Accretion	26,292	19,823
Deferred Income Tax Expense (Benefit)		6,597
(Gain) Loss on Derivatives	-16,856	10,439
Cash Settlements of Derivatives	10,579	-5,245
Dry Hole Expense	-1	86
(Gain) Loss on Sale of Asset	65	71
Impairment Expense	7,012	25
Changes in operating assets and liabilities
Accounts Receivable	10,437	-8,921
Inventory, Prepaid Expenses and Other Assets	712	31
Accounts Payable and Accrued Liabilities	-12,518	-16,986
Other Assets and Liabilities	-199	-307
NET CASH PROVIDED BY OPERATING ACTIVITIES	21,542	19,767
CASH FLOWS FROM INVESTING ACTIVITIES
Intercompany loans to subsidiaries	27,192	62,160
Proceeds from Joint Venture Acreage Management	39	67
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets	217	15
Proceeds from Joint Venture	16,611
Acquisitions of Undeveloped Acreage	-17,454	-15,077
Capital Expenditures for Development of Oil & Gas Properties and Equipment	-60,719	-66,618
NET CASH USED IN INVESTING ACTIVITIES	-34,114	-19,453
CASH FLOWS FROM FINANCING ACTIVITIES
Repayments of Loans and Other Notes Payable	-392	-399
NET CASH PROVIDED BY FINANCING ACTIVITIES	-392	-399
NET DECREASE IN CASH	-12,964	-85
CASH – BEGINNING	17,978	1,386
CASH – ENDING	5,014	1,301
Non-Guarantor Subsidiaries
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	2,826	3,166
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Non-cash Expenses	44	139
Depreciation, Depletion, Amortization and Accretion	1,480	712
Deferred Income Tax Expense (Benefit)		743
(Gain) Loss on Sale of Asset	-32
Impairment Expense	11
Changes in operating assets and liabilities
Accounts Receivable	-1,087	-10,439
Inventory, Prepaid Expenses and Other Assets	-322	14
Accounts Payable and Accrued Liabilities	-2,496	2,878
Other Assets and Liabilities	-133
NET CASH PROVIDED BY OPERATING ACTIVITIES	291	-2,787
CASH FLOWS FROM INVESTING ACTIVITIES
Intercompany loans to subsidiaries	-1,688	-175
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets	455
Acquisitions of Undeveloped Acreage	-5	-457
Capital Expenditures for Development of Oil & Gas Properties and Equipment	-7,139	-2,020
NET CASH USED IN INVESTING ACTIVITIES	-8,377	-2,652
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from Long-Term Debt and Line of Credit	18,826	5,922
Repayments of Long-Term Debt and Line of Credit	-9,761	-19
Repayments of Loans and Other Notes Payable	-294	-129
Distributions by the Partners of Consolidated Joint Ventures	-531	-360
NET CASH PROVIDED BY FINANCING ACTIVITIES	8,240	5,414
NET DECREASE IN CASH	154	-25
CASH – BEGINNING	113	509
CASH – ENDING	267	484
Parent Company
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	-17,814	8,868
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Non-cash Expenses	3,403	1,922
Deferred Income Tax Expense (Benefit)		-3,189
(Gain) Loss on Derivatives	-263	-689
Cash Settlements of Derivatives	500	368
Changes in operating assets and liabilities
Accounts Receivable	428	-50
Inventory, Prepaid Expenses and Other Assets	-62	-189
Accounts Payable and Accrued Liabilities	2,336	7,805
Other Assets and Liabilities	27	-41
NET CASH PROVIDED BY OPERATING ACTIVITIES	-11,445	14,805
CASH FLOWS FROM INVESTING ACTIVITIES
Intercompany loans to subsidiaries	-23,681	-75,553
NET CASH USED IN INVESTING ACTIVITIES	-23,681	-75,553
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from Long-Term Debt and Line of Credit	54,000	61,000
Repayments of Long-Term Debt and Line of Credit	-16,000
Debt Issuance Costs	-459	-252
Dividends Paid	-2,415
NET CASH PROVIDED BY FINANCING ACTIVITIES	35,126	60,748
CASH – BEGINNING	5	5
CASH – ENDING	$5	$5