Rex Energy Inactive 10-Q9 Nov 152015 Q3 Quarterly reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
Document and Entity Information - shares	Sep. 30, 2015	Nov. 06, 2015
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q3
Trading Symbol	REXX
Entity Registrant Name	REX ENERGY CORP
Entity Central Index Key	1,397,516
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		55,737,213

Consolidated Balance Sheets (Un

Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Current Assets
Cash and Cash Equivalents	$ 3,150	$ 17,978
Accounts Receivable	29,138	43,936
Taxes Receivable	19	504
Short-Term Derivative Instruments	29,194	29,265
Inventory, Prepaid Expenses and Other	2,169	3,403
Assets Held for Sale		34,257
Total Current Assets	63,670	129,343
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties	1,202,256	1,079,039
Unevaluated Oil and Gas Properties	288,800	322,413
Other Property and Equipment	45,930	46,361
Wells and Facilities in Progress	125,153	127,655
Pipelines	14,275	15,657
Total Property and Equipment	1,676,414	1,591,125
Less: Accumulated Depreciation, Depletion and Amortization	(631,977)	(366,917)
Net Property and Equipment	1,044,437	1,224,208
Deferred Financing Costs and Other Assets – Net	16,271	17,070
Equity Method Investments		17,895
Long-Term Derivative Instruments	11,749	4,904
Long-Term Deferred Tax Asset	10,648	8,301
Total Assets	1,146,775	1,401,721
Current Liabilities
Accounts Payable	29,551	53,340
Current Maturities of Long-Term Debt	668	1,176
Accrued Liabilities	51,964	59,478
Short-Term Derivative Instruments	763	421
Current Deferred Tax Liability	10,648	8,301
Liabilities Related to Assets Held for Sale		25,115
Total Current Liabilities	93,594	147,831
Noncurrent Liabilities
Long-Term Derivative Instruments	3,425	2,377
Senior Secured Line of Credit and Long-Term Debt	69,132	251
Senior Notes	675,000
Premium on Senior Notes, Net	2,442	2,725
Other Deposits and Liabilities	3,372	4,018
Future Abandonment Cost	40,745	38,146
Total Liabilities	$ 887,710	$ 870,348
Commitments and Contingencies (See Note 12)
Stockholders’ Equity
Preferred Stock	$ 1	$ 1
Common Stock	54	54
Additional Paid-In Capital	622,245	617,826
Accumulated Deficit	(363,235)	(90,749)
Rex Energy Stockholders’ Equity	259,065	527,132
Noncontrolling Interests		4,241
Total Stockholders’ Equity	259,065	531,373
Total Liabilities and Stockholders’ Equity	1,146,775	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) (Unaudited) - $ / shares	9 Months Ended	12 Months Ended
	Sep. 30, 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	54,975,151	54,174,763
Common Stock, shares outstanding	54,975,151	54,174,763
8.875% Senior Notes
Interest rate	8.875%	8.875%
Due date	2,020	2,020
6.25% Senior Notes
Interest rate	6.25%	6.25%
Due date	2,022	2,022

Consolidated Statements of Oper

Consolidated Statements of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
OPERATING REVENUE
Oil, Natural Gas and NGL Sales	$ 37,565	$ 73,448	$ 137,437	$ 227,650
Other Revenue	8	18	30	92
TOTAL OPERATING REVENUE	37,573	73,466	137,467	227,742
OPERATING EXPENSES
Production and Lease Operating Expense	30,616	27,674	90,310	69,338
General and Administrative Expense	5,376	9,288	23,507	27,179
(Gain) Loss on Disposal of Asset	(230)	174	(465)	468
Impairment Expense	139,810		264,677	41
Exploration Expense	807	1,462	2,242	4,890
Depreciation, Depletion, Amortization and Accretion	27,124	26,375	82,788	66,454
Other Operating Expense (Income)	183	(24)	5,304	3
TOTAL OPERATING EXPENSES	203,686	64,949	468,363	168,373
INCOME (LOSS) FROM OPERATIONS	(166,113)	8,517	(330,896)	59,369
OTHER EXPENSE
Interest Expense	(11,886)	(10,946)	(36,097)	(25,236)
Gain on Derivatives, Net	28,649	12,316	45,487	2,315
Other Income	20	3	119	20
Loss on Equity Method Investments		(202)	(411)	(610)
TOTAL OTHER INCOME (EXPENSE)	16,783	1,171	9,098	(23,511)
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX	(149,330)	9,688	(321,798)	35,858
Income Tax (Expense) Benefit	20,037	(4,069)	20,653	(13,839)
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	(129,293)	5,619	(301,145)	22,019
Income From Discontinued Operations, Net of Income Taxes	34,617	970	38,149	3,963
NET INCOME (LOSS)	(94,676)	6,589	(262,996)	25,982
Net Income (Loss) Attributable to Noncontrolling Interests	(1)	895	2,245	3,340
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	(94,675)	5,694	(265,241)	22,642
Preferred Stock Dividends	2,415		7,245
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	$ (97,090)	$ 5,694	$ (272,486)	$ 22,642
Earnings per common share:
Basic – Net Income (Loss) From Continuing Operations Attributable to Rex Energy Common Shareholders	$ (2.44)	$ 0.11	$ (5.74)	$ 0.41
Basic – Net Income From Discontinued Operations Attributable to Rex Energy Common Shareholders	0.64	0	0.67	0.01
Basic – Net Income (Loss) Attributable to Rex Energy Common Shareholders	$ (1.80)	$ 0.11	$ (5.07)	$ 0.42
Basic – Weighted Average Shares of Common Stock Outstanding	53,936	53,214	53,748	53,493
Diluted – Net Income (Loss) From Continuing Operations Attributable to Rex Energy Common Shareholders	$ (2.44)	$ 0.10	$ (5.74)	$ 0.40
Diluted – Net Income From Discontinued Operations Attributable to Rex Energy Common Shareholders	0.64	0	0.67	0.01
Diluted – Net Income (Loss) Attributable to Rex Energy Common Shareholders	$ (1.80)	$ 0.10	$ (5.07)	$ 0.41
Diluted – Weighted Average Shares of Common Stock Outstanding	53,936	57,991	53,748	55,254

Consolidated Statements of Chan

Consolidated Statements of Changes in Noncontrolling Interests and Stockholders' Equity (Unaudited) - 9 months ended Sep. 30, 2015 - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock	Preferred Stock	Additional Paid-in Capital	Accumulated Deficit	Rex Energy Stockholders' Equity	Noncontrolling Interest
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	4,851			4,851		4,851
Issuance of Restricted Stock, Net of Forfeitures (in shares)		800
Dividends Declared on Preferred Stock ($150.00 per preferred share)	(7,245)				(7,245)	(7,245)
Capital Distributions	(830)						(830)
Sale of Consolidated Subsidiary	(6,088)			(432)		(432)	(5,656)
Net Income (Loss)	(262,996)				(265,241)	(265,241)	$ 2,245
Balance at Sep. 30, 2015	$ 259,065	$ 54	$ 1	$ 622,245	$ (363,235)	$ 259,065
Balance (in shares) at Sep. 30, 2015		54,975	16

Consolidated Statements of Cha6

Consolidated Statements of Changes in Noncontrolling Interests and Stockholders' Equity (Parenthetical) (Unaudited)	9 Months Ended
	Sep. 30, 2015$ / shares
Statement Of Stockholders Equity [Abstract]
Dividend declared, per preferred share	$ 150

Consolidated Statements of Cash

Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	$ (262,996)	$ 25,982
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Loss from Equity Method Investments	411	610
Non-cash Expenses	5,691	5,146
Depreciation, Depletion, Amortization and Accretion	82,866	69,014
Gain on Derivatives	(45,487)	(2,315)
Cash Settlements of Derivatives	40,102	(3,331)
Dry Hole Expense	468	237
Deferred Income Tax Expense		14,592
Impairment Expense	264,677	41
(Gain) Loss on Sale of Assets	(509)	385
Gain on Sale of Water Solutions	(57,014)
Changes in operating assets and liabilities
Accounts Receivable	12,015	(9,854)
Inventory, Prepaid Expenses and Other Assets	1,092	(1,038)
Accounts Payable and Accrued Liabilities	(26,103)	36,060
Other Assets and Liabilities	(1,794)	(1,966)
NET CASH PROVIDED BY OPERATING ACTIVITIES	13,419	133,563
CASH FLOWS FROM INVESTING ACTIVITIES
Proceeds from Joint Venture Acreage Management	54	210
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets	76,251	412
Proceeds from Joint Venture	16,611
Acquisitions of Undeveloped Acreage	(26,511)	(153,628)
Capital Expenditures for Development of Oil & Gas Properties and Equipment	(163,207)	(310,353)
NET CASH USED IN INVESTING ACTIVITIES	(96,802)	(463,359)
CASH FLOWS FROM FINANCING ACTIVITIES
Repayments of Long-Term Debt and Line of Credit	(108,335)	(248,146)
Proceeds from Long-Term Debt and Line of Credit	186,813	193,041
Repayments of Loans and Other Notes Payable	(1,337)	(1,998)
Proceeds from Senior Notes, Net of Discounts and Premiums		325,000
Debt Issuance Costs	(629)	(6,731)
Proceeds from the Issuance of Preferred Stock, Net		155,011
Dividends Paid on Preferred Stock	(7,245)
Proceeds from the Exercise of Stock Options		421
Distributions by the Partners of Consolidated Joint Ventures	(830)	(1,080)
NET CASH PROVIDED BY FINANCING ACTIVITIES	68,437	415,518
NET INCREASE (DECREASE) IN CASH	(14,946)	85,722
CASH – BEGINNING	18,096	1,900
CASH – ENDING	3,150	87,622
CASH AND CASH EQUIVALENTS ATTRIBUTABLE TO CONTINUING OPERATIONS	3,150	87,285
CASH AND CASH EQUIVALENTS ATTRIBUTABLE TO ASSETS HELD FOR SALE		337
SUPPLEMENTAL DISCLOSURES
Interest Paid, net of capitalized interest	33,686	12,774
Cash Paid for Income Taxes	(502)	(4,643)
NON-CASH ACTIVITIES
Increase (Decrease) in Accrued Liabilities for Capital Expenditures	$ (8,651)	$ 7,042

Basis of Presentation and Princ

Basis of Presentation and Principles of Consolidation	9 Months Ended
Basis of Presentation and Principles of Consolidation	Sep. 30, 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 Basin and Illinois Basin. 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 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 additional information see Note 3, Discontinued Operations/Assets Held for Sale 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 owned a 60% interest. The sale of Water Solutions closed in July 2015. As a result, the assets and liabilities of Water Solutions were classified as held for sale in the accompanying Consolidated Balance Sheets as of December 31, 2014, and the results of operations have been classified as discontinued operations in the accompanying Consolidated Statements of Operations for the three and nine-month periods ended September 30, 2015 and 2014.

Future Abandonment Cost

Future Abandonment Cost	9 Months Ended
Future Abandonment Cost	Sep. 30, 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 totaled $1.1 million and $3.1 ($ in Thousands) September 30, 2015 Beginning Balance at January 1, 2015 $ 40,099 Future Abandonment Obligation Incurred 752 Future Abandonment Obligation Settled (1,563 ) Future Abandonment Obligation Cancelled or Sold (119 ) Future Abandonment Obligation Revision of Estimated Obligation 195 Future Abandonment Obligation Accretion Expense 3,100 Total Future Abandonment Cost 1 $ 42,464 1

Discontinued Operations_Assets

Discontinued Operations/Assets Held For Sale	9 Months Ended
Discontinued Operations/Assets Held For Sale	Sep. 30, 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. In June 2015, we entered into a purchase and sale agreement with American Water Works Company, Inc. (“American Water”) pursuant to which American Water acquired Water Solutions for consideration of approximately $130.0 million, inclusive of cash and debt and subject to other customary adjustments. The sale closed in July 2015, and we received approximately $66.1 million in net proceeds, resulting in a gain of approximately $57.0 million. The transaction is recorded as Discontinued Operations. Any post-closing adjustments are expected to be settled during the fourth quarter of 2015. Water Solutions operates and manages water sourcing, water transfer, equipment rental, trucking and water disposal services, primarily in the Appalachian Basin. The carrying value of the assets and liabilities of Water Solutions that were classified as held for sale in the accompanying Consolidated Balance Sheets at December 31, 2014 are as follows: December 31, ($ in Thousands) 2014 Assets: Cash and Cash Equivalents $ 118 Accounts Receivable 13,226 Inventory, Prepaid Expenses and Other 163 Total Current Assets 13,507 Other Property and Equipment, Net 19,690 Wells and Facilities in Progress 688 Intangible Assets, Net 372 Total Long-Term Assets 20,750 Total Assets Held for Sale $ 34,257 Liabilities: Accounts Payable $ 3,694 Current Maturities of Long-Term Debt 6,236 Accrued Liabilities 6,304 Total Current Liabilities 16,234 Senior Secured Line of Credit and Long-Term Debt 8,881 Total Long-Term Liabilities 8,881 Total Liabilities Related to Assets Held for Sale $ 25,115 Net Assets Held for Sale $ 9,142 Summarized financial information for Discontinued Operations related to Water Solutions and the sale of our investment in 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 September 30, Nine Months Ended September 30, ($ in Thousands) 2015 2014 2015 2014 Revenues: Field Services Revenue $ 1,479 $ 13,071 $ 33,086 $ 41,462 Total Operating Revenue 1,479 13,071 33,086 41,462 Costs and Expenses: General and Administrative Expense 82 1,086 1,961 2,825 Depreciation, Depletion, Amortization and Accretion 2 989 78 2,560 Field Services Operating Expense 1,228 9,567 25,981 30,912 Gain on Sale of Asset (2 ) (91 ) (44 ) (84 ) Interest Expense 56 134 487 482 Other (Income) Expense (56,956 ) 16 (56,836 ) 50 Total Costs and Expenses (55,590 ) 11,701 (28,373 ) 36,745 Income from Discontinued Operations Before Income Taxes 57,069 1,370 61,459 4,717 Income Tax Expense (22,452 ) (400 ) (23,310 ) (754 ) Income from Discontinued Operations, net of taxes $ 34,617 $ 970 $ 38,149 $ 3,963

Business and Oil and Gas Proper

Business and Oil and Gas Property Acquisitions and Dispositions	9 Months Ended
	Sep. 30, 2015
Business Combinations [Abstract]
Business and Oil and Gas Property Acquisitions and Dispositions	4. BUSINESS AND OIL AND GAS PROPERTY ACQUISITIONS AND DISPOSITIONS Water Solutions As described in Note 3 above, we sold Water Solutions pursuant to a purchase and sale agreement with American Water. ArcLight Capital Partners, LLC 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. We expect to receive consideration for the transaction of approximately $67.0 million, with $16.6 million received at closing for wells that had previously been completed or were at that time in the process of being drilled and completed. The remainder of the proceeds will be received as additional wells are 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. ArcLight also has the option to participate in the development of 17 additional wells in 2016; if ArcLight exercises this option, ArcLight will participate and fund 20% of the estimated well costs for the designated wells in return for a 20% working interest. If ArcLight elects to participate in the 2016 wells, the wells will also be subject to certain return on investment and internal rate of return thresholds, which, once meant, will revert 50% of ArcLight’s working interest in the wells back to us. As of September 30, 2015, ArcLight had paid approximately $24.9 million for their interest in wells that have been drilled or are in the process of being drilled. 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 Pron

Recently Issued Accounting Pronouncements	9 Months Ended
Recently Issued Accounting Pronouncements	Sep. 30, 2015
Accounting Policies [Abstract]
Recently Issued Accounting Pronouncements	5. RECENTLY ISSUED ACCOUNTING PRONOUNCEMENTS In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis In April 2015, the FASB issued ASU 2015-03, Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers Revenue Recognition 1) Identify the contract(s) with a customer. 2) Identify the performance obligations in the contract. 3) Determine the transaction price. 4) Allocate the transaction price to the performance obligations in the contract. 5) Recognize revenue when (or as) the entity satisfies a performance obligation. An entity should apply the amendments in this ASU using one of the following two methods: 1) Retrospectively to each prior reporting period presented. 2) Retrospectively with the cumulative effect of initially applying this ASU recognized at the date of the initial applications. In July 2015, the FASB approved a one-year deferral of the effective date of this new standard so the guidance is effective for the reporting period beginning January 1, 2018, with early adoption permitted in the first quarter 2017. We are currently evaluating the new guidance and have not determined the impact this standard may have on our Consolidated Financial Statements or decided upon the method of adoption. In August 2015, the FASB issued ASU 2015-15, Interest – Imputation of Interest (Subtopic 835-30), Presentation and Subsequent Measurement of Debt Issuance Costs with Line-of-Credit Arrangements Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs

Concentrations of Credit Risk

Concentrations of Credit Risk	9 Months Ended
Concentrations of Credit Risk	Sep. 30, 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 Fair Value of Financial and Derivative Instruments We also depend on a relatively small number of purchasers for a substantial portion of our revenue. For the nine months ended September 30, 2015, approximately 91.7% of our commodity sales came from five purchasers, with the largest single purchaser accounting for 44.1% 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.

Long-Term Debt

Long-Term Debt	9 Months Ended
Long-Term Debt	Sep. 30, 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 September 4, 2015 (the “Senior Credit Facility”). As of September 30, 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 subfacility exists for up to $60.0 million of letters of credit. As of September 30, 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 September 30, 2015, we had $69.0 million in outstanding borrowings and approximately $270.3 million available to borrow. There were no borrowings as of December 31, 2014. 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 September 30, 2015 was approximately 3.4 to 1.0. 2020 Senior Notes and 2022 Senior Notes As of September 30, 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”). The Senior Notes are unsecured, and are governed by indentures with substantially similar terms and provisions (the “Indentures”). The Indentures contain affirmative and negative covenants that are customary for instruments of this nature, including restrictions or limitations on our ability to incur additional debt, pay dividends, purchase or redeem stock or subordinated indebtedness, make investments, create liens, sell assets, merge with or into other companies or transfer substantially all of our assets, unless those actions satisfy the terms and conditions of the Indentures or are otherwise excepted or permitted. Certain of the limitations in the Indentures, including our ability to incur debt, pay dividends or make other restricted payments, become more restrictive in the event our ratio of consolidated cash flow to fixed charges for the most recent trailing four quarters (the “Fixed Charge Coverage Ratio”) is less than 2.25:1. As of September 30, 2015, our Fixed Charge Coverage Ratio was 1.73. We expect our Fixed Charge Coverage Ratio to be less than 2.25:1 for the rest of 2015 and 2016. As a result, we anticipate that our ability to incur debt, pay dividends or make certain other restricted payments will be subject to the more restrictive provisions of the Indentures for those periods. The Indentures also contain customary events of default. In certain circumstances, the Trustee or the holders of the Senior Notes may declare all outstanding Senior Notes to be due and payable immediately. Management does not believe that any acceleration of payment will occur within the next twelve months. As of September 30, 2015 and December 31, 2014, we had recorded on our Consolidated Balance Sheets approximately $2.4 million and $2.7 million, respectively, of a net premium related to the Senior Notes. The amortization of our net premium during the three and nine months ended September 30, 2015, which follows the effective interest method, was approximately $0.1 million and $0.3 million, respectively, and was recorded as a credit to Interest Expense on our Consolidated Statement of Operations. Interest is payable semi-annually on our Senior Notes. Interest on the 2020 Senior Notes is paid at a rate of 8.875% per annum on June 1 and December 1 of each year while interest on the 2022 Senior Notes is paid at a rate of 6.25% per annum on February 1 and August 1 of each year. In connection with our Senior Notes due 2020 and our Senior Notes due 2022, we have interest payments due each year of approximately $31.1 million and $20.3 million, respectively. In addition to the Senior Credit Facility and the Senior Notes, we may, from time to time in the normal course of business finance assets such as vehicles, office equipment and leasehold improvements through debt financing at favorable terms. Long-term debt and other obligations consisted of the following at September 30, 2015 and December 31, 2014: ($ in Thousands) September 30, 2015 (Unaudited) December 31, 2014 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 2,442 2,725 Senior Line of Credit(a) 69,000 — Capital Leases and Other Obligations(a) 800 1,427 Total Debt 747,242 679,152 Less Current Portion of Long-Term Debt (668 ) (1,176 ) Total Long-Term Debt $ 746,574 $ 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 and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 1.8%, 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 4.2%, 5.8% and 4.0%, respectively. The following is the principal maturity schedule for debt outstanding as of September 30, 2015: 2015 $ 182 2016 590 2017 28 2018 — 2019 69,000 Thereafter 675,000 Total (a) $ 744,800 (a) Excludes $2.4 million net premium on Senior Notes.

Derivative Instruments And Fair

Derivative Instruments And Fair Value Measurements	9 Months Ended
Derivative Instruments And Fair Value Measurements	Sep. 30, 2015
Fair Value Of Financial Instruments And Derivative Instruments [Abstract]
Derivative Instruments And Fair Value Measurements	8. DERIVATIVE INSTRUMENTS AND FAIR VALUE MEASUREMENTS 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 September 30, 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, 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 $15.1 $3.0 As of September 30, 2015, we had over 75.0% and 18.0% of our annualized oil production hedged through the remainder of 2015 and 2016, respectively, over 85.0% and 77.0% of our annualized natural gas production hedged through the remainder of 2015 and 2016, respectively, and over 59.0% and 41.0% of our annualized NGL production hedged through the remainder of 2015 and 2016, respectively. These percentages exclude the effects of our basis swaps and do not include any estimated impact of increased production from future drilling 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 September 30, 2015 and December 31, 2014, we had $69.0 million and $0.0 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 As of September 30, 2015 and December 31, 2014, we did not have any interest rate derivatives outstanding. We utilize the mark-to-market accounting method to account for interest rate swap and swaptions. We recognize all gains and losses related to interest rate derivatives in the Consolidated Statements of Operations as Gain on Derivatives, Net under Other Expense. During the three and nine months ended September 30, 2015, we received cash payments of approximately $0.1 million and $0.9 million, respectively, related to our previously-held interest rate swaps and swaptions. The following table summarizes the location and amounts of gains and losses on our derivative instruments from continuing operations, none of which are designated as hedges for accounting purposes, in our accompanying Consolidated Statements of Operations for the three and nine months ended September 30, 2015 and 2014: For the Three Months Ended September 30, For the Nine Months Ended September 30, ($ in Thousands) 2015 2014 2015 2014 Oil $ 5,599 $ 3,776 $ 5,648 $ 125 Natural Gas 12,013 6,857 28,649 77 NGLs 10,068 1,683 10,441 1,030 Refined Products (180 ) — (185 ) — Interest Rate 1,149 — 934 1,083 Gain on Derivatives, Net $ 28,649 $ 12,316 $ 45,487 $ 2,315 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 $36.8 million and $31.4 million at September 30, 2015 and December 31, 2014, respectively. Our open asset/(liability) financial commodity derivative instrument positions at September 30, 2015 consisted of: Period Volume Put Option Floor Ceiling Swap Fair Market Value ($ in Thousands) Oil 2015 - Collars 75,000 Bbls $ — $ 52.90 $ 63.15 $ — $ 556 2015 - Three-Way Collars 150,000 Bbls 50.00 65.00 72.50 — 2,102 2016 - Collars 60,000 Bbls — 53.75 63.81 — 467 2016 - Three-Way Collars 45,000 Bbls 50.00 65.00 70.00 — 423 2016 - Deferred Put Spreads 120,000 Bbls 50.00 65.00 — — 531 450,000 Bbls $ 4,079 Natural Gas 2015 - Swaps 4,375,000 Mcf $ — $ — $ — $ 3.49 $ 3,891 2015 - Swaptions 550,000 Mcf — — — 3.53 453 2015 - Cap Swaps 1,950,000 Mcf 3.43 — — 4.12 1,170 2015 - Three-Way Collars 2,200,000 Mcf 2.84 3.53 4.25 — 881 2015 - Put Spreads 650,000 Mcf 2.56 3.32 — — 336 2015 - Calls 750,000 Mcf — — 4.15 — — 2015 - Basis Swaps - Dominion South 2,300,000 Mcf — — — (0.82 ) 101 2016 - Swaps 9,600,000 Mcf — — — 3.45 6,207 2016 - Swaptions 0 Mcf — — — — (305 ) 2016 - Cap Swaps 3,600,000 Mcf 3.45 — — 4.11 1,848 2016 - Collars 900,000 Mcf — 3.20 4.04 — 427 2016 - Three-Way Collars 19,170,000 Mcf 2.51 3.22 3.99 — 4,620 2016 - Put Spreads 2,100,000 Mcf 2.25 3.00 — — 172 2016 - Basis Swaps - Dominion South 12,510,000 Mcf — — — (0.90 ) (124 ) 2017 - Swaps 960,000 Mcf — — — 3.60 614 2017 - Cap Swaps 2,100,000 Mcf 3.34 — — 4.07 1,122 2017 - Three-Way Collars 13,900,000 Mcf 2.38 3.09 4.02 — 2,670 2017 - Calls 840,000 Mcf — — 4.00 — (93 ) 2017 - Basis Swaps - Dominion South 4,550,000 Mcf — — — (0.83 ) (353 ) 2017 - Basis Swaps - Texas Gas 14,600,000 Mcf — — — (0.13 ) (15 ) 2018 - Swaps 960,000 Mcf — — — 3.60 614 2018 - Cap Swaps 1,800,000 Mcf 3.30 — — 4.05 975 2018 - Three-Way Collars 5,475,000 Mcf 2.40 3.00 3.75 — 296 2018 - Calls 3,650,000 Mcf — — 4.25 — (439 ) 2018 - Basis Swaps - Dominion South 6,400,000 Mcf — — — (0.83 ) (515 ) 2018 - Basis Swaps - Texas Gas 14,600,000 Mcf — — — (0.13 ) (15 ) 2019 - Basis Swaps - Dominion South 7,300,000 Mcf — — — (0.83 ) (592 ) 2020 - Basis Swaps - Dominion South 7,320,000 Mcf — — — (0.83 ) (596 ) 145,110,000 Mcf $ 23,350 NGLs 2015 - C3+ NGL Swaps 387,000 Bbls $ — $ — $ — $ 31.92 $ 2,642 2015 - Ethane Swaps 102,600 Bbls — — — 8.40 5 2016 - C3+ NGL Swaps 1,131,000 Bbls — — — 32.76 6,848 2016 - Ethane Swaps 240,000 Bbls — — — 8.82 54 2017 - C3+ NGL Swaps 132,000 Bbls — — — 19.74 (38 ) 1,992,600 Bbls $ 9,511 Refined Product (Heating Oil) 2016 - Swaps 12,000 Bbls $ — $ — $ — $ 84.00 $ (185 ) 12,000 Bbls $ (185 ) The combined fair value of derivatives, none of which are designated or qualifying as hedges, included in our Consolidated Balance Sheets as of September 30, 2015 and December 31, 2014 is summarized below: September 30, December 31, ($ in Thousands) 2015 2014 Short-Term Derivative Assets: Crude Oil—Deferred Put Spread $ 398 $ 1,413 Crude Oil—Call Protected Swap — 1,227 Crude Oil—Three-Way Collars 2,384 4,596 Crude Oil—Collars 1,023 — NGL—Swaps 7,847 6,181 Natural Gas—Swaps 8,462 4,522 Natural Gas—Cap Swaps 2,628 3,430 Natural Gas—Basis Swaps 661 2,815 Natural Gas—Three-Way Collars 4,427 5,081 Natural Gas—Swaption 454 — Natural Gas—Collars 427 — Natural Gas—Put Spread 483 — Total Short-Term Derivative Assets $ 29,194 $ 29,265 Long-Term Derivative Assets: NGL—Swaps $ 1,790 $ — Crude Oil—Deferred Put Spread 133 — Crude Oil—Three-Way Collars 141 — Natural Gas—Cap Swaps 2,487 1,617 Natural Gas—Swaps 2,864 1,554 Natural Gas—Basis Swaps 269 — Natural Gas—Put Spread 25 — Natural Gas—Three-Way Collars 4,040 1,733 Total Long-Term Derivative Assets $ 11,749 $ 4,904 Total Derivative Assets $ 40,943 $ 34,169 Short-Term Derivative Liabilities: NGL—Swaps $ (84 ) $ — Refined Product—Swaps (139 ) — Natural Gas—Call — (74 ) Natural Gas—Swaption (1 ) (154 ) Natural Gas—Put Spread — (193 ) Natural Gas—Basis Swaps (539 ) — Total Short - Term Derivative Liabilities $ (763 ) $ (421 ) Long-Term Derivative Liabilities: NGL—Swaps $ (42 ) $ — Refined Product—Swaps (46 ) — Natural Gas—Basis Swaps (2,500 ) (1,281 ) Natural Gas—Swaption (305 ) — Natural Gas—Call (532 ) (1,096 ) Total Long-Term Derivative Liabilities $ (3,425 ) $ (2,377 ) Total Derivative Liabilities $ (4,188 ) $ (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 September 30, 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 September 30, 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 September 30, 2015 and December 31, 2014 are included in the table below. As of September 30, 2015 Range (price per Mcf) Weighted Average (price per Mcf) Fair Value (in thousands) Natural Gas Basis Differential Forward Curve - Dominion South ($0.44) - ($1.39) $ (0.80 ) $ (2,079 ) Natural Gas Basis Differential Forward Curve - Texas Gas ($0.12) - ($0.13) $ (0.12 ) $ (30 ) As of December 31, 2014 Range (price per Mcf) Weighted Average (price per Mcf) Fair Value (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 and nine months ended September 30, 2015 and for the year 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 September 30, 2015 Using: ($ in Thousands) Total Carrying Value as of September 30, 2015 Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Commodity Derivatives $ 36,755 $ — $ 38,864 $ (2,109 ) 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 values attributable to our oil derivatives as of September 30, 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 September 30, 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 September 30, 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 nine months ended September 30, 2015 and 2014: Nine Months Ended September 30, ($ in Thousands) 2015 2014 Beginning Balance of Level 3 $ 1,341 $ 4,323 Changes in Fair Value 371 (4,343 ) Purchases — — Settlements Received (3,821 ) 2,882 Ending Balance of Level 3 $ (2,109 ) $ 2,862 Changes in fair value on our Level 3 commodity derivative contracts outstanding for the nine months ended September 30, 2015 and 2014, resulted in an increase of approximately $0.4 million and a decrease of approximately $4.3 million, respectively. This amount has been included in Gain (Loss) on Derivatives, Net in our Consolidated Statements of Operations. Future Abandonment Cost We report the fair value of asset retirement obligations on a nonrecurring basis in our Consolidated Balance Sheets. We estimate the fair value of asset retirement obligations based on discounted cash flow projections using numerous estimates, assumptions and judgments regarding such factors as the existence of a legal obligation for an asset retirement obligation; amounts and timing of settlements; the credit-adjusted risk-free rate to be used; and inflation rates. These inputs are unobservable, and thus result in a Level 3 classification. See Note 2, Future Abandonment Costs, Financial Instruments Not Recorded at Fair Value The following table sets forth the fair values of financial instruments that are not recorded at fair value in our Consolidated Financial Statements: September 30, 2015 December 31, 2014 ($ in Thousands) Carrying Amount Fair Value Carrying Amount Fair Value 8.875% Senior Notes due 2020 $ 350,000 $ 168,000 $ 350,000 $ 311,955 6.25% Senior Notes due 2022 $ 325,000 $ 135,688 325,000 241,313 Secured Line of Credit 69,000 69,000 — — Capital Leases and Other Obligations 800 781 1,427 1,393 Total $ 744,800 $ 373,469 $ 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 During the nine months ended September 30, 2015, we recorded an other than temporary impairment of $264.7 million related to proved properties, unproved properties and equity method investments. 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 expense calculation are considered to be Level 2 within the fair value hierarchy. For additional information on our impairment expense, see Note 15, Impairment Expense

Income Taxes

Income Taxes	9 Months Ended
Income Taxes	Sep. 30, 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 September 30, Nine Months Ended September 30, ($ in Thousands) 2015 2014 2015 2014 Income (Expense) Benefit $ 20,037 $ (4,069 ) $ 20,653 $ (13,839 ) Effective Tax Rate 13.4 % 42.0 % 6.4 % 38.6 % For the nine months ended September 30, 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 September 30, 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 nine months ended September 30, 2014, our overall effective tax rate on pretax income from continuing operations was different than the statutory rate of 35% due primarily to state taxes and permanent items, including section 162(m) limitations. Income tax payments made during the three and nine months ended September 30, 2015 and 2014 were negligible. We received tax refunds during the nine months ended September 30, 2015 of approximately $0.5 million and $4.7 million during the nine months ended September 30, 2014.

Capital Stock

Capital Stock	9 Months Ended
Capital Stock	Sep. 30, 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 September 30, 2015 and December 31, 2014, shares of common stock issued and outstanding totaled 54,975,151 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 our acquisition of assets from SWEPI, LP, an affiliate of Royal Dutch Shell, plc, and used 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 February 15, May 15, August 15 and November 15 of each year. We 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. Dividends that are not declared and paid in accordance with the quarterly schedule will accumulate from the most recent date upon which dividends were paid but will not bear interest. In February, May and August 2015, we paid quarterly cash dividends of $150.00 per share for the periods of November 15, 2014 to February 15, 2015, February 15, 2015 to May 15, 2015 and May 15, 2015 to August 15, 2015, respectively, each in the aggregate amount of $2.4 million.

Employee Benefit and Equity Pla

Employee Benefit and Equity Plans	9 Months Ended
Employee Benefit and Equity Plans	Sep. 30, 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 nine-month period ended September 30, 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 months ending September 30, 2015 and the three and nine-month periods ended September 30, 2014. Stock-based compensation expense relating to stock options outstanding for the three and nine months ended September 30, 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. The intrinsic value of stock options exercised for the nine months ended September 30, 2014, was approximately $0.3 million. There were no stock options exercised for the nine months ended September 30, 2015. There was no tax benefit for each of the nine-month periods ended September 30, 2015 and 2014. A summary of the status of our issued and outstanding stock options as of September 30, 2015 is as follows: Outstanding Exercisable Exercise Price Number Outstanding At 9/30/15 Weighted-Average Exercise Price Number Exercisable At 9/30/15 Weighted-Average Exercise Price $ 4.05 40,000 $ 4.05 — $ — $ 4.90 40,000 $ 4.90 — $ — $ 5.04 46,041 $ 5.04 46,041 $ 5.04 $ 9.50 75,000 $ 9.50 75,000 $ 9.50 $ 9.99 129,583 $ 9.99 129,583 $ 9.99 $ 10.42 29,548 $ 10.42 29,548 $ 10.42 $ 11.87 3,500 $ 11.87 3,500 $ 11.87 $ 12.50 19,139 $ 12.50 19,139 $ 12.50 $ 13.19 50,000 $ 13.19 50,000 $ 13.19 $ 22.34 30,000 $ 22.34 30,000 $ 22.34 462,811 $ 9.76 382,811 $ 10.86 The weighted average remaining contractual term for options outstanding at September 30, 2015 was 3.0 years and there was no aggregate intrinsic value. The weighted average remaining contractual term for options exercisable at September 30, 2015 was 2.2 years and there was no aggregate intrinsic value. As of September 30, 2015, unrecognized compensation expense related to stock options was $0.1 million. Restricted Stock Awards During the nine-month period ended September 30, 2015, the Compensation Committee approved the issuance of an aggregate of 1,361,497 shares of restricted common stock to 127 employees, one director and one non-employee contractor. During the nine-month period ended September 30, 2014, the Compensation Committee approved the issuance of an aggregate of 51,178 shares of restricted stock to 18 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 September 30, 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: Nine Months Ended September 30, 2015 Year Ended December 31, 2014 Expected Dividend Yield 0.0 % 0.0 % Risk-Free Interest Rate 1.0 % 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 was negligible and $4.8 million for the three and nine-month periods ended September 30, 2015, respectively, and $1.6 million and $4.3 million for the three and nine-month periods ended September 30, 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 September 30, 2015, total unrecognized compensation cost related to restricted common stock grants was approximately $4.3 million, which will be recognized over a weighted average period of 1.6 years. A summary of the restricted stock activity for the nine months ended September 30, 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 1,361,497 3.97 Forfeitures (561,109 ) 11.35 Vested (439,346 ) 8.33 Restricted stock awards, as of September 30, 2015 1,880,343 $ 8.49

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
Commitments and Contingencies	Sep. 30, 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. Other than as set forth below, 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. Litigation Related to Proposed Oil and Gas Leases in Clearfield County, Pennsylvania In October 2011, we were named as defendants in a proposed class action lawsuit filed in the Court of Common Pleas of Clearfield County, Pennsylvania (the “Cardinale case”). The named plaintiffs are two individuals who have sued on behalf of themselves and all persons who are alleged to be similarly situated. The complaint in the Cardinale case generally asserts that a binding contract to lease oil and gas interests was formed between the Company and each proposed class member when representatives of Western Land Services, Inc. (“Western”), a leasing agent that we engaged, presented a form of proposed oil and gas lease and an order for payment to each person in 2008, and each person signed the proposed oil and gas lease form and order for payment and delivered the documents to representatives of Western. We rejected these leases and never signed them. The plaintiffs seek the certification of a class and a judgment declaring the rights of the parties with respect to those proposed leases, as well as damages and other relief as may be established by plaintiffs at trial, together with interest, costs, expenses and attorneys’ fees. In May 2012, the trial court dismissed the Cardinale case with prejudice on the grounds that there was no contract formed between us and the plaintiffs. The plaintiffs appealed the dismissal during the second half of 2012. On May 3, 2013, the Superior Court reversed the decision of the Common Pleas Court and remanded the case for further proceedings. In July 2012, while the Cardinale case was in the midst of the appeals process, counsel for the plaintiffs in the Cardinale case filed two additional lawsuits against us in the Court of Common Pleas of Clearfield County, Pennsylvania: one a proposed class action lawsuit with a different named plaintiff (the “Billotte case”) and another on behalf of a group of individually named plaintiffs (the “Meeker case”). The complaints for both cases contain the same claims as those set forth in the Cardinale case. It is our understanding that these two additional lawsuits were filed for procedural reasons in light of the dismissal of the Cardinale case and the pendency of the appeal. Proceedings in the Billotte case have been consolidated with the Cardinale case; proceedings in the Meeker case are ongoing. In June 2015, the trial court conducted a hearing on plaintiff’s motion for certification of a class in the Cardinale case. In July 2015, the trial court denied plaintiffs’ motion for class certification. Plaintiffs served notice of their appeal of that decision in August 2015 and filed the appeal in September 2015. We continue to vigorously defend against each of these claims. At this time we are unable to express an opinion with respect to the likelihood of an unfavorable outcome or provide an estimate of potential losses, if any. 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 September 30, 2015, we know of no significant probable or possible environmental contingent liabilities. Letters of Credit At September 30, 2015, we had posted $10.7 million in various letters of credit to secure our drilling and related operations. Lease Commitments As of September 30, 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 the three and nine months ended September 30, 2015, was approximately $0.3 million and $0.7 million, respectively, and $0.3 million and $0.8 million for the three and nine months ended September 30, 2014, respectively. Lease commitments by year for each of the next five years are presented in the table below: ($ in Thousands) 2015 $ 282 2016 1,129 2017 1,143 2018 721 2019 721 Thereafter 180 Total $ 4,176 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 $4.0 million in 2015, $19.8 million in 2016, $23.9 million in 2017, $23.9 million in 2018, $23.9 million in 2019 and $165.2 million thereafter, assuming our average net revenue interest in the region of approximately 54%. Charges incurred for unutilized processing capacity with MarkWest during the three and nine-month periods ended September 30, 2015 were negligible and $0.4 million, respectively, and were negligible during the three and nine-month periods ended September 30, 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 $0.6 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 $4.8 million in early termination fees, which were classified as Other Operating Expense in our Consolidated Statement of Operations for the nine months ended September 30, 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 $4.1 million in 2015 and $4.0 million in 2016, 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 $425.7 million. For the three and nine months ended September 30, 2015 and 2014, we incurred expenses related to the transportation, processing and marketing of our oil, natural gas and NGLs of approximately $20.9 million and $60.3 million in 2015, respectively, and $15.7 million and $36.1 million in 2014, 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 three and nine months ended September 30, 2015, we incurred approximately $0.7 million and $2.8 million, respectively, in fees related to unutilized capacity commitments. The unutilized commitment fees are related to undeveloped properties that we acquired during 2014. Minimum net obligations under these sales, gathering and transportation agreements for the next five years are as follows: ($ in Thousands) Total 2015 $ 4,680 2016 25,007 2017 39,958 2018 41,544 2019 40,548 Thereafter 500,763 Total $ 652,500 Pennsylvania Impact Fee In 2012, Pennsylvania state legislators instituted a natural gas impact fee on producers of unconventional natural gas. The fee is 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 $ 35,200 $ 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 ) All fees owed are due on April 1 of each year. For the three and nine months ended September 30, 2015 and 2014, we recorded expense of approximately $0.8 million and $2.3 million in 2015, respectively, and $1.2 million and $2.5 million in 2014, respectively. We record expenses related to the impact fees as Production and Lease Operating Expense. As of September 30, 2015, approximately $2.5 million was accrued for the 2015 impact fees.

Earnings Per Common Share

Earnings Per Common Share	9 Months Ended
Earnings Per Common Share	Sep. 30, 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 each of the three and nine months ended September 30, 2015, we excluded stock options to purchase 0.5 million shares due to our Net Loss from Continuing Operations. For each of the three and nine months ended September 30, 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 each of the three and nine months ended September 30, 2015, we excluded performance-based restricted stock of 1.1 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 (in thousands, except per share amounts) Three Months Ended September 30, Nine Months Ended September 30, Numerator: 2015 2014 2015 2014 Net Income (Loss) From Continuing Operations $ (129,293 ) $ 5,619 $ (301,145 ) $ 22,019 Net Income From Discontinued Operations, Less Noncontrolling Interests 34,618 75 35,904 623 Less: Preferred Stock Dividends (2,415 ) — (7,245 ) — Net Income (Loss) Attributable to Common Shareholders $ (97,090 ) $ 5,694 $ (272,486 ) $ 22,642 Denominator: Weighted Average Common Shares Outstanding - Basic 53,936 53,214 53,748 53,493 Effect of Dilutive Securities: Employee Stock Options — 111 — 134 Employee Performance-Based Restricted Stock Awards — 485 — 218 Effect of Assumed Conversions of Preferred Stock — 4,181 — 1,409 Weighted Average Common Shares Outstanding - Diluted 53,936 57,991 53,748 55,254 Earnings per Common Share Attributable to Rex Energy Common Shareholders: Basic — Net Income (Loss) From Continuing Operations $ (2.44 ) $ 0.11 $ (5.74 ) $ 0.41 — Net Income From Discontinued Operations 0.64 0.00 0.67 0.01 — Net Income (Loss) Attributable to Rex Energy Common Shareholders $ (1.80 ) $ 0.11 $ (5.07 ) $ 0.42 Diluted — Net Income (Loss) From Continuing Operations $ (2.44 ) $ 0.10 $ (5.74 ) $ 0.40 — Net Income From Discontinued Operations 0.64 0.00 0.67 0.01 — Net Income (Loss) Attributable to Rex Energy Common Shareholders $ (1.80 ) $ 0.10 $ (5.07 ) $ 0.41

Equity Method Investments

Equity Method Investments	9 Months Ended
Equity Method Investments	Sep. 30, 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. Our investment in RW Gathering totaled $17.9 million as of December 31, 2014, and was recorded on our Consolidated Balance Sheets as Equity Method Investments. During the second quarter of 2015 we incurred a 100% impairment charge of $17.5 million related to RW Gathering (for additional information, see Note 15, Impairment Expense During the three and nine-month periods ended September 30, 2015, we incurred approximately $0.2 million and $0.5 million, respectively, as compared to $0.2 million and $0.5 million for the three and nine-month periods ended September 30, 2014, respectively, 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 September 30, 2015 and December 31, 2014, there were no receivables due from RW Gathering to us.

Impairment Expense

Impairment Expense	9 Months Ended
Impairment Expense	Sep. 30, 2015
Goodwill And Intangible Assets Disclosure [Abstract]
Impairment Expense	15. IMPAIRMENT EXPENSE For the three and nine months ended September 30, 2015, impairment expenses incurred were approximately $139.8 million and $264.7 million, respectively, while impairment expenses incurred during the three and nine months ended September 30, 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 nine months of 2015 included proved property impairments of approximately $211.4 million, with approximately $170.5 million attributable to unconventional assets in the Appalachian Basin, including $17.5 million related to our equity method investment in RW Gathering, and $40.0 million attributable to our conventional oil properties in the Illinois Basin. The remaining proved property impairment expense is related to our conventional dry gas assets in the Appalachian Basin. In addition to the proved properties, we also incurred unproved property impairments of approximately $38.5 million related to unconventional assets in the Appalachian Basin and $14.8 million related to our conventional oil properties in the Illinois Basin.

Exploration Expense

Exploration Expense	9 Months Ended
Exploration Expense	Sep. 30, 2015
Extractive Industries [Abstract]
Exploration Expense	16. EXPLORATION EXPENSE For the three and nine months ended September 30, 2015, we incurred approximately $0.8 million and $2.2 million, respectively, in exploration expenses as compared to $1.5 million and $4.9 million in exploration expenses for the same periods in 2014, respectively. Approximately $0.8 million of the expense incurred in 2015 was due to geological and geophysical type expenditures, $1.0 million was due to the payment of delay rentals in the Appalachian Basin

Condensed Consolidating Financi

Condensed Consolidating Financial Information	9 Months Ended
Condensed Consolidating Financial Information	Sep. 30, 2015
Condensed Financial Information Of Parent Company Only Disclosure [Abstract]
Condensed Consolidating Financial Information	17. CONDENSED CONSOLIDATING FINANCIAL INFORMATION As of September 30, 2015, we had an aggregate of $675.0 million of outstanding Senior Notes, as shown in Note 7, Long-Term Debt Rex Energy I, LLC Rex Energy Operating Corporation Rex Energy IV, LLC PennTex Resources Illinois, Inc. R.E. Gas Development, LLC The non-guarantor subsidiaries include certain consolidated subsidiaries, including Water Solutions, R.E. Disposal, LLC, Rex Energy Marketing, LLC and R.E. Ventures Holdings, LLC. We derive much of our business through and derive much of our income through our subsidiaries. Therefore, our ability to make required payments with respect to indebtedness and other obligations depends on the financial results and condition of our subsidiaries and our ability to receive funds from our subsidiaries. As of September 30, 2015, there were no restrictions on the ability of any of the guarantor subsidiaries to transfer funds to us. There may be restrictions for certain non-guarantor subsidiaries. The following financial statements present condensed consolidating financial data for (i) Rex Energy Corporation, the issuer of the notes, (ii) the combined Guarantors, (iii) the combined other subsidiaries of the Company that did not guarantee the Notes, and (iv) eliminations necessary to arrive at our consolidated financial statements, which include condensed consolidated balance sheets as of September 30, 2015 and December 31, 2014, the condensed consolidating statements of operations for each of the three and nine-month periods ended September 30, 2015 and 2014, and the condensed consolidating statements of cash flows for each of the nine-month periods ended September 30, 2015 and 2014. REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING BALANCE SHEETS AS OF SEPTEMBER 30, 2015 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance ASSETS Current Assets Cash and Cash Equivalents $ 3,145 $ — $ 5 $ — $ 3,150 Accounts Receivable 29,054 37 47 — 29,138 Taxes Receivable — — 19 — 19 Short-Term Derivative Instruments 29,194 — — — 29,194 Inventory, Prepaid Expenses and Other 2,031 — 138 — 2,169 Total Current Assets 63,424 37 209 — 63,670 Property and Equipment (Successful Efforts Method) Evaluated Oil and Gas Properties 1,208,437 771 — (6,952 ) 1,202,256 Unevaluated Oil and Gas Properties 288,800 — — — 288,800 Other Property and Equipment 45,035 895 — — 45,930 Wells and Facilities in Progress 125,207 234 — (288 ) 125,153 Pipelines 16,412 — — (2,137 ) 14,275 Total Property and Equipment 1,683,891 1,900 — (9,377 ) 1,676,414 Less: Accumulated Depreciation, Depletion and Amortization (633,955 ) (860 ) — 2,838 (631,977 ) Net Property and Equipment 1,049,936 1,040 — (6,539 ) 1,044,437 Deferred Financing Costs and Other Assets—Net 2,490 — 13,781 — 16,271 Long-Term Deferred Tax Asset — — 10,648 — 10,648 Intercompany Receivables — — 1,043,565 (1,043,565 ) — Investment in Subsidiaries – Net (1,907 ) — 243,331 (241,424 ) — Long-Term Derivative Instruments 11,749 — — — 11,749 Total Assets $ 1,125,692 $ 1,077 $ 1,311,534 $ (1,291,528 ) $ 1,146,775 LIABILITIES AND STOCKHOLDERS’ EQUITY Current Liabilities Accounts Payable $ 29,551 $ — $ — $ — $ 29,551 Current Maturities of Long-Term Debt 668 — — — 668 Accrued Liabilities 35,471 152 16,341 — 51,964 Short-Term Derivative Instruments 763 — — — 763 Current Deferred Tax Liability — — 10,648 — 10,648 Total Current Liabilities 66,453 152 26,989 — 93,594 Long-Term Derivative Instruments 3,425 — — — 3,425 Senior Secured Line of Credit and Other Long-Term Debt 132 — 69,000 — 69,132 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 — — 2,442 — 2,442 Other Deposits and Liabilities 3,372 — — — 3,372 Future Abandonment Cost 40,685 60 — — 40,745 Intercompany Payables 1,043,090 475 — (1,043,565 ) — Total Liabilities 1,157,157 687 773,431 (1,043,565 ) 887,710 Stockholders’ Equity Preferred Stock — — 1 — 1 Common Stock — — 54 — 54 Additional Paid-In Capital 177,144 — 618,164 (173,063 ) 622,245 Accumulated Earnings (Deficit) (208,609 ) 390 (80,116 ) (74,900 ) (363,235 ) Total Stockholders’ Equity (31,465 ) 390 538,103 (247,963 ) 259,065 Total Liabilities and Stockholders’ Equity $ 1,125,692 $ 1,077 $ 1,311,534 $ (1,291,528 ) $ 1,146,775 REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS FOR THE THREE MONTHS ENDED SEPTEMBER 30, 2015 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance OPERATING REVENUE Oil, Natural Gas and NGL Sales $ 37,429 $ 136 $ — $ — $ 37,565 Other Revenue 8 — — — 8 TOTAL OPERATING REVENUE 37,437 136 — — 37,573 OPERATING EXPENSES Production and Lease Operating Expense 30,565 51 — — 30,616 General and Administrative Expense 5,434 12 (70 ) — 5,376 Gain on Disposal of Asset (230 ) — — — (230 ) Impairment Expense 139,837 1,003 — (1,030 ) 139,810 Exploration Expense 628 179 — — 807 Depreciation, Depletion, Amortization and Accretion 27,370 27 — (273 ) 27,124 Other Operating Income 183 — — — 183 TOTAL OPERATING EXPENSES 203,787 1,272 (70 ) (1,303 ) 203,686 INCOME (LOSS) FROM OPERATIONS (166,350 ) (1,136 ) 70 1,303 (166,113 ) OTHER INCOME (EXPENSE) Interest Expense (53 ) — (11,833 ) — (11,886 ) Gain on Derivatives, Net 27,499 — 1,150 — 28,649 Other Income 20 — — — 20 Loss From Equity Method Investments — — — — — Income (Loss) From Equity in Consolidated Subsidiaries (1,063 ) 1,063 (86,517 ) 86,517 — TOTAL OTHER INCOME (EXPENSE) 26,403 1,063 (97,200 ) 86,517 16,783 INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX (139,947 ) (73 ) (97,130 ) 87,820 (149,330 ) Income Tax Benefit 17,510 74 2,453 — 20,037 INCOME (LOSS) FROM CONTINUING OPERATIONS (122,437 ) 1 (94,677 ) 87,820 (129,293 ) Income From Discontinued Operations, Net of Income Tax — 34,557 — 60 34,617 Net Income (Loss) (122,437 ) 34,558 (94,677 ) 87,880 (94,676 ) Net Income Attributable to Noncontrolling Interests of Discontinued Operations — (1 ) — — (1 ) NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY $ (122,437 ) $ 34,559 $ (94,677 ) $ 87,880 $ (94,675 ) Preferred Stock Dividends — — 2,415 — 2,415 NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS $ (122,437 ) $ 34,559 $ (97,092 ) $ 87,880 $ (97,090 ) REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2015 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance OPERATING REVENUE Oil, Natural Gas and NGL Sales $ 136,981 $ 456 $ — $ — $ 137,437 Other Revenue 30 — — — 30 TOTAL OPERATING REVENUE 137,011 456 — — 137,467 OPERATING EXPENSES Production and Lease Operating Expense 90,164 146 — — 90,310 General and Administrative Expense 18,587 45 4,875 — 23,507 Gain on Disposal of Asset (465 ) — — — (465 ) Impairment Expense 264,693 1,014 — (1,030 ) 264,677 Exploration Expense 1,972 275 — (5 ) 2,242 Depreciation, Depletion, Amortization and Accretion 83,427 133 — (772 ) 82,788 Other Operating Expense 5,304 — — — 5,304 TOTAL OPERATING EXPENSES 463,682 1,613 4,875 (1,807 ) 468,363 INCOME (LOSS) FROM OPERATIONS (326,671 ) (1,157 ) (4,875 ) 1,807 (330,896 ) OTHER INCOME (EXPENSE) Interest Expense (195 ) — (35,902 ) — (36,097 ) Gain on Derivatives, Net 44,553 — 934 — 45,487 Other Income 119 — — — 119 Loss From Equity Method Investments (411 ) — — — (411 ) Income (Loss) From Equity in Consolidated Subsidiaries (1,083 ) 1,083 (227,955 ) 227,955 — TOTAL OTHER INCOME (EXPENSE) 42,983 1,083 (262,923 ) 227,955 9,098 INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX (283,688 ) (74 ) (267,798 ) 229,762 (321,798 ) Income Tax Benefit 18,022 74 2,557 — 20,653 INCOME (LOSS) FROM CONTINUING OPERATIONS (265,666 ) — (265,241 ) 229,762 (301,145 ) Income (Loss) From Discontinued Operations, Net of Income Tax — 39,341 — (1,192 ) 38,149 Net Income (Loss) (265,666 ) 39,341 (265,241 ) 228,570 (262,996 ) Net Income (Loss) Attributable to Noncontrolling Interests of Discontinued Operations — 2,245 — — 2,245 NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY $ (265,666 ) $ 37,096 $ (265,241 ) $ 228,570 $ (265,241 ) Preferred Stock Dividends — — 7,245 — 7,245 NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS $ (265,666 ) $ 37,096 $ (272,486 ) $ 228,570 $ (272,486 ) REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS FOR THE NINE MONTHS ENDING SEPTEMBER 30, 2015 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance CASH FLOWS FROM OPERATING ACTIVITIES Net Income (Loss) $ (265,666 ) $ 39,341 $ (265,241 ) $ 228,570 $ (262,996 ) Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities Loss From Equity Method Investments 411 — — — 411 Non-Cash Expenses (Income) (120 ) (334 ) 6,145 — 5,691 Depreciation, Depletion, Amortization and Accretion 83,427 3,205 — (3,766 ) 82,866 (Gain) on Derivatives (44,553 ) — (934 ) — (45,487 ) Cash Settlements of Derivatives 39,168 — 934 — 40,102 Dry Hole Expense 199 275 — (6 ) 468 Gain on Sale of Asset (465 ) (44 ) — — (509 ) Gain on Sale of Water Solutions — — (57,014 ) — (57,014 ) Impairment Expense 264,693 1,014 — (1,030 ) 264,677 Changes in operating assets and liabilities Accounts Receivable 14,602 (478 ) 429 (2,538 ) 12,015 Inventory, Prepaid Expenses and Other Assets 1,342 (142 ) (108 ) — 1,092 Accounts Payable and Accrued Liabilities (27,935 ) (4,816 ) 4,110 2,538 (26,103 ) Other Assets and Liabilities (1,748 ) (73 ) 27 — (1,794 ) NET CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES 63,355 37,948 (311,652 ) 223,768 13,419 CASH FLOWS FROM INVESTING ACTIVITIES Intercompany loans to subsidiaries 79,071 (38,532 ) 184,393 (224,932 ) — Proceeds from Joint Venture Acreage Management 54 — — — 54 Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets 9,557 559 66,135 — 76,251 Proceeds from Joint Venture 16,611 — — — 16,611 Acquisitions of Undeveloped Acreage (26,232 ) (279 ) — — (26,511 ) Capital Expenditures for Development of Oil and Gas Properties and Equipment (156,432 ) (7,939 ) — 1,164 (163,207 ) NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES (77,371 ) (46,191 ) 250,528 (223,768 ) (96,802 ) CASH FLOWS FROM FINANCING ACTIVITIES Proceeds from Long-Term Debt and Lines of Credit — 35,813 151,000 — 186,813 Repayments of Long-Term Debt and Lines of Credit — (26,335 ) (82,000 ) — (108,335 ) Repayments of Loans and Other Long-Term Debt (817 ) (520 ) — — (1,337 ) Debt Issuance Costs — (3 ) (626 ) — (629 ) Dividends Paid — — (7,245 ) — (7,245 ) Distributions by the Partners of Consolidated Subsidiaries — (830 ) — — (830 ) NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES (817 ) 8,125 61,129 — 68,437 NET INCREASE (DECREASE) IN CASH (14,833 ) (118 ) 5 — (14,946 ) CASH – BEGINNING 17,978 118 — — 18,096 CASH - ENDING $ 3,145 $ — $ 5 $ — $ 3,150 REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING BALANCE SHEETS AS OF DECEMBER 31, 2014 ($ in Thousands) 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 SEPTEMBER 30, 2014 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance OPERATING REVENUE Oil, Natural Gas and NGL Sales $ 73,343 $ 105 $ — $ — $ 73,448 Other Revenue 18 — — — 18 TOTAL OPERATING REVENUE 73,361 105 — — 73,466 OPERATING EXPENSES Production and Lease Operating Expense 27,670 4 — — 27,674 General and Administrative Expense 7,709 24 1,555 — 9,288 Loss on Disposal of Asset 174 — — — 174 Impairment Expense — — — — — Exploration Expense 1,452 10 — — 1,462 Depreciation, Depletion, Amortization and Accretion 26,536 36 — (197 ) 26,375 Other Operating Expense (24 ) — — — (24 ) TOTAL OPERATING EXPENSES 63,517 74 1,555 (197 ) 64,949 INCOME (LOSS) FROM OPERATIONS 9,844 31 (1,555 ) 197 8,517 OTHER INCOME (EXPENSE) Interest Expense (56 ) — (10,890 ) — (10,946 ) Gain (Loss) on Derivatives, Net 12,316 — — — 12,316 Other Expense 3 — — — 3 Loss From Equity Method Investments (202 ) — — — (202 ) Income (Loss) From Equity in Consolidated Subsidiaries 18 (18 ) 12,840 (12,840 ) — TOTAL OTHER INCOME (EXPENSE) 12,079 (18 ) 1,950 (12,840 ) 1,171 INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX 21,923 13 395 (12,643 ) 9,688 Income Tax (Expense) Benefit (8,853 ) (515 ) 5,299 — (4,069 ) INCOME (LOSS) FROM CONTINUING OPERATIONS 13,070 (502 ) 5,694 (12,643 ) 5,619 Loss From Discontinued Operations, Net of Income Tax — 1,836 — (866 ) 970 Net Income (Loss) 13,070 1,334 5,694 (13,509 ) 6,589 Net Income Attributable to Noncontrolling Interests of Discontinued Operations — 895 — — 895 NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY $ 13,070 $ 439 $ 5,694 $ (13,509 ) $ 5,694 Preferred Stock Dividends — — — — — NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS $ 13,070 $ 439 $ 5,694 $ (13,509 ) $ 5,694 REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2014 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance OPERATING REVENUE Oil, Natural Gas and NGL Sales $ 227,547 $ 103 $ — $ — $ 227,650 Other Revenue 92 — — — 92 TOTAL OPERATING REVENUE 227,639 103 — — 227,742 OPERATING EXPENSES Production and Lease Operating Expense 69,328 10 — — 69,338 General and Administrative Expense 22,811 72 4,296 — 27,179 Loss on Disposal of Asset 468 — — — 468 Impairment Expense 41 — — — 41 Exploration Expense 4,877 13 — — 4,890 Depreciation, Depletion, Amortization and Accretion 66,812 109 — (467 ) 66,454 Other Operating Expense 3 — — — 3 TOTAL OPERATING EXPENSES 164,340 204 4,296 (467 ) 168,373 INCOME (LOSS) FROM OPERATIONS 63,299 (101 ) (4,296 ) 467 59,369 OTHER INCOME (EXPENSE) Interest Expense (86 ) — (25,150 ) — (25,236 ) Gain on Derivatives, Net 1,232 — 1,083 — 2,315 Other Income 20 — — — 20 Loss From Equity Method Investments (610 ) — — — (610 ) Income (Loss) From Equity in Consolidated Subsidiaries (65 ) 65 39,667 (39,667 ) — TOTAL OTHER INCOME (EXPENSE) 491 65 15,600 (39,667 ) (23,511 ) INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX 63,790 (36 ) 11,304 (39,200 ) 35,858 Income Tax (Expense) Benefit (22,964 ) (2,214 ) 11,339 — (13,839 ) INCOME (LOSS) FROM CONTINUING OPERATIONS 40,826 (2,250 ) 22,643 (39,200 ) 22,019 Income (Loss) From Discontinued Operations, Net of Income Taxes — 7,597 — (3,634 ) 3,963 NET INCOME (LOSS) 40,826 5,347 22,643 (42,834 ) 25,982 Net Income Attributable to Noncontrolling Interests — 3,340 — — 3,340 NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY $ 40,826 $ 2,007 $ 22,643 $ (42,834 ) $ 22,642 REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS FOR THE NINE MONTHS ENDING SEPTEMBER 30, 2014 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance CASH FLOWS FROM OPERATING ACTIVITIES Net Income (Loss) $ 40,826 $ 5,347 $ 22,643 $ (42,834 ) $ 25,982 Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities Loss From Equity Method Investments 610 — — — 610 Non-Cash Expenses (203 ) 233 5,116 — 5,146 Depreciation, Depletion, Amortization and Accretion 66,812 2,671 — (469 ) 69,014 Deferred Income Tax Expense (Benefit) 22,964 2,967 (11,339 ) — 14,592 Gain on Derivatives (1,232 ) — (1,083 ) — (2,315 ) Cash Settlements of Derivatives (4,209 ) — 878 — (3,331 ) Dry Hole Expense 237 — — — 237 (Gain) Loss on Sale of Asset 469 (84 ) — — 385 Impairment Expense 41 — — — 41 Changes in operating assets and liabilities Accounts Receivable (9,510 ) (3,455 ) 4,685 (1,574 ) (9,854 ) Inventory, Prepaid Expenses and Other Assets (812 ) (209 ) (17 ) — (1,038 ) Accounts Payable and Accrued Liabilities 22,975 (1,007 ) 12,518 1,574 36,060 Other Assets and Liabilities (1,942 ) (24 ) — — (1,966 ) NET CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES 137,026 6,439 33,401 (43,303 ) 133,563 CASH FLOWS FROM INVESTING ACTIVITIES Intercompany loans to subsidiaries 408,192 248 (448,109 ) 39,669 — Proceeds from Joint Venture Acreage Management 210 — — — 210 Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets 248 164 — — 412 Acquisitions of Undeveloped Acreage (152,765 ) (863 ) — — (153,628 ) Capital Expenditures for Development of Oil and Gas Properties and Equipment (305,672 ) (8,315 ) — 3,634 (310,353 ) NET CASH USED IN INVESTING ACTIVITIES (49,787 ) (8,766 ) (448,109 ) 43,303 (463,359 ) CASH FLOWS FROM FINANCING ACTIVITIES Proceeds from Long-Term Debt and Lines of Credit — 22,041 171,000 — 193,041 Repayments of Long-Term Debt and Lines of Credit — (18,146 ) (230,000 ) — (248,146 ) Repayments of Loans and Other Notes Payable (1,323 ) (675 ) — — (1,998 ) Proceeds from Senior Notes, Net of Discounts and Premiums — — 325,000 — 325,000 Debt Issuance Costs — (7 ) (6,724 ) — (6,731 ) Proceeds from the Issuance of Preferred Stock, Net — — 155,011 — 155,011 Proceeds from Exercise of Stock Options — — 421 — 421 Distributions by the Partners of Consolidated Subsidiaries — (1,080 ) — — (1,080 ) NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES (1,323 ) 2,133 414,708 — 415,518 NET INCREASE IN CASH 85,916 (194 ) — — 85,722 CASH – BEGINNING 1,386 509 5 — 1,900 CASH - ENDING $ 87,302 $ 315 $ 5 $ — $ 87,622

Recently Issued Accounting Pr25

Recently Issued Accounting Pronouncements (Policies)	9 Months Ended
Recently Issued Accounting Pronouncements (Policies)	Sep. 30, 2015
Accounting Policies [Abstract]
Recently Issued Accounting Pronouncements	In February 2015, the FASB issued ASU 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis In April 2015, the FASB issued ASU 2015-03, Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers Revenue Recognition 1) Identify the contract(s) with a customer. 2) Identify the performance obligations in the contract. 3) Determine the transaction price. 4) Allocate the transaction price to the performance obligations in the contract. 5) Recognize revenue when (or as) the entity satisfies a performance obligation. An entity should apply the amendments in this ASU using one of the following two methods: 1) Retrospectively to each prior reporting period presented. 2) Retrospectively with the cumulative effect of initially applying this ASU recognized at the date of the initial applications. In July 2015, the FASB approved a one-year deferral of the effective date of this new standard so the guidance is effective for the reporting period beginning January 1, 2018, with early adoption permitted in the first quarter 2017. We are currently evaluating the new guidance and have not determined the impact this standard may have on our Consolidated Financial Statements or decided upon the method of adoption. In August 2015, the FASB issued ASU 2015-15, Interest – Imputation of Interest (Subtopic 835-30), Presentation and Subsequent Measurement of Debt Issuance Costs with Line-of-Credit Arrangements Interest – Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs

Future Abandonment Cost (Tables

Future Abandonment Cost (Tables)	9 Months Ended
Future Abandonment Cost (Tables)	Sep. 30, 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) September 30, 2015 Beginning Balance at January 1, 2015 $ 40,099 Future Abandonment Obligation Incurred 752 Future Abandonment Obligation Settled (1,563 ) Future Abandonment Obligation Cancelled or Sold (119 ) Future Abandonment Obligation Revision of Estimated Obligation 195 Future Abandonment Obligation Accretion Expense 3,100 Total Future Abandonment Cost 1 $ 42,464 1

Discontinued Operations_Asset27

Discontinued Operations/Assets Held For Sale (Tables)	9 Months Ended
Discontinued Operations/Assets Held For Sale (Tables)	Sep. 30, 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 were classified as held for sale in the accompanying Consolidated Balance Sheets at December 31, 2014 are as follows: December 31, ($ in Thousands) 2014 Assets: Cash and Cash Equivalents $ 118 Accounts Receivable 13,226 Inventory, Prepaid Expenses and Other 163 Total Current Assets 13,507 Other Property and Equipment, Net 19,690 Wells and Facilities in Progress 688 Intangible Assets, Net 372 Total Long-Term Assets 20,750 Total Assets Held for Sale $ 34,257 Liabilities: Accounts Payable $ 3,694 Current Maturities of Long-Term Debt 6,236 Accrued Liabilities 6,304 Total Current Liabilities 16,234 Senior Secured Line of Credit and Long-Term Debt 8,881 Total Long-Term Liabilities 8,881 Total Liabilities Related to Assets Held for Sale $ 25,115 Net Assets Held for Sale $ 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 and the sale of our investment in 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 September 30, Nine Months Ended September 30, ($ in Thousands) 2015 2014 2015 2014 Revenues: Field Services Revenue $ 1,479 $ 13,071 $ 33,086 $ 41,462 Total Operating Revenue 1,479 13,071 33,086 41,462 Costs and Expenses: General and Administrative Expense 82 1,086 1,961 2,825 Depreciation, Depletion, Amortization and Accretion 2 989 78 2,560 Field Services Operating Expense 1,228 9,567 25,981 30,912 Gain on Sale of Asset (2 ) (91 ) (44 ) (84 ) Interest Expense 56 134 487 482 Other (Income) Expense (56,956 ) 16 (56,836 ) 50 Total Costs and Expenses (55,590 ) 11,701 (28,373 ) 36,745 Income from Discontinued Operations Before Income Taxes 57,069 1,370 61,459 4,717 Income Tax Expense (22,452 ) (400 ) (23,310 ) (754 ) Income from Discontinued Operations, net of taxes $ 34,617 $ 970 $ 38,149 $ 3,963

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
Long-Term Debt (Tables)	Sep. 30, 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 September 30, 2015 and December 31, 2014: ($ in Thousands) September 30, 2015 (Unaudited) December 31, 2014 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 2,442 2,725 Senior Line of Credit(a) 69,000 — Capital Leases and Other Obligations(a) 800 1,427 Total Debt 747,242 679,152 Less Current Portion of Long-Term Debt (668 ) (1,176 ) Total Long-Term Debt $ 746,574 $ 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 and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 1.8%, 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 4.2%, 5.8% and 4.0%, respectively.
Principal Maturity Schedule for Total Debt Outstanding	The following is the principal maturity schedule for debt outstanding as of September 30, 2015: 2015 $ 182 2016 590 2017 28 2018 — 2019 69,000 Thereafter 675,000 Total (a) $ 744,800 (a) Excludes $2.4 million net premium on Senior Notes.

Derivative Instruments And Fa29

Derivative Instruments And Fair Value Measurements (Tables)	9 Months Ended
Derivative Instruments And Fair Value Measurements (Tables)	Sep. 30, 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 and nine months ended September 30, 2015 and 2014: For the Three Months Ended September 30, For the Nine Months Ended September 30, ($ in Thousands) 2015 2014 2015 2014 Oil $ 5,599 $ 3,776 $ 5,648 $ 125 Natural Gas 12,013 6,857 28,649 77 NGLs 10,068 1,683 10,441 1,030 Refined Products (180 ) — (185 ) — Interest Rate 1,149 — 934 1,083 Gain on Derivatives, Net $ 28,649 $ 12,316 $ 45,487 $ 2,315
Asset or Liability Financial Commodity Derivative Instrument Positions	Our open asset/(liability) financial commodity derivative instrument positions at September 30, 2015 consisted of: Period Volume Put Option Floor Ceiling Swap Fair Market Value ($ in Thousands) Oil 2015 - Collars 75,000 Bbls $ — $ 52.90 $ 63.15 $ — $ 556 2015 - Three-Way Collars 150,000 Bbls 50.00 65.00 72.50 — 2,102 2016 - Collars 60,000 Bbls — 53.75 63.81 — 467 2016 - Three-Way Collars 45,000 Bbls 50.00 65.00 70.00 — 423 2016 - Deferred Put Spreads 120,000 Bbls 50.00 65.00 — — 531 450,000 Bbls $ 4,079 Natural Gas 2015 - Swaps 4,375,000 Mcf $ — $ — $ — $ 3.49 $ 3,891 2015 - Swaptions 550,000 Mcf — — — 3.53 453 2015 - Cap Swaps 1,950,000 Mcf 3.43 — — 4.12 1,170 2015 - Three-Way Collars 2,200,000 Mcf 2.84 3.53 4.25 — 881 2015 - Put Spreads 650,000 Mcf 2.56 3.32 — — 336 2015 - Calls 750,000 Mcf — — 4.15 — — 2015 - Basis Swaps - Dominion South 2,300,000 Mcf — — — (0.82 ) 101 2016 - Swaps 9,600,000 Mcf — — — 3.45 6,207 2016 - Swaptions 0 Mcf — — — — (305 ) 2016 - Cap Swaps 3,600,000 Mcf 3.45 — — 4.11 1,848 2016 - Collars 900,000 Mcf — 3.20 4.04 — 427 2016 - Three-Way Collars 19,170,000 Mcf 2.51 3.22 3.99 — 4,620 2016 - Put Spreads 2,100,000 Mcf 2.25 3.00 — — 172 2016 - Basis Swaps - Dominion South 12,510,000 Mcf — — — (0.90 ) (124 ) 2017 - Swaps 960,000 Mcf — — — 3.60 614 2017 - Cap Swaps 2,100,000 Mcf 3.34 — — 4.07 1,122 2017 - Three-Way Collars 13,900,000 Mcf 2.38 3.09 4.02 — 2,670 2017 - Calls 840,000 Mcf — — 4.00 — (93 ) 2017 - Basis Swaps - Dominion South 4,550,000 Mcf — — — (0.83 ) (353 ) 2017 - Basis Swaps - Texas Gas 14,600,000 Mcf — — — (0.13 ) (15 ) 2018 - Swaps 960,000 Mcf — — — 3.60 614 2018 - Cap Swaps 1,800,000 Mcf 3.30 — — 4.05 975 2018 - Three-Way Collars 5,475,000 Mcf 2.40 3.00 3.75 — 296 2018 - Calls 3,650,000 Mcf — — 4.25 — (439 ) 2018 - Basis Swaps - Dominion South 6,400,000 Mcf — — — (0.83 ) (515 ) 2018 - Basis Swaps - Texas Gas 14,600,000 Mcf — — — (0.13 ) (15 ) 2019 - Basis Swaps - Dominion South 7,300,000 Mcf — — — (0.83 ) (592 ) 2020 - Basis Swaps - Dominion South 7,320,000 Mcf — — — (0.83 ) (596 ) 145,110,000 Mcf $ 23,350 NGLs 2015 - C3+ NGL Swaps 387,000 Bbls $ — $ — $ — $ 31.92 $ 2,642 2015 - Ethane Swaps 102,600 Bbls — — — 8.40 5 2016 - C3+ NGL Swaps 1,131,000 Bbls — — — 32.76 6,848 2016 - Ethane Swaps 240,000 Bbls — — — 8.82 54 2017 - C3+ NGL Swaps 132,000 Bbls — — — 19.74 (38 ) 1,992,600 Bbls $ 9,511 Refined Product (Heating Oil) 2016 - Swaps 12,000 Bbls $ — $ — $ — $ 84.00 $ (185 ) 12,000 Bbls $ (185 )
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 September 30, 2015 and December 31, 2014 is summarized below: September 30, December 31, ($ in Thousands) 2015 2014 Short-Term Derivative Assets: Crude Oil—Deferred Put Spread $ 398 $ 1,413 Crude Oil—Call Protected Swap — 1,227 Crude Oil—Three-Way Collars 2,384 4,596 Crude Oil—Collars 1,023 — NGL—Swaps 7,847 6,181 Natural Gas—Swaps 8,462 4,522 Natural Gas—Cap Swaps 2,628 3,430 Natural Gas—Basis Swaps 661 2,815 Natural Gas—Three-Way Collars 4,427 5,081 Natural Gas—Swaption 454 — Natural Gas—Collars 427 — Natural Gas—Put Spread 483 — Total Short-Term Derivative Assets $ 29,194 $ 29,265 Long-Term Derivative Assets: NGL—Swaps $ 1,790 $ — Crude Oil—Deferred Put Spread 133 — Crude Oil—Three-Way Collars 141 — Natural Gas—Cap Swaps 2,487 1,617 Natural Gas—Swaps 2,864 1,554 Natural Gas—Basis Swaps 269 — Natural Gas—Put Spread 25 — Natural Gas—Three-Way Collars 4,040 1,733 Total Long-Term Derivative Assets $ 11,749 $ 4,904 Total Derivative Assets $ 40,943 $ 34,169 Short-Term Derivative Liabilities: NGL—Swaps $ (84 ) $ — Refined Product—Swaps (139 ) — Natural Gas—Call — (74 ) Natural Gas—Swaption (1 ) (154 ) Natural Gas—Put Spread — (193 ) Natural Gas—Basis Swaps (539 ) — Total Short - Term Derivative Liabilities $ (763 ) $ (421 ) Long-Term Derivative Liabilities: NGL—Swaps $ (42 ) $ — Refined Product—Swaps (46 ) — Natural Gas—Basis Swaps (2,500 ) (1,281 ) Natural Gas—Swaption (305 ) — Natural Gas—Call (532 ) (1,096 ) Total Long-Term Derivative Liabilities $ (3,425 ) $ (2,377 ) Total Derivative Liabilities $ (4,188 ) $ (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 September 30, 2015 and December 31, 2014 are included in the table below. As of September 30, 2015 Range (price per Mcf) Weighted Average (price per Mcf) Fair Value (in thousands) Natural Gas Basis Differential Forward Curve - Dominion South ($0.44) - ($1.39) $ (0.80 ) $ (2,079 ) Natural Gas Basis Differential Forward Curve - Texas Gas ($0.12) - ($0.13) $ (0.12 ) $ (30 ) As of December 31, 2014 Range (price per Mcf) Weighted Average (price per Mcf) Fair Value (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 September 30, 2015 Using: ($ in Thousands) Total Carrying Value as of September 30, 2015 Quoted Prices in Active Markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) Commodity Derivatives $ 36,755 $ — $ 38,864 $ (2,109 ) 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 nine months ended September 30, 2015 and 2014: Nine Months Ended September 30, ($ in Thousands) 2015 2014 Beginning Balance of Level 3 $ 1,341 $ 4,323 Changes in Fair Value 371 (4,343 ) Purchases — — Settlements Received (3,821 ) 2,882 Ending Balance of Level 3 $ (2,109 ) $ 2,862
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: September 30, 2015 December 31, 2014 ($ in Thousands) Carrying Amount Fair Value Carrying Amount Fair Value 8.875% Senior Notes due 2020 $ 350,000 $ 168,000 $ 350,000 $ 311,955 6.25% Senior Notes due 2022 $ 325,000 $ 135,688 325,000 241,313 Secured Line of Credit 69,000 69,000 — — Capital Leases and Other Obligations 800 781 1,427 1,393 Total $ 744,800 $ 373,469 $ 676,427 $ 554,661

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
Income Taxes (Tables)	Sep. 30, 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 September 30, Nine Months Ended September 30, ($ in Thousands) 2015 2014 2015 2014 Income (Expense) Benefit $ 20,037 $ (4,069 ) $ 20,653 $ (13,839 ) Effective Tax Rate 13.4 % 42.0 % 6.4 % 38.6 %

Employee Benefit And Equity P31

Employee Benefit And Equity Plans (Tables)	9 Months Ended
Employee Benefit And Equity Plans (Tables)	Sep. 30, 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 September 30, 2015 is as follows: Outstanding Exercisable Exercise Price Number Outstanding At 9/30/15 Weighted-Average Exercise Price Number Exercisable At 9/30/15 Weighted-Average Exercise Price $ 4.05 40,000 $ 4.05 — $ — $ 4.90 40,000 $ 4.90 — $ — $ 5.04 46,041 $ 5.04 46,041 $ 5.04 $ 9.50 75,000 $ 9.50 75,000 $ 9.50 $ 9.99 129,583 $ 9.99 129,583 $ 9.99 $ 10.42 29,548 $ 10.42 29,548 $ 10.42 $ 11.87 3,500 $ 11.87 3,500 $ 11.87 $ 12.50 19,139 $ 12.50 19,139 $ 12.50 $ 13.19 50,000 $ 13.19 50,000 $ 13.19 $ 22.34 30,000 $ 22.34 30,000 $ 22.34 462,811 $ 9.76 382,811 $ 10.86
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: Nine Months Ended September 30, 2015 Year Ended December 31, 2014 Expected Dividend Yield 0.0 % 0.0 % Risk-Free Interest Rate 1.0 % 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 nine months ended September 30, 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 1,361,497 3.97 Forfeitures (561,109 ) 11.35 Vested (439,346 ) 8.33 Restricted stock awards, as of September 30, 2015 1,880,343 $ 8.49

Commitments and Contingencies (

Commitments and Contingencies (Tables)	9 Months Ended
Commitments and Contingencies (Tables)	Sep. 30, 2015
Commitments And Contingencies Disclosure [Abstract]
Lease Commitments for Each of Next Five Years	As of September 30, 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 the three and nine months ended September 30, 2015, was approximately $0.3 million and $0.7 million, respectively, and $0.3 million and $0.8 million for the three and nine months ended September 30, 2014, respectively. Lease commitments by year for each of the next five years are presented in the table below: ($ in Thousands) 2015 $ 282 2016 1,129 2017 1,143 2018 721 2019 721 Thereafter 180 Total $ 4,176
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 $ 4,680 2016 25,007 2017 39,958 2018 41,544 2019 40,548 Thereafter 500,763 Total $ 652,500
Fee for Unconventional Gas Wells	In 2012, Pennsylvania state legislators instituted a natural gas impact fee on producers of unconventional natural gas. The fee is 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 $ 35,200 $ 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 )

Earnings Per Common Share (Tabl

Earnings Per Common Share (Tables)	9 Months Ended
Earnings Per Common Share (Tables)	Sep. 30, 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 September 30, Nine Months Ended September 30, Numerator: 2015 2014 2015 2014 Net Income (Loss) From Continuing Operations $ (129,293 ) $ 5,619 $ (301,145 ) $ 22,019 Net Income From Discontinued Operations, Less Noncontrolling Interests 34,618 75 35,904 623 Less: Preferred Stock Dividends (2,415 ) — (7,245 ) — Net Income (Loss) Attributable to Common Shareholders $ (97,090 ) $ 5,694 $ (272,486 ) $ 22,642 Denominator: Weighted Average Common Shares Outstanding - Basic 53,936 53,214 53,748 53,493 Effect of Dilutive Securities: Employee Stock Options — 111 — 134 Employee Performance-Based Restricted Stock Awards — 485 — 218 Effect of Assumed Conversions of Preferred Stock — 4,181 — 1,409 Weighted Average Common Shares Outstanding - Diluted 53,936 57,991 53,748 55,254 Earnings per Common Share Attributable to Rex Energy Common Shareholders: Basic — Net Income (Loss) From Continuing Operations $ (2.44 ) $ 0.11 $ (5.74 ) $ 0.41 — Net Income From Discontinued Operations 0.64 0.00 0.67 0.01 — Net Income (Loss) Attributable to Rex Energy Common Shareholders $ (1.80 ) $ 0.11 $ (5.07 ) $ 0.42 Diluted — Net Income (Loss) From Continuing Operations $ (2.44 ) $ 0.10 $ (5.74 ) $ 0.40 — Net Income From Discontinued Operations 0.64 0.00 0.67 0.01 — Net Income (Loss) Attributable to Rex Energy Common Shareholders $ (1.80 ) $ 0.10 $ (5.07 ) $ 0.41

Condensed Consolidating Finan34

Condensed Consolidating Financial Information (Tables)	9 Months Ended
Condensed Consolidating Financial Information (Tables)	Sep. 30, 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 SEPTEMBER 30, 2015 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance ASSETS Current Assets Cash and Cash Equivalents $ 3,145 $ — $ 5 $ — $ 3,150 Accounts Receivable 29,054 37 47 — 29,138 Taxes Receivable — — 19 — 19 Short-Term Derivative Instruments 29,194 — — — 29,194 Inventory, Prepaid Expenses and Other 2,031 — 138 — 2,169 Total Current Assets 63,424 37 209 — 63,670 Property and Equipment (Successful Efforts Method) Evaluated Oil and Gas Properties 1,208,437 771 — (6,952 ) 1,202,256 Unevaluated Oil and Gas Properties 288,800 — — — 288,800 Other Property and Equipment 45,035 895 — — 45,930 Wells and Facilities in Progress 125,207 234 — (288 ) 125,153 Pipelines 16,412 — — (2,137 ) 14,275 Total Property and Equipment 1,683,891 1,900 — (9,377 ) 1,676,414 Less: Accumulated Depreciation, Depletion and Amortization (633,955 ) (860 ) — 2,838 (631,977 ) Net Property and Equipment 1,049,936 1,040 — (6,539 ) 1,044,437 Deferred Financing Costs and Other Assets—Net 2,490 — 13,781 — 16,271 Long-Term Deferred Tax Asset — — 10,648 — 10,648 Intercompany Receivables — — 1,043,565 (1,043,565 ) — Investment in Subsidiaries – Net (1,907 ) — 243,331 (241,424 ) — Long-Term Derivative Instruments 11,749 — — — 11,749 Total Assets $ 1,125,692 $ 1,077 $ 1,311,534 $ (1,291,528 ) $ 1,146,775 LIABILITIES AND STOCKHOLDERS’ EQUITY Current Liabilities Accounts Payable $ 29,551 $ — $ — $ — $ 29,551 Current Maturities of Long-Term Debt 668 — — — 668 Accrued Liabilities 35,471 152 16,341 — 51,964 Short-Term Derivative Instruments 763 — — — 763 Current Deferred Tax Liability — — 10,648 — 10,648 Total Current Liabilities 66,453 152 26,989 — 93,594 Long-Term Derivative Instruments 3,425 — — — 3,425 Senior Secured Line of Credit and Other Long-Term Debt 132 — 69,000 — 69,132 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 — — 2,442 — 2,442 Other Deposits and Liabilities 3,372 — — — 3,372 Future Abandonment Cost 40,685 60 — — 40,745 Intercompany Payables 1,043,090 475 — (1,043,565 ) — Total Liabilities 1,157,157 687 773,431 (1,043,565 ) 887,710 Stockholders’ Equity Preferred Stock — — 1 — 1 Common Stock — — 54 — 54 Additional Paid-In Capital 177,144 — 618,164 (173,063 ) 622,245 Accumulated Earnings (Deficit) (208,609 ) 390 (80,116 ) (74,900 ) (363,235 ) Total Stockholders’ Equity (31,465 ) 390 538,103 (247,963 ) 259,065 Total Liabilities and Stockholders’ Equity $ 1,125,692 $ 1,077 $ 1,311,534 $ (1,291,528 ) $ 1,146,775 REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING BALANCE SHEETS AS OF DECEMBER 31, 2014 ($ in Thousands) 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 SEPTEMBER 30, 2015 ($ in Thousands) REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2015 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance OPERATING REVENUE Oil, Natural Gas and NGL Sales $ 136,981 $ 456 $ — $ — $ 137,437 Other Revenue 30 — — — 30 TOTAL OPERATING REVENUE 137,011 456 — — 137,467 OPERATING EXPENSES Production and Lease Operating Expense 90,164 146 — — 90,310 General and Administrative Expense 18,587 45 4,875 — 23,507 Gain on Disposal of Asset (465 ) — — — (465 ) Impairment Expense 264,693 1,014 — (1,030 ) 264,677 Exploration Expense 1,972 275 — (5 ) 2,242 Depreciation, Depletion, Amortization and Accretion 83,427 133 — (772 ) 82,788 Other Operating Expense 5,304 — — — 5,304 TOTAL OPERATING EXPENSES 463,682 1,613 4,875 (1,807 ) 468,363 INCOME (LOSS) FROM OPERATIONS (326,671 ) (1,157 ) (4,875 ) 1,807 (330,896 ) OTHER INCOME (EXPENSE) Interest Expense (195 ) — (35,902 ) — (36,097 ) Gain on Derivatives, Net 44,553 — 934 — 45,487 Other Income 119 — — — 119 Loss From Equity Method Investments (411 ) — — — (411 ) Income (Loss) From Equity in Consolidated Subsidiaries (1,083 ) 1,083 (227,955 ) 227,955 — TOTAL OTHER INCOME (EXPENSE) 42,983 1,083 (262,923 ) 227,955 9,098 INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX (283,688 ) (74 ) (267,798 ) 229,762 (321,798 ) Income Tax Benefit 18,022 74 2,557 — 20,653 INCOME (LOSS) FROM CONTINUING OPERATIONS (265,666 ) — (265,241 ) 229,762 (301,145 ) Income (Loss) From Discontinued Operations, Net of Income Tax — 39,341 — (1,192 ) 38,149 Net Income (Loss) (265,666 ) 39,341 (265,241 ) 228,570 (262,996 ) Net Income (Loss) Attributable to Noncontrolling Interests of Discontinued Operations — 2,245 — — 2,245 NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY $ (265,666 ) $ 37,096 $ (265,241 ) $ 228,570 $ (265,241 ) Preferred Stock Dividends — — 7,245 — 7,245 NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS $ (265,666 ) $ 37,096 $ (272,486 ) $ 228,570 $ (272,486 ) REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS FOR THE THREE MONTHS ENDED SEPTEMBER 30, 2014 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance OPERATING REVENUE Oil, Natural Gas and NGL Sales $ 73,343 $ 105 $ — $ — $ 73,448 Other Revenue 18 — — — 18 TOTAL OPERATING REVENUE 73,361 105 — — 73,466 OPERATING EXPENSES Production and Lease Operating Expense 27,670 4 — — 27,674 General and Administrative Expense 7,709 24 1,555 — 9,288 Loss on Disposal of Asset 174 — — — 174 Impairment Expense — — — — — Exploration Expense 1,452 10 — — 1,462 Depreciation, Depletion, Amortization and Accretion 26,536 36 — (197 ) 26,375 Other Operating Expense (24 ) — — — (24 ) TOTAL OPERATING EXPENSES 63,517 74 1,555 (197 ) 64,949 INCOME (LOSS) FROM OPERATIONS 9,844 31 (1,555 ) 197 8,517 OTHER INCOME (EXPENSE) Interest Expense (56 ) — (10,890 ) — (10,946 ) Gain (Loss) on Derivatives, Net 12,316 — — — 12,316 Other Expense 3 — — — 3 Loss From Equity Method Investments (202 ) — — — (202 ) Income (Loss) From Equity in Consolidated Subsidiaries 18 (18 ) 12,840 (12,840 ) — TOTAL OTHER INCOME (EXPENSE) 12,079 (18 ) 1,950 (12,840 ) 1,171 INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX 21,923 13 395 (12,643 ) 9,688 Income Tax (Expense) Benefit (8,853 ) (515 ) 5,299 — (4,069 ) INCOME (LOSS) FROM CONTINUING OPERATIONS 13,070 (502 ) 5,694 (12,643 ) 5,619 Loss From Discontinued Operations, Net of Income Tax — 1,836 — (866 ) 970 Net Income (Loss) 13,070 1,334 5,694 (13,509 ) 6,589 Net Income Attributable to Noncontrolling Interests of Discontinued Operations — 895 — — 895 NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY $ 13,070 $ 439 $ 5,694 $ (13,509 ) $ 5,694 Preferred Stock Dividends — — — — — NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS $ 13,070 $ 439 $ 5,694 $ (13,509 ) $ 5,694 REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING STATEMENTS OF OPERATIONS FOR THE NINE MONTHS ENDED SEPTEMBER 30, 2014 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance OPERATING REVENUE Oil, Natural Gas and NGL Sales $ 227,547 $ 103 $ — $ — $ 227,650 Other Revenue 92 — — — 92 TOTAL OPERATING REVENUE 227,639 103 — — 227,742 OPERATING EXPENSES Production and Lease Operating Expense 69,328 10 — — 69,338 General and Administrative Expense 22,811 72 4,296 — 27,179 Loss on Disposal of Asset 468 — — — 468 Impairment Expense 41 — — — 41 Exploration Expense 4,877 13 — — 4,890 Depreciation, Depletion, Amortization and Accretion 66,812 109 — (467 ) 66,454 Other Operating Expense 3 — — — 3 TOTAL OPERATING EXPENSES 164,340 204 4,296 (467 ) 168,373 INCOME (LOSS) FROM OPERATIONS 63,299 (101 ) (4,296 ) 467 59,369 OTHER INCOME (EXPENSE) Interest Expense (86 ) — (25,150 ) — (25,236 ) Gain on Derivatives, Net 1,232 — 1,083 — 2,315 Other Income 20 — — — 20 Loss From Equity Method Investments (610 ) — — — (610 ) Income (Loss) From Equity in Consolidated Subsidiaries (65 ) 65 39,667 (39,667 ) — TOTAL OTHER INCOME (EXPENSE) 491 65 15,600 (39,667 ) (23,511 ) INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX 63,790 (36 ) 11,304 (39,200 ) 35,858 Income Tax (Expense) Benefit (22,964 ) (2,214 ) 11,339 — (13,839 ) INCOME (LOSS) FROM CONTINUING OPERATIONS 40,826 (2,250 ) 22,643 (39,200 ) 22,019 Income (Loss) From Discontinued Operations, Net of Income Taxes — 7,597 — (3,634 ) 3,963 NET INCOME (LOSS) 40,826 5,347 22,643 (42,834 ) 25,982 Net Income Attributable to Noncontrolling Interests — 3,340 — — 3,340 NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY $ 40,826 $ 2,007 $ 22,643 $ (42,834 ) $ 22,642
Condensed Consolidating Statements of Cash Flows	REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS FOR THE NINE MONTHS ENDING SEPTEMBER 30, 2015 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance CASH FLOWS FROM OPERATING ACTIVITIES Net Income (Loss) $ (265,666 ) $ 39,341 $ (265,241 ) $ 228,570 $ (262,996 ) Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities Loss From Equity Method Investments 411 — — — 411 Non-Cash Expenses (Income) (120 ) (334 ) 6,145 — 5,691 Depreciation, Depletion, Amortization and Accretion 83,427 3,205 — (3,766 ) 82,866 (Gain) on Derivatives (44,553 ) — (934 ) — (45,487 ) Cash Settlements of Derivatives 39,168 — 934 — 40,102 Dry Hole Expense 199 275 — (6 ) 468 Gain on Sale of Asset (465 ) (44 ) — — (509 ) Gain on Sale of Water Solutions — — (57,014 ) — (57,014 ) Impairment Expense 264,693 1,014 — (1,030 ) 264,677 Changes in operating assets and liabilities Accounts Receivable 14,602 (478 ) 429 (2,538 ) 12,015 Inventory, Prepaid Expenses and Other Assets 1,342 (142 ) (108 ) — 1,092 Accounts Payable and Accrued Liabilities (27,935 ) (4,816 ) 4,110 2,538 (26,103 ) Other Assets and Liabilities (1,748 ) (73 ) 27 — (1,794 ) NET CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES 63,355 37,948 (311,652 ) 223,768 13,419 CASH FLOWS FROM INVESTING ACTIVITIES Intercompany loans to subsidiaries 79,071 (38,532 ) 184,393 (224,932 ) — Proceeds from Joint Venture Acreage Management 54 — — — 54 Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets 9,557 559 66,135 — 76,251 Proceeds from Joint Venture 16,611 — — — 16,611 Acquisitions of Undeveloped Acreage (26,232 ) (279 ) — — (26,511 ) Capital Expenditures for Development of Oil and Gas Properties and Equipment (156,432 ) (7,939 ) — 1,164 (163,207 ) NET CASH PROVIDED BY (USED IN) INVESTING ACTIVITIES (77,371 ) (46,191 ) 250,528 (223,768 ) (96,802 ) CASH FLOWS FROM FINANCING ACTIVITIES Proceeds from Long-Term Debt and Lines of Credit — 35,813 151,000 — 186,813 Repayments of Long-Term Debt and Lines of Credit — (26,335 ) (82,000 ) — (108,335 ) Repayments of Loans and Other Long-Term Debt (817 ) (520 ) — — (1,337 ) Debt Issuance Costs — (3 ) (626 ) — (629 ) Dividends Paid — — (7,245 ) — (7,245 ) Distributions by the Partners of Consolidated Subsidiaries — (830 ) — — (830 ) NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES (817 ) 8,125 61,129 — 68,437 NET INCREASE (DECREASE) IN CASH (14,833 ) (118 ) 5 — (14,946 ) CASH – BEGINNING 17,978 118 — — 18,096 CASH - ENDING $ 3,145 $ — $ 5 $ — $ 3,150 REX ENERGY CORPORATION AND SUBSIDIARIES CONDENSED CONSOLIDATING STATEMENTS OF CASH FLOWS FOR THE NINE MONTHS ENDING SEPTEMBER 30, 2014 ($ in Thousands) Guarantor Subsidiaries Non-Guarantor Subsidiaries Rex Energy Corporation (Note Issuer) Eliminations Consolidated Balance CASH FLOWS FROM OPERATING ACTIVITIES Net Income (Loss) $ 40,826 $ 5,347 $ 22,643 $ (42,834 ) $ 25,982 Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities Loss From Equity Method Investments 610 — — — 610 Non-Cash Expenses (203 ) 233 5,116 — 5,146 Depreciation, Depletion, Amortization and Accretion 66,812 2,671 — (469 ) 69,014 Deferred Income Tax Expense (Benefit) 22,964 2,967 (11,339 ) — 14,592 Gain on Derivatives (1,232 ) — (1,083 ) — (2,315 ) Cash Settlements of Derivatives (4,209 ) — 878 — (3,331 ) Dry Hole Expense 237 — — — 237 (Gain) Loss on Sale of Asset 469 (84 ) — — 385 Impairment Expense 41 — — — 41 Changes in operating assets and liabilities Accounts Receivable (9,510 ) (3,455 ) 4,685 (1,574 ) (9,854 ) Inventory, Prepaid Expenses and Other Assets (812 ) (209 ) (17 ) — (1,038 ) Accounts Payable and Accrued Liabilities 22,975 (1,007 ) 12,518 1,574 36,060 Other Assets and Liabilities (1,942 ) (24 ) — — (1,966 ) NET CASH PROVIDED BY (USED IN) OPERATING ACTIVITIES 137,026 6,439 33,401 (43,303 ) 133,563 CASH FLOWS FROM INVESTING ACTIVITIES Intercompany loans to subsidiaries 408,192 248 (448,109 ) 39,669 — Proceeds from Joint Venture Acreage Management 210 — — — 210 Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets 248 164 — — 412 Acquisitions of Undeveloped Acreage (152,765 ) (863 ) — — (153,628 ) Capital Expenditures for Development of Oil and Gas Properties and Equipment (305,672 ) (8,315 ) — 3,634 (310,353 ) NET CASH USED IN INVESTING ACTIVITIES (49,787 ) (8,766 ) (448,109 ) 43,303 (463,359 ) CASH FLOWS FROM FINANCING ACTIVITIES Proceeds from Long-Term Debt and Lines of Credit — 22,041 171,000 — 193,041 Repayments of Long-Term Debt and Lines of Credit — (18,146 ) (230,000 ) — (248,146 ) Repayments of Loans and Other Notes Payable (1,323 ) (675 ) — — (1,998 ) Proceeds from Senior Notes, Net of Discounts and Premiums — — 325,000 — 325,000 Debt Issuance Costs — (7 ) (6,724 ) — (6,731 ) Proceeds from the Issuance of Preferred Stock, Net — — 155,011 — 155,011 Proceeds from Exercise of Stock Options — — 421 — 421 Distributions by the Partners of Consolidated Subsidiaries — (1,080 ) — — (1,080 ) NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES (1,323 ) 2,133 414,708 — 415,518 NET INCREASE IN CASH 85,916 (194 ) — — 85,722 CASH – BEGINNING 1,386 509 5 — 1,900 CASH - ENDING $ 87,302 $ 315 $ 5 $ — $ 87,622

Basis of Presentation and Pri35

Basis of Presentation and Principles of Consolidation - Additional Information (Details)	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 - Addit

Future Abandonment Cost - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]
Accretion expense	$ 1,100	$ 1,300	$ 3,100	$ 2,900

Future Abandonment Cost (Detail

Future Abandonment Cost (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
Future Abandonment Cost (Details) - USD ($) $ in Thousands		Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Asset Retirement Obligation Disclosure [Abstract]
Beginning Balance at January 1, 2015				$ 40,099
Future Abandonment Obligation Incurred				752
Future Abandonment Obligation Settled				(1,563)
Future Abandonment Obligation Cancelled or Sold				(119)
Future Abandonment Obligation Revision of Estimated Obligation				195
Future Abandonment Obligation Accretion Expense		$ 1,100	$ 1,300	3,100	$ 2,900
Total Future Abandonment Cost	[1]	$ 42,464		$ 42,464

[1]	Includes approximately $1.7 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 ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Asset Retirement Obligations [Line Items]
Accrued Liabilities	$ 51,964	$ 59,478
Remediation Property for Sale, Abandonment or Disposal
Asset Retirement Obligations [Line Items]
Accrued Liabilities	$ 1,700

Discontinued Operations_ Assets

Discontinued Operations/ Assets Held for Sale - Additional Information (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended
	Jul. 31, 2015	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Jun. 30, 2015	Dec. 31, 2014
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Gain on asset held for sale	$ 66,100
Gain classified as other (income) expense		$ (20)	$ (3)	$ (119)	$ (20)
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%
American Water Works Company, Inc.
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Aggregate consideration of Water Solutions						$ 130,000
Discontinued Operations Assets Held For Sale \| Water Solutions Holdings, LLC
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Gain classified as other (income) expense	$ (57,000)	$ (56,956)	$ 16	$ (56,836)	$ 50

Summary of Carrying Value of As

Summary of Carrying Value of Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2014	Sep. 30, 2014
Assets:
Cash and Cash Equivalents		$ 337
Total Current Assets	$ 34,257
Liabilities:
Total Liabilities Related to Assets Held for Sale	25,115
Water Solutions Holdings, LLC
Assets:
Cash and Cash Equivalents	118
Accounts Receivable	13,226
Inventory, Prepaid Expenses and Other	163
Total Current Assets	13,507
Other Property and Equipment, Net	19,690
Wells and Facilities in Progress	688
Intangible Assets, Net	372
Total Long-Term Assets	20,750
Total Assets Held for Sale	34,257
Liabilities:
Accounts Payable	3,694
Current Maturities of Long-Term Debt	6,236
Accrued Liabilities	6,304
Total Current Liabilities	16,234
Senior Secured Line of Credit and Long-Term Debt	8,881
Total Long-Term Liabilities	8,881
Total Liabilities Related to Assets Held for Sale	25,115
Net Assets Held for Sale	$ 9,142

Summary of Financial Informatio

Summary of Financial Information for Discontinued Operations (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended
	Jul. 31, 2015	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues:
Total Operating Revenue		$ 37,573	$ 73,466	$ 137,467	$ 227,742
Costs and Expenses:
General and Administrative Expense		5,376	9,288	23,507	27,179
Depreciation, Depletion, Amortization and Accretion		27,124	26,375	82,788	66,454
Gain on Sale of Asset		(230)	174	(465)	468
Interest Expense		11,886	10,946	36,097	25,236
Gain classified as other (income) expense		(20)	(3)	(119)	(20)
Income from Discontinued Operations, net of taxes		34,617	970	38,149	3,963
Discontinued Operations Assets Held For Sale \| Water Solutions Holdings, LLC
Revenues:
Field Services Revenue		1,479	13,071	33,086	41,462
Total Operating Revenue		1,479	13,071	33,086	41,462
Costs and Expenses:
General and Administrative Expense		82	1,086	1,961	2,825
Depreciation, Depletion, Amortization and Accretion		2	989	78	2,560
Field Services Operating Expense		1,228	9,567	25,981	30,912
Gain on Sale of Asset		(2)	(91)	(44)	(84)
Interest Expense		56	134	487	482
Gain classified as other (income) expense	$ (57,000)	(56,956)	16	(56,836)	50
Total Costs and Expenses		(55,590)	11,701	(28,373)	36,745
Income from Discontinued Operations Before Income Taxes		57,069	1,370	61,459	4,717
Income Tax Expense		(22,452)	(400)	(23,310)	(754)
Income from Discontinued Operations, net of taxes		$ 34,617	$ 970	$ 38,149	$ 3,963

Business and Oil and Gas Prop42

Business and Oil and Gas Property Acquisitions and Dispositions - Additional Information (Details) $ in Thousands	Mar. 31, 2015USD ($)Well	Jan. 31, 2016Well	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)
Business Acquisition And Dispositions [Line Items]
Payments for interest in wells that have been drilled or in process of being drilled			$ 163,207	$ 310,353
Arc Light Capital Partners Limited Liability Corporation
Business Acquisition And Dispositions [Line Items]
Percentage of estimated well costs	35.00%
Total consideration for the transaction	$ 67,000
Amount received at closing of wells	$ 16,600
Percentage of working interest	50.00%
Percentage of working interest attained through return on investment and internal rate of return	50.00%
Percentage of remaining working interest	17.50%
Payments for interest in wells that have been drilled or in process of being drilled			$ 24,900
Scenario Forecast \| Arc Light Capital Partners Limited Liability Corporation
Business Acquisition And Dispositions [Line Items]
Number of specifically designated wells for development \| Well		17
Percentage of estimated well costs		20.00%
Percentage of working interest		20.00%
Percentage of working interest attained through return on investment and internal rate of return		50.00%
Butler County, Pennsylvania \| Arc Light Capital Partners Limited Liability Corporation
Business Acquisition And Dispositions [Line Items]
Number of specifically designated wells for development \| Well	32

Recently Issued Accounting Pr43

Recently Issued Accounting Pronouncements - Additional Information (Details) $ in Millions	Sep. 30, 2015USD ($)
Accounting Policies [Abstract]
Net deferred financing costs	$ 13.8

Concentrations of Credit Risk -

Concentrations of Credit Risk - Additional Information (Details) - Sales - Customer Concentration Risk	9 Months Ended
	Sep. 30, 2015Customer
Purchaser
Concentration Risk [Line Items]
Percentage of revenue from major customers	91.70%
Number of major customers	5
Largest single purchaser
Concentration Risk [Line Items]
Percentage of revenue from major customers	44.10%

Long-Term Debt - Senior Credit

Long-Term Debt - Senior Credit Facility - Additional Information (Details) - USD ($)	9 Months Ended
	Sep. 30, 2015		Dec. 31, 2014
Debt Instrument [Line Items]
Line of credit facility, amount outstanding	$ 69,000,000	[1]	$ 0
Senior Credit Facility
Debt Instrument [Line Items]
Line of credit facility, current borrowing capacity	350,000,000
Line of credit facility, remaining borrowing capacity	$ 270,300,000
Line of credit facility, maturity date	Sep. 12, 2019
Current ratio	3.40%
Senior Credit Facility \| Minimum
Debt Instrument [Line Items]
Criteria Current ratio	1.00%
Net senior secured debt to EBITDAX	0.70%
Senior Credit Facility \| Maximum
Debt Instrument [Line Items]
Criteria of net senior secured debt to EBITDAX	3.00%
Net senior secured debt to EBITDAX	1.00%
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

[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 and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 1.8%, 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 4.2%, 5.8% and 4.0%, respectively.

Long-Term Debt - Senior Notes D

Long-Term Debt - Senior Notes Due Twenty Twenty and Senior Notes Due Twenty Twenty Two - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Senior Notes	$ 675,000	$ 675,000
Premium on Senior Notes, Net	2,442	2,442	$ 2,725
Amortization of net premium	100	$ 300
Trailing quarters fixed charge coverage ratio		2.25%
Fixed charge coverage ratio		1.73%
8.875% Senior Notes
Debt Instrument [Line Items]
Senior Notes	$ 350,000	$ 350,000	$ 350,000
Interest rate	8.875%	8.875%	8.875%
Yearly interest payments		$ 31,100
6.25% Senior Notes
Debt Instrument [Line Items]
Senior Notes	$ 325,000	$ 325,000	$ 325,000
Interest rate	6.25%	6.25%	6.25%
Yearly interest payments		$ 20,300
Maximum
Debt Instrument [Line Items]
Expected fixed charge coverage ratio for current fiscal quarter		2.25%
Expected fixed charge coverage ratio for next fiscal year		2.25%

Components of Long-Term Debt an

Components of Long-Term Debt and Lines of Credit (Details) - USD ($) $ in Thousands		Sep. 30, 2015		Dec. 31, 2014
Debt Instrument [Line Items]
Senior Notes		$ 675,000
Premium on Senior Notes, Net		2,442		$ 2,725
Senior Line of Credit		69,000	[1]	0
Capital Leases and Other Obligations	[1]	800		1,427
Total Debt		747,242		679,152
Less Current Portion of Long-Term Debt		(668)		(1,176)
Total Long-Term Debt		746,574		677,976
8.875% Senior Notes
Debt Instrument [Line Items]
Senior Notes		350,000		350,000
6.25% Senior Notes
Debt Instrument [Line Items]
Senior Notes		$ 325,000		$ 325,000

[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 and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 1.8%, 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 4.2%, 5.8% and 4.0%, respectively.

Components of Long-Term Debt 48

Components of Long-Term Debt and Lines of Credit (Parenthetical) (Details)	3 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Sep. 30, 2015	Dec. 31, 2014
Senior Credit Facility
Debt Instrument [Line Items]
Average interest rate	1.80%	1.70%	2.20%
Capital Leases and Other Obligations
Debt Instrument [Line Items]
Average interest rate	4.20%	5.80%	4.00%
8.875% Senior Notes
Debt Instrument [Line Items]
Interest rate	8.875%	8.875%	8.875%
Debt instrument maturity date		Dec. 1, 2020	Dec. 1, 2020
6.25% Senior Notes
Debt Instrument [Line Items]
Interest rate	6.25%	6.25%	6.25%
Debt instrument maturity date		Aug. 1, 2022	Aug. 1, 2022

Principal Maturity Schedule for

Principal Maturity Schedule for Debt Outstanding (Details) - USD ($) $ in Thousands	Sep. 30, 2015		Dec. 31, 2014
Debt Disclosure [Abstract]
2,015	$ 182
2,016	590
2,017	28
2,019	69,000
Thereafter	675,000
Total	$ 744,800	[1]	$ 676,427

[1]	Excludes $2.4 million net premium on Senior Notes

Principal Maturity Schedule f50

Principal Maturity Schedule for Debt Outstanding (Parenthetical) (Details) $ in Millions	Sep. 30, 2015USD ($)
Debt Disclosure [Abstract]
Senior notes, net premium	$ 2.4

Derivative Instruments and Fa51

Derivative Instruments and Fair Value Measurements - Additional Information (Details) - USD ($)	3 Months Ended			9 Months Ended
	Sep. 30, 2015		Sep. 30, 2014	Sep. 30, 2015		Sep. 30, 2014	Dec. 31, 2014
Derivatives Fair Value [Line Items]
Cash Settlements of Derivatives				$ (40,102,000)		$ 3,331,000
Senior Line of Credit	$ 69,000,000	[1]		69,000,000	[1]		$ 0
Senior Notes	675,000,000			675,000,000
Derivative interest rate outstanding	0			0			0
Derivatives asset (liability)	36,800,000			36,800,000			31,400,000
Unrealized gain (loss) on commodity derivative contracts				400,000		(4,300,000)
Impairment Expense	139,810,000			264,677,000		41,000
Other Than Temporary Impairment
Derivatives Fair Value [Line Items]
Impairment Expense				264,700,000
Crude Oil
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	$ 4,079,000			$ 4,079,000
Crude Oil \| Minimum
Derivatives Fair Value [Line Items]
Commodity hedged on annualized basis hedge through 2015	75.00%			75.00%
Commodity hedged on annualized basis hedge through 2016	18.00%			18.00%
Natural Gas
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	$ 23,350,000			$ 23,350,000
Natural Gas \| Minimum
Derivatives Fair Value [Line Items]
Commodity hedged on annualized basis hedge through 2015	85.00%			85.00%
Commodity hedged on annualized basis hedge through 2016	77.00%			77.00%
Natural Gas Liquids
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	$ 9,511,000			$ 9,511,000
Natural Gas Liquids \| Minimum
Derivatives Fair Value [Line Items]
Commodity hedged on annualized basis hedge through 2015	59.00%			59.00%
Commodity hedged on annualized basis hedge through 2016	41.00%			41.00%
Commodity derivatives
Derivatives Fair Value [Line Items]
Cash Settlements of Derivatives	$ 15,100,000		$ 3,000,000	$ 39,200,000		$ 4,200,000
Derivatives asset (liability)	36,755,000			36,755,000			$ 31,371,000
Interest Rate Swap and Swaption
Derivatives Fair Value [Line Items]
Cash Settlements of Derivatives	$ 100,000			$ 900,000

[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 and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 1.8%, 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 4.2%, 5.8% and 4.0%, respectively.

Schedule of Location and Amount

Schedule of Location and Amounts of Gains and Losses on Derivative Instruments (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Derivative Instruments Gain Loss [Line Items]
Gain on Derivatives, Net	$ 28,649	$ 12,316	$ 45,487	$ 2,315
Crude Oil
Derivative Instruments Gain Loss [Line Items]
Gain on Derivatives, Net	5,599	3,776	5,648	125
Refined Products
Derivative Instruments Gain Loss [Line Items]
Gain on Derivatives, Net	(180)		(185)
Natural Gas
Derivative Instruments Gain Loss [Line Items]
Gain on Derivatives, Net	12,013	6,857	28,649	77
Natural Gas Liquids
Derivative Instruments Gain Loss [Line Items]
Gain on Derivatives, Net	10,068	$ 1,683	10,441	1,030
Interest Rate Swap
Derivative Instruments Gain Loss [Line Items]
Gain on Derivatives, Net	$ 1,149		$ 934	$ 1,083

Asset or Liability Financial Co

Asset or Liability Financial Commodity Derivative Instrument Positions (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2015USD ($)$ / bbl$ / Mcf$ / galbblMcf	Dec. 31, 2014USD ($)
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	$ 36,800	$ 31,400
Crude Oil
Derivatives Fair Value [Line Items]
Volume \| bbl	450,000
Derivatives asset (liability)	$ 4,079
Crude Oil \| 2015 \| Collars
Derivatives Fair Value [Line Items]
Volume \| bbl	75,000
Floor \| $ / bbl	52.90
Ceiling \| $ / bbl	63.15
Derivatives asset (liability)	$ 556
Crude Oil \| 2015 \| Three Way Collars
Derivatives Fair Value [Line Items]
Volume \| bbl	150,000
Put Option \| $ / bbl	50
Floor \| $ / bbl	65
Ceiling \| $ / bbl	72.50
Derivatives asset (liability)	$ 2,102
Crude Oil \| 2016 \| Collars
Derivatives Fair Value [Line Items]
Volume \| bbl	60,000
Floor \| $ / bbl	53.75
Ceiling \| $ / bbl	63.81
Derivatives asset (liability)	$ 467
Crude Oil \| 2016 \| Three Way Collars
Derivatives Fair Value [Line Items]
Volume \| bbl	45,000
Put Option \| $ / bbl	50
Floor \| $ / bbl	65
Ceiling \| $ / bbl	70
Derivatives asset (liability)	$ 423
Crude Oil \| 2016 \| Deferred Put Spreads
Derivatives Fair Value [Line Items]
Volume \| bbl	120,000
Put Option \| $ / bbl	50
Floor \| $ / bbl	65
Derivatives asset (liability)	$ 531
Refined Product (Heating Oil)
Derivatives Fair Value [Line Items]
Volume \| bbl	12,000
Derivatives asset (liability)	$ (185)
Refined Product (Heating Oil) \| 2016 \| Swaps
Derivatives Fair Value [Line Items]
Volume \| bbl	12,000
Swap \| $ / gal	84
Derivatives asset (liability)	$ (185)
Natural Gas
Derivatives Fair Value [Line Items]
Volume \| Mcf	145,110,000
Derivatives asset (liability)	$ 23,350
Natural Gas \| Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	(2,079)	$ 1,341
Natural Gas \| Basis Swaps Texas Gas
Derivatives Fair Value [Line Items]
Derivatives asset (liability)	$ (30)
Natural Gas \| 2015 \| Three Way Collars
Derivatives Fair Value [Line Items]
Volume \| Mcf	2,200,000
Put Option \| $ / Mcf	2.84
Floor \| $ / Mcf	3.53
Ceiling \| $ / Mcf	4.25
Derivatives asset (liability)	$ 881
Natural Gas \| 2015 \| Swaps
Derivatives Fair Value [Line Items]
Volume \| Mcf	4,375,000
Swap \| $ / Mcf	3.49
Derivatives asset (liability)	$ 3,891
Natural Gas \| 2015 \| Swaptions
Derivatives Fair Value [Line Items]
Volume \| Mcf	550,000
Swap \| $ / Mcf	3.53
Derivatives asset (liability)	$ 453
Natural Gas \| 2015 \| Cap Swaps
Derivatives Fair Value [Line Items]
Volume \| Mcf	1,950,000
Put Option \| $ / Mcf	3.43
Swap \| $ / Mcf	4.12
Derivatives asset (liability)	$ 1,170
Natural Gas \| 2015 \| Put Spreads
Derivatives Fair Value [Line Items]
Volume \| Mcf	650,000
Put Option \| $ / Mcf	2.56
Floor \| $ / Mcf	3.32
Derivatives asset (liability)	$ 336
Natural Gas \| 2015 \| Calls Option
Derivatives Fair Value [Line Items]
Volume \| Mcf	750,000
Ceiling \| $ / Mcf	4.15
Natural Gas \| 2015 \| Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume \| Mcf	2,300,000
Swap \| $ / Mcf	(0.82)
Derivatives asset (liability)	$ 101
Natural Gas \| 2016 \| Collars
Derivatives Fair Value [Line Items]
Volume \| Mcf	900,000
Floor \| $ / Mcf	3.20
Ceiling \| $ / Mcf	4.04
Derivatives asset (liability)	$ 427
Natural Gas \| 2016 \| Three Way Collars
Derivatives Fair Value [Line Items]
Volume \| Mcf	19,170,000
Put Option \| $ / Mcf	2.51
Floor \| $ / Mcf	3.22
Ceiling \| $ / Mcf	3.99
Derivatives asset (liability)	$ 4,620
Natural Gas \| 2016 \| Swaps
Derivatives Fair Value [Line Items]
Volume \| Mcf	9,600,000
Swap \| $ / Mcf	3.45
Derivatives asset (liability)	$ 6,207
Natural Gas \| 2016 \| Swaptions
Derivatives Fair Value [Line Items]
Volume \| Mcf	0
Derivatives asset (liability)	$ (305)
Natural Gas \| 2016 \| Cap Swaps
Derivatives Fair Value [Line Items]
Volume \| Mcf	3,600,000
Put Option \| $ / Mcf	3.45
Swap \| $ / Mcf	4.11
Derivatives asset (liability)	$ 1,848
Natural Gas \| 2016 \| Put Spreads
Derivatives Fair Value [Line Items]
Volume \| Mcf	2,100,000
Put Option \| $ / Mcf	2.25
Floor \| $ / Mcf	3
Derivatives asset (liability)	$ 172
Natural Gas \| 2016 \| Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume \| Mcf	12,510,000
Swap \| $ / Mcf	(0.90)
Derivatives asset (liability)	$ (124)
Natural Gas \| 2017 \| Three Way Collars
Derivatives Fair Value [Line Items]
Volume \| Mcf	13,900,000
Put Option \| $ / Mcf	2.38
Floor \| $ / Mcf	3.09
Ceiling \| $ / Mcf	4.02
Derivatives asset (liability)	$ 2,670
Natural Gas \| 2017 \| Swaps
Derivatives Fair Value [Line Items]
Volume \| Mcf	960,000
Swap \| $ / Mcf	3.60
Derivatives asset (liability)	$ 614
Natural Gas \| 2017 \| Cap Swaps
Derivatives Fair Value [Line Items]
Volume \| Mcf	2,100,000
Put Option \| $ / Mcf	3.34
Swap \| $ / Mcf	4.07
Derivatives asset (liability)	$ 1,122
Natural Gas \| 2017 \| Calls Option
Derivatives Fair Value [Line Items]
Volume \| Mcf	840,000
Ceiling \| $ / Mcf	4
Derivatives asset (liability)	$ (93)
Natural Gas \| 2017 \| Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume \| Mcf	4,550,000
Swap \| $ / Mcf	(0.83)
Derivatives asset (liability)	$ (353)
Natural Gas \| 2017 \| Basis Swaps Texas Gas
Derivatives Fair Value [Line Items]
Volume \| Mcf	14,600,000
Swap \| $ / Mcf	(0.13)
Derivatives asset (liability)	$ (15)
Natural Gas \| 2018 \| Three Way Collars
Derivatives Fair Value [Line Items]
Volume \| bbl	5,475,000
Put Option \| $ / bbl	2.40
Floor \| $ / bbl	3
Ceiling \| $ / bbl	3.75
Derivatives asset (liability)	$ 296
Natural Gas \| 2018 \| Swaps
Derivatives Fair Value [Line Items]
Volume \| Mcf	960,000
Swap \| $ / Mcf	3.60
Derivatives asset (liability)	$ 614
Natural Gas \| 2018 \| Cap Swaps
Derivatives Fair Value [Line Items]
Volume \| Mcf	1,800,000
Put Option \| $ / Mcf	3.30
Swap \| $ / Mcf	4.05
Derivatives asset (liability)	$ 975
Natural Gas \| 2018 \| Calls Option
Derivatives Fair Value [Line Items]
Volume \| bbl	3,650,000
Ceiling \| $ / bbl	4.25
Derivatives asset (liability)	$ (439)
Natural Gas \| 2018 \| Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume \| Mcf	6,400,000
Swap \| $ / Mcf	(0.83)
Derivatives asset (liability)	$ (515)
Natural Gas \| 2018 \| Basis Swaps Texas Gas
Derivatives Fair Value [Line Items]
Volume \| Mcf	14,600,000
Swap \| $ / Mcf	(0.13)
Derivatives asset (liability)	$ (15)
Natural Gas \| 2019 \| Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume \| Mcf	7,300,000
Swap \| $ / Mcf	(0.83)
Derivatives asset (liability)	$ (592)
Natural Gas \| 2020 \| Basis Swaps Dominion South
Derivatives Fair Value [Line Items]
Volume \| Mcf	7,320,000
Swap \| $ / Mcf	(0.83)
Derivatives asset (liability)	$ (596)
Natural Gas Liquids
Derivatives Fair Value [Line Items]
Volume \| bbl	1,992,600
Derivatives asset (liability)	$ 9,511
Natural Gas Liquids \| 2015 \| C3+ NGL Swaps
Derivatives Fair Value [Line Items]
Volume \| bbl	387,000
Swap \| $ / bbl	31.92
Derivatives asset (liability)	$ 2,642
Natural Gas Liquids \| 2015 \| Ethane Swaps
Derivatives Fair Value [Line Items]
Volume \| bbl	102,600
Swap \| $ / bbl	8.40
Derivatives asset (liability)	$ 5
Natural Gas Liquids \| 2016 \| C3+ NGL Swaps
Derivatives Fair Value [Line Items]
Volume \| bbl	1,131,000
Swap \| $ / bbl	32.76
Derivatives asset (liability)	$ 6,848
Natural Gas Liquids \| 2016 \| Ethane Swaps
Derivatives Fair Value [Line Items]
Volume \| bbl	240,000
Swap \| $ / bbl	8.82
Derivatives asset (liability)	$ 54
Natural Gas Liquids \| 2017 \| C3+ NGL Swaps
Derivatives Fair Value [Line Items]
Volume \| bbl	132,000
Swap \| $ / bbl	19.74
Derivatives asset (liability)	$ (38)

Combined Fair Value of Derivati

Combined Fair Value of Derivatives (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	$ 29,194	$ 29,265
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	11,749	4,904
Total Derivative Assets	40,943	34,169
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	(763)	(421)
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	(3,425)	(2,377)
Total Derivative Liabilities	(4,188)	(2,798)
Crude Oil \| Deferred Put Spreads
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	398	1,413
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	133
Crude Oil \| Call Protected Swaps
Short-Term Derivative Assets:
Total Short-Term Derivative Assets		1,227
Crude Oil \| Three Way Collars
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	2,384	4,596
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	141
Crude Oil \| Collars
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	1,023
Refined Product (Heating Oil) \| Swaps
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	(139)
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	(46)
Natural Gas Liquids \| Swaps
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	7,847	6,181
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	1,790
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	(84)
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	(42)
Natural Gas \| Three Way Collars
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	4,427	5,081
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	4,040	1,733
Natural Gas \| Collars
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	427
Natural Gas \| Swaps
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	8,462	4,522
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	2,864	1,554
Natural Gas \| Cap Swaps
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	2,628	3,430
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	2,487	1,617
Natural Gas \| Basis Swaps
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	661	2,815
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	269
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	(539)
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	(2,500)	(1,281)
Natural Gas \| Swaptions
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	454
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities	(1)	(154)
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	(305)
Natural Gas \| Put Spreads
Short-Term Derivative Assets:
Total Short-Term Derivative Assets	483
Long-Term Derivative Assets:
Total Long-Term Derivative Assets	25
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities		(193)
Natural Gas \| Calls Option
Short-Term Derivative Liabilities:
Total Short - Term Derivative Liabilities		(74)
Long-Term Derivative Liabilities:
Total Long-Term Derivative Liabilities	$ (532)	$ (1,096)

Significant Unobservable Inputs

Significant Unobservable Inputs Used in Fair Value Measurements of Natural Gas Basis Swaps (Details) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2015USD ($)$ / Mcf	Dec. 31, 2014USD ($)$ / Mcf
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Derivatives asset (liability) \| $	$ 36,800	$ 31,400
Natural Gas
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Derivatives asset (liability) \| $	$ 23,350
Natural Gas \| Basis Swaps Dominion South
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Weighted Average (price per Mcf)	(0.80)	(0.84)
Derivatives asset (liability) \| $	$ (2,079)	$ 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)	(0.44)	(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)	(1.39)	(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)	(0.12)
Derivatives asset (liability) \| $	$ (30)
Natural Gas \| Basis Swaps Texas Gas \| Minimum
Fair Value Assets Measured On Recurring Basis Unobservable Input Reconciliation [Line Items]
Range (price per Mcf)	(0.12)
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 ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivatives asset (liability)	$ 36,800	$ 31,400
Commodity derivatives
Fair Value Assets And Liabilities Measured On Recurring And Nonrecurring Basis [Line Items]
Derivatives asset (liability)	36,755	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)	38,864	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)	$ (2,109)	$ 1,341

Reconciliation of Commodity Der

Reconciliation of Commodity Derivative Contracts Measured at Fair Value on Recurring Basis Using Significant Unobservable Inputs (Level 3) (Details) - Commodity derivatives - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
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	371	(4,343)
Settlements Received	(3,821)	2,882
Ending Balance of Level 3	$ (2,109)	$ 2,862

Financial Instruments Not Recor

Financial Instruments Not Recorded at Fair Value (Details) - USD ($) $ in Thousands		Sep. 30, 2015		Dec. 31, 2014
Derivatives Fair Value [Line Items]
Senior Notes		$ 675,000
Senior Line of Credit		69,000	[1]	$ 0
Capital Leases and Other Obligations	[1]	800		1,427
Total		744,800	[2]	676,427
Fair Value
Derivatives Fair Value [Line Items]
Secured Line of Credit		69,000
Capital Leases and Other Obligations		781		1,393
Total		373,469		554,661
8.875% Senior Notes
Derivatives Fair Value [Line Items]
Senior Notes		350,000		350,000
8.875% Senior Notes \| Fair Value
Derivatives Fair Value [Line Items]
Senior Notes		168,000		311,955
6.25% Senior Notes
Derivatives Fair Value [Line Items]
Senior Notes		325,000		325,000
6.25% Senior Notes \| Fair Value
Derivatives Fair Value [Line Items]
Senior Notes		$ 135,688		$ 241,313

[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 and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 1.8%, 1.7% and 2.2%, respectively. The average interest rate on our capital leases and other obligations for the three and nine months ended September 30, 2015 and the year ended December 31, 2014, was approximately 4.2%, 5.8% and 4.0%, respectively.
[2]	Excludes $2.4 million net premium on Senior Notes

Financial Instruments Not Rec59

Financial Instruments Not Recorded at Fair Value (Parenthetical) (Detail)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
8.875% Senior Notes
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	8.875%	8.875%
Due date	2,020	2,020
8.875% Senior Notes \| Carrying Amount
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	8.875%	8.875%
Due date	2,020	2,020
8.875% Senior Notes \| Fair Value
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	8.875%	8.875%
Due date	2,020	2,020
6.25% Senior Notes
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	6.25%	6.25%
Due date	2,022	2,022
6.25% Senior Notes \| Carrying Amount
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	6.25%	6.25%
Due date	2,022	2,022
6.25% Senior Notes \| Fair Value
Derivatives Fair Value [Line Items]
Senior Notes, interest rate	6.25%	6.25%
Due date	2,022	2,022

Schedule of Income Tax Included

Schedule of Income Tax Included in Continuing Operations (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Income Tax Disclosure [Abstract]
Income Tax (Expense) Benefit	$ 20,037	$ (4,069)	$ 20,653	$ (13,839)
Effective Tax Rate	13.40%	42.00%	6.40%	38.60%

Income Taxes - Additional Infor

Income Taxes - Additional Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Income Tax Disclosure [Abstract]
Statutory rate	35.00%	35.00%
Income tax refunds	$ 0.5	$ 4.7

Capital Stock - Additional Info

Capital Stock - Additional Information (Details) - USD ($) $ / shares in Units, $ in Thousands	Aug. 18, 2014	Aug. 31, 2015	May. 31, 2015	Feb. 28, 2015	Sep. 30, 2015	Sep. 30, 2014	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					54,975,151		54,174,763
Common Stock, shares outstanding					54,975,151		54,174,763
Preferred Stock, shares issued					16,100		16,100
Preferred Stock, par value					$ 0.001		$ 0.001
Proceeds from the Issuance of Preferred Stock, Net						$ 155,011
6.0% convertible perpetual preferred stock, Series A
Schedule Of Capitalization Equity [Line Items]
Preferred Stock, shares issued	16,100
Preferred Stock, par value	$ 0.001
Proceeds from the Issuance of Preferred Stock, Net	$ 155,000
Dividend per share in amount					$ 600
Dividend per share percentage					6.00%
Quarterly cash dividend paid per share		$ 150	$ 150	$ 150
Quarterly cash dividend amount paid		$ 2,400	$ 2,400	$ 2,400
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 P63

Employee Benefit and Equity Plans - Additional Information (Details)	3 Months Ended			9 Months Ended		12 Months Ended
	Sep. 30, 2015USD ($)shares	Mar. 31, 2015USD ($)shares	Sep. 30, 2014USD ($)shares	Sep. 30, 2015USD ($)EmployeesPerson$ / sharesshares	Sep. 30, 2014USD ($)Personshares	Dec. 31, 2014$ / shares
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of option issued to purchase common stock \| shares	0		0	80,000	0
Intrinsic value of stock options exercised					$ 300,000
Stock options exercised \| shares				0
Total tax benefit				$ 0	$ 0
Outstanding weighted average remaining term (in years)				2 years 2 months 12 days
Weighted average remaining term of options exercisable (in years)				3 years
Aggregate intrinsic value of options outstanding	$ 0			$ 0
Aggregate intrinsic value of options exercisable	0			0
Unrecognized compensation expense	100,000			$ 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 \| Employees				3
Restricted Stock
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Unrecognized compensation expense	$ 4,300,000			$ 4,300,000
Common stock issued by compensation committee \| shares				1,361,497	51,178
Number of employees subjected to issuance of common stock \| Person				127	18
Fair value of TSR awards of per share estimated on date of grant \| $ / shares				$ 3.97
Share-based compensation			$ 1,600,000	$ 4,800,000	$ 4,300,000
Unrecognized compensation expense weighted average period, in years				1 year 7 months 6 days
Vested stock \| shares				439,346
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 \| $ / shares				$ 2.56		$ 10.15
Restricted Stock \| Certain Performance Factors Waived
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Vested stock \| shares		189,872
Restricted Stock \| Director
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of employees subjected to issuance of common stock \| Person				1

Summary of Issued and Outstandi

Summary of Issued and Outstanding Stock Options (Details)	Sep. 30, 2015$ / sharesshares
Share Based Compensation Shares Authorized Under Stock Option Plans Exercise Price Range [Line Items]
Number Outstanding \| shares	462,811
Weighted-Average Exercise Price, Outstanding	$ 9.76
Number Exercisable \| shares	382,811
Weighted-Average Exercise Price, Exercisable	$ 10.86
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 \| shares	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 \| shares	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 \| shares	46,041
Weighted-Average Exercise Price, Outstanding	$ 5.04
Number Exercisable \| shares	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 \| shares	75,000
Weighted-Average Exercise Price, Outstanding	$ 9.50
Number Exercisable \| shares	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 \| shares	129,583
Weighted-Average Exercise Price, Outstanding	$ 9.99
Number Exercisable \| shares	129,583
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 \| shares	29,548
Weighted-Average Exercise Price, Outstanding	$ 10.42
Number Exercisable \| shares	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 \| shares	3,500
Weighted-Average Exercise Price, Outstanding	$ 11.87
Number Exercisable \| shares	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 \| shares	19,139
Weighted-Average Exercise Price, Outstanding	$ 12.50
Number Exercisable \| shares	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 \| shares	50,000
Weighted-Average Exercise Price, Outstanding	$ 13.19
Number Exercisable \| shares	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 \| shares	30,000
Weighted-Average Exercise Price, Outstanding	$ 22.34
Number Exercisable \| shares	30,000
Weighted-Average Exercise Price, Exercisable	$ 22.34

Monte Carlo Simulation Model As

Monte Carlo Simulation Model Assumptions Used to Estimate Fair Value of Restricted Stock (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 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
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Expected Volatility Rate Minimum	29.80%	28.40%
Expected Volatility Rate Maximum	85.00%	65.70%

Summary of Nonvested Stock Acti

Summary of Nonvested Stock Activity (Details) - Restricted Stock - $ / shares	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
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	1,361,497	51,178
Forfeitures, Number of Shares	(561,109)
Vested, Number of Shares	(439,346)
Stock awards, ending balance, Number of Shares	1,880,343
Stock awards, beginning balance, Weighted Average Grant Date Fair Value	$ 14.05
Awards, Weighted Average Grant Date Fair Value	3.97
Forfeitures, Weighted Average Grant Date Fair Value	11.35
Vested, Weighted Average Grant Date Fair Value	8.33
Stock awards, ending balance, Weighted Average Grant Date Fair Value	$ 8.49

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Details)	1 Months Ended			3 Months Ended			9 Months Ended
	Jan. 31, 2015USD ($)	May. 31, 2012Contract	Oct. 31, 2011Person	Sep. 30, 2015USD ($)Rigs	Mar. 31, 2015Rigs	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)Rigs	Sep. 30, 2014USD ($)	Dec. 31, 2014USD ($)
Loss Contingencies [Line Items]
Number of plaintiffs \| Person			2
Number of contract formation \| Contract		0
Significant probable or possible environmental contingent liabilities				$ 0			$ 0
Letters of credit				10,700,000			10,700,000
Rent expense				300,000		$ 300,000	700,000	$ 800,000
Termination fees incurred							4,800,000
Maximum guarantee of payment of obligations				425,700,000			425,700,000
Transportation, processing and marketing expenses of oil natural gas and natural gas liquids				20,900,000		15,700,000	60,300,000	36,100,000
Fees related to unutilized capacity commitments				700,000			2,800,000
Production and Lease Operating Expense				30,616,000		27,674,000	90,310,000	69,338,000
Accrued Liabilities				$ 51,964,000			$ 51,964,000		$ 59,478,000
Scenario Forecast
Loss Contingencies [Line Items]
Termination fees paid	$ 2,500,000
Capacity Reservation
Loss Contingencies [Line Items]
Estimated working interest				54.00%			54.00%
Charges incurred for unutilized processing capacity							$ 400,000
Capacity Reservation \| 2015
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed				$ 4,000,000			4,000,000
Capacity Reservation \| 2016
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed				19,800,000			19,800,000
Capacity Reservation \| 2017
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed				23,900,000			23,900,000
Capacity Reservation \| 2018
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed				23,900,000			23,900,000
Capacity Reservation \| 2019
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed				23,900,000			23,900,000
Capacity Reservation \| Thereafter
Loss Contingencies [Line Items]
Obligation for the cryogenic gas processing plant if gas is not processed				$ 165,200,000			$ 165,200,000
Drilling Commitments
Loss Contingencies [Line Items]
Number of rigs to support Appalachian Basin operations \| Rigs				1			1
Number of contracts terminated \| Rigs					2
Drilling Commitments \| 2015
Loss Contingencies [Line Items]
Minimum cost to retain drilling rigs							$ 600,000
Minimum gross cost to retain the completion services							4,100,000
Drilling Commitments \| 2016
Loss Contingencies [Line Items]
Minimum cost to retain drilling rigs							2,200,000
Minimum gross cost to retain the completion services							4,000,000
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				$ 800,000		$ 1,200,000	$ 2,300,000	$ 2,500,000
Accrued Liabilities				$ 2,500,000			$ 2,500,000

Lease Commitments for Each of N

Lease Commitments for Each of Next Five Years (Details) $ in Thousands	Sep. 30, 2015USD ($)
Commitments And Contingencies Disclosure [Abstract]
2,015	$ 282
2,016	1,129
2,017	1,143
2,018	721
2,019	721
Thereafter	180
Total	$ 4,176

Minimum Net Obligations under S

Minimum Net Obligations under Sales, Gathering and Transportation Agreements (Details) $ in Thousands	Sep. 30, 2015USD ($)
Commitments And Contingencies Disclosure [Abstract]
2,015	$ 4,680
2,016	25,007
2,017	39,958
2,018	41,544
2,019	40,548
Thereafter	500,763
Total	$ 652,500

Fee for Unconventional Gas Well

Fee for Unconventional Gas Wells (Details) - Pennsylvania Impact Fee $ in Thousands	9 Months Ended
	Sep. 30, 2015USD ($)	[1]
Less than $2.25
Unconventional Gas Wells [Line Items]
Year One	$ 40,200
Year Two	30,200
Year Three	25,200
Year 4 – 10	10,100
Year 11 – 15	5,000
$2.26 - $2.99
Unconventional Gas Wells [Line Items]
Year One	45,300
Year Two	35,200
Year Three	30,200
Year 4 – 10	15,100
Year 11 – 15	5,000
$3.00 - $4.99
Unconventional Gas Wells [Line Items]
Year One	50,300
Year Two	40,200
Year Three	30,200
Year 4 – 10	20,100
Year 11 – 15	10,100
$5.00 - $5.99
Unconventional Gas Wells [Line Items]
Year One	55,300
Year Two	45,300
Year Three	40,200
Year 4 – 10	20,100
Year 11 – 15	10,100
More than $5.99
Unconventional Gas Wells [Line Items]
Year One	60,400
Year Two	55,300
Year Three	50,300
Year 4 – 10	20,100
Year 11 – 15	$ 10,100

[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 - Add

Earnings Per Common Share - Additional Information (Details) - shares shares in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 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		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	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	1.1	0.4	1.1	0.7

Earnings Per Share - Computatio

Earnings Per Share - Computation of Basic and Diluted Earning Per Common Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Numerator:
Net Income (Loss) From Continuing Operations	$ (129,293)	$ 5,619	$ (301,145)	$ 22,019
Net Income From Discontinued Operations, Less Noncontrolling Interests	34,618	75	35,904	623
Less: Preferred Stock Dividends	(2,415)		(7,245)
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	$ (97,090)	$ 5,694	$ (272,486)	$ 22,642
Denominator:
Weighted Average Common Shares Outstanding - Basic	53,936	53,214	53,748	53,493
Effect of Dilutive Securities:
Employee Stock Options		111		134
Employee Performance-Based Restricted Stock Awards		485		218
Effect of Assumed Conversions of Preferred Stock		4,181		1,409
Weighted Average Common Shares Outstanding - Diluted	53,936	57,991	53,748	55,254
Earnings per Common Share Attributable to Rex Energy Common Shareholders:
Basic — Net Income (Loss) From Continuing Operations	$ (2.44)	$ 0.11	$ (5.74)	$ 0.41
Basic — Net Income From Discontinued Operations	0.64	0	0.67	0.01
Basic – Net Income (Loss) Attributable to Rex Energy Common Shareholders	(1.80)	0.11	(5.07)	0.42
Diluted — Net Income (Loss) From Continuing Operations	(2.44)	0.10	(5.74)	0.40
Diluted — Net Income From Discontinued Operations	0.64	0	0.67	0.01
Diluted – Net Income (Loss) Attributable to Rex Energy Common Shareholders	$ (1.80)	$ 0.10	$ (5.07)	$ 0.41

Equity Method Investments - Add

Equity Method Investments - Additional Information (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Jun. 30, 2015	Dec. 31, 2014
Schedule Of Equity Method Investments [Line Items]
Equity Method Investments					$ 0	$ 17,895,000
Impairment Expense	$ 139,810,000		$ 264,677,000	$ 41,000
Loss on Equity Method Investments		$ (202,000)	(411,000)	(610,000)
Production and Lease Operating Expense	$ 30,616,000	27,674,000	$ 90,310,000	69,338,000
RW Gathering, LLC
Schedule Of Equity Method Investments [Line Items]
Ownership percentage	40.00%		40.00%
Impairment Expense			$ 17,500,000	17,500,000
Contributions to Equity Method Investments			0	0
Loss on Equity Method Investments	$ (500,000)	(500,000)	$ (1,500,000)	(1,500,000)
Impairment charge in percentage			100.00%
Production and Lease Operating Expense	200,000	$ 200,000	$ 500,000	$ 500,000
Receivables	$ 0		$ 0			$ 0

Impairment Expense - Additional

Impairment Expense - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2015	Sep. 30, 2014
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Impairment Expense	$ 139,810	$ 264,677	$ 41
Appalachian Basin
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Undeveloped properties, cost	$ 288,800	288,800
Proved Property
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Impairment Expense		211,400
Proved Property \| Conventional Oil Properties \| Illinois Basin
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Impairment Expense		40,000
Proved Property \| Unconventional Assets \| Appalachian Basin
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Impairment Expense		170,500
Unproved Property Impairments \| Conventional Oil Properties \| Illinois Basin
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Impairment Expense		14,800
Unproved Property Impairments \| Unconventional Assets \| Appalachian Basin
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Impairment Expense		38,500
RW Gathering, LLC
Amortization Expense Per Equivalent Unit Of Production Or Per Dollar Of Gross Revenue [Line Items]
Impairment Expense		$ 17,500	$ 17,500

Exploration Expense - Additiona

Exploration Expense - Additional Information (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Exploration Expense [Line Items]
Exploration Expense	$ 807	$ 1,462	$ 2,242	$ 4,890
Geological and Geophysical Type Expenditures
Exploration Expense [Line Items]
Exploration Expense			800	3,300
Payment of Delay Rentals \| Appalachian Basin
Exploration Expense [Line Items]
Exploration Expense			1,000	$ 1,200
Dry Hole Expense For Non Operated Properties \| Illinois Basin
Exploration Expense [Line Items]
Exploration Expense			$ 400

Condensed Consolidating Finan76

Condensed Consolidating Financial Information - Additional Information (Details) $ in Millions	Sep. 30, 2015USD ($)
Condensed Financial Information Of Parent Company Only Disclosure [Abstract]
Senior Notes	$ 675

Condensed Consolidating Balance

Condensed Consolidating Balance Sheets (Details) - USD ($) $ in Thousands	Sep. 30, 2015	Jun. 30, 2015	Dec. 31, 2014	Sep. 30, 2014
Current Assets
Cash and Cash Equivalents	$ 3,150		$ 17,978	$ 87,285
Accounts Receivable	29,138		43,936
Taxes Receivable	19		504
Total Short-Term Derivative Assets	29,194		29,265
Assets Held for Sale			34,257
Inventory, Prepaid Expenses and Other	2,169		3,403
Total Current Assets	63,670		129,343
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties	1,202,256		1,079,039
Unevaluated Oil and Gas Properties	288,800		322,413
Other Property and Equipment	45,930		46,361
Wells and Facilities in Progress	125,153		127,655
Pipelines	14,275		15,657
Total Property and Equipment	1,676,414		1,591,125
Less: Accumulated Depreciation, Depletion and Amortization	(631,977)		(366,917)
Net Property and Equipment	1,044,437		1,224,208
Deferred Financing Costs and Other Assets – Net	16,271		17,070
Long-Term Deferred Tax Asset	10,648		8,301
Long-Term Derivative Instruments	11,749		4,904
Total Assets	1,146,775		1,401,721
Equity Method Investments		$ 0	17,895
Current Liabilities
Accounts Payable	29,551		53,340
Current Maturities of Long-Term Debt	668		1,176
Accrued Liabilities	51,964		59,478
Short-Term Derivative Instruments	763		421
Current Deferred Tax Liability	10,648		8,301
Liabilities Related to Assets Held for Sale			25,115
Total Current Liabilities	93,594		147,831
Long-Term Derivative Instruments	3,425		2,377
Senior Secured Line of Credit and Long-Term Debt	69,132		251
Senior Notes	675,000
Premium on Senior Notes, Net	2,442		2,725
Other Deposits and Liabilities	3,372		4,018
Future Abandonment Cost	40,745		38,146
Total Liabilities	887,710		870,348
Stockholders’ Equity
Preferred Stock	1		1
Common Stock	54		54
Additional Paid-In Capital	622,245		617,826
Accumulated Earnings (Deficit)	(363,235)		(90,749)
Rex Energy Stockholders’ Equity	259,065		527,132
Noncontrolling Interests			4,241
Total Stockholders’ Equity	259,065		531,373
Total Liabilities and Stockholders’ Equity	1,146,775		1,401,721
Eliminations
Current Assets
Assets Held for Sale			(2,537)
Total Current Assets			(2,537)
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties	(6,952)		(5,760)
Wells and Facilities in Progress	(288)		(560)
Pipelines	(2,137)		(1,898)
Total Property and Equipment	(9,377)		(8,218)
Less: Accumulated Depreciation, Depletion and Amortization	2,838		1,037
Net Property and Equipment	(6,539)		(7,181)
Intercompany Receivables	(1,043,565)		(951,025)
Investment in Subsidiaries – Net	(241,424)		(264,150)
Total Assets	(1,291,528)		(1,224,893)
Current Liabilities
Accounts Payable			(2,537)
Total Current Liabilities			(2,537)
Intercompany Payables	(1,043,565)		(951,025)
Total Liabilities	(1,043,565)		(953,562)
Stockholders’ Equity
Additional Paid-In Capital	(173,063)		(256,887)
Accumulated Earnings (Deficit)	(74,900)		(18,483)
Rex Energy Stockholders’ Equity			(275,370)
Noncontrolling Interests			4,039
Total Stockholders’ Equity	(247,963)		(271,331)
Total Liabilities and Stockholders’ Equity	(1,291,528)		(1,224,893)
Guarantor Subsidiaries
Current Assets
Cash and Cash Equivalents	3,145		17,978
Accounts Receivable	29,054		43,726
Total Short-Term Derivative Assets	29,194		29,265
Inventory, Prepaid Expenses and Other	2,031		3,374
Total Current Assets	63,424		94,343
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties	1,208,437		1,084,332
Unevaluated Oil and Gas Properties	288,800		321,708
Other Property and Equipment	45,035		45,466
Wells and Facilities in Progress	125,207		127,759
Pipelines	16,412		17,555
Total Property and Equipment	1,683,891		1,596,820
Less: Accumulated Depreciation, Depletion and Amortization	(633,955)		(367,224)
Net Property and Equipment	1,049,936		1,229,596
Deferred Financing Costs and Other Assets – Net	2,490		2,421
Investment in Subsidiaries – Net	(1,907)		4,161
Long-Term Derivative Instruments	11,749		4,904
Total Assets	1,125,692		1,353,320
Equity Method Investments			17,895
Current Liabilities
Accounts Payable	29,551		55,877
Current Maturities of Long-Term Debt	668		1,176
Accrued Liabilities	35,471		46,783
Short-Term Derivative Instruments	763		421
Total Current Liabilities	66,453		104,257
Long-Term Derivative Instruments	3,425		2,377
Senior Secured Line of Credit and Long-Term Debt	132		251
Other Deposits and Liabilities	3,372		4,018
Future Abandonment Cost	40,685		38,097
Intercompany Payables	1,043,090		947,114
Total Liabilities	1,157,157		1,096,114
Stockholders’ Equity
Additional Paid-In Capital	177,144		177,144
Accumulated Earnings (Deficit)	(208,609)		80,062
Rex Energy Stockholders’ Equity			257,206
Total Stockholders’ Equity	(31,465)		257,206
Total Liabilities and Stockholders’ Equity	1,125,692		1,353,320
Non-Guarantor Subsidiaries
Current Assets
Accounts Receivable	37		210
Assets Held for Sale			36,794
Total Current Assets	37		37,004
Property and Equipment (Successful Efforts Method)
Evaluated Oil and Gas Properties	771		467
Unevaluated Oil and Gas Properties			705
Other Property and Equipment	895		895
Wells and Facilities in Progress	234		456
Total Property and Equipment	1,900		2,523
Less: Accumulated Depreciation, Depletion and Amortization	(860)		(730)
Net Property and Equipment	1,040		1,793
Investment in Subsidiaries – Net			1,541
Total Assets	1,077		40,338
Current Liabilities
Accrued Liabilities	152		571
Liabilities Related to Assets Held for Sale			25,115
Total Current Liabilities	152		25,686
Future Abandonment Cost	60		49
Intercompany Payables	475		3,911
Total Liabilities	687		29,646
Stockholders’ Equity
Additional Paid-In Capital			79,743
Accumulated Earnings (Deficit)	390		(69,253)
Rex Energy Stockholders’ Equity			10,490
Noncontrolling Interests			202
Total Stockholders’ Equity	390		10,692
Total Liabilities and Stockholders’ Equity	1,077		40,338
Parent Company
Current Assets
Cash and Cash Equivalents	5
Accounts Receivable	47
Taxes Receivable	19		504
Inventory, Prepaid Expenses and Other	138		29
Total Current Assets	209		533
Property and Equipment (Successful Efforts Method)
Deferred Financing Costs and Other Assets – Net	13,781		14,649
Long-Term Deferred Tax Asset	10,648		8,301
Intercompany Receivables	1,043,565		951,025
Investment in Subsidiaries – Net	243,331		258,448
Total Assets	1,311,534		1,232,956
Current Liabilities
Accrued Liabilities	16,341		12,124
Current Deferred Tax Liability	10,648		8,301
Total Current Liabilities	26,989		20,425
Senior Secured Line of Credit and Long-Term Debt	69,000
Total Liabilities	773,431		698,150
Stockholders’ Equity
Preferred Stock	1		1
Common Stock	54		54
Additional Paid-In Capital	618,164		617,826
Accumulated Earnings (Deficit)	(80,116)		(83,075)
Rex Energy Stockholders’ Equity			534,806
Total Stockholders’ Equity	538,103		534,806
Total Liabilities and Stockholders’ Equity	1,311,534		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
8.875% and 6.25% Senior Notes
Current Liabilities
Premium on Senior Notes, Net	2,442		2,725
8.875% and 6.25% Senior Notes \| Parent Company
Current Liabilities
Premium on Senior Notes, Net	$ 2,442		$ 2,725

Condensed Consolidating Balan78

Condensed Consolidating Balance Sheets (Parenthetical) (Details)	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
8.875% Senior Notes
Condensed Balance Sheet Statements Captions [Line Items]
Interest rate	8.875%	8.875%
Due date	2,020	2,020
6.25% Senior Notes
Condensed Balance Sheet Statements Captions [Line Items]
Interest rate	6.25%	6.25%
Due date	2,022	2,022

Condensed Consolidating Stateme

Condensed Consolidating Statements of Operations (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
OPERATING REVENUE
Oil, Natural Gas and NGL Sales	$ 37,565	$ 73,448	$ 137,437	$ 227,650
Other Revenue	8	18	30	92
TOTAL OPERATING REVENUE	37,573	73,466	137,467	227,742
OPERATING EXPENSES
Production and Lease Operating Expense	30,616	27,674	90,310	69,338
General and Administrative Expense	5,376	9,288	23,507	27,179
(Gain) Loss on Disposal of Asset	(230)	174	(465)	468
Impairment Expense	139,810		264,677	41
Exploration Expense	807	1,462	2,242	4,890
Depreciation, Depletion, Amortization and Accretion	27,124	26,375	82,788	66,454
Other Operating Expense (Income)	183	(24)	5,304	3
TOTAL OPERATING EXPENSES	203,686	64,949	468,363	168,373
INCOME (LOSS) FROM OPERATIONS	(166,113)	8,517	(330,896)	59,369
OTHER INCOME (EXPENSE)
Interest Expense	(11,886)	(10,946)	(36,097)	(25,236)
Gain on Derivatives, Net	28,649	12,316	45,487	2,315
Other Income	20	3	119	20
Loss on Equity Method Investments		(202)	(411)	(610)
TOTAL OTHER INCOME (EXPENSE)	16,783	1,171	9,098	(23,511)
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX	(149,330)	9,688	(321,798)	35,858
Income Tax (Expense) Benefit	20,037	(4,069)	20,653	(13,839)
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	(129,293)	5,619	(301,145)	22,019
Income (Loss) From Discontinued Operations, Net of Income Tax	34,617	970	38,149	3,963
NET INCOME (LOSS)	(94,676)	6,589	(262,996)	25,982
Net Income (Loss) Attributable to Noncontrolling Interests of Discontinued Operations	(1)	895	2,245	3,340
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	(94,675)	5,694	(265,241)	22,642
Preferred Stock Dividends	2,415		7,245
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	(97,090)	5,694	(272,486)	22,642
Eliminations
OPERATING EXPENSES
Impairment Expense	(1,030)		(1,030)
Exploration Expense			(5)
Depreciation, Depletion, Amortization and Accretion	(273)	(197)	(772)	(467)
TOTAL OPERATING EXPENSES	(1,303)	(197)	(1,807)	(467)
INCOME (LOSS) FROM OPERATIONS	1,303	197	1,807	467
OTHER INCOME (EXPENSE)
Income (Loss) From Equity in Consolidated Subsidiaries	86,517	(12,840)	227,955	(39,667)
TOTAL OTHER INCOME (EXPENSE)	86,517	(12,840)	227,955	(39,667)
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX	87,820	(12,643)	229,762	(39,200)
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	87,820	(12,643)	229,762	(39,200)
Income (Loss) From Discontinued Operations, Net of Income Tax	60	(866)	(1,192)	(3,634)
NET INCOME (LOSS)	87,880	(13,509)	228,570	(42,834)
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	87,880	(13,509)	228,570	(42,834)
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	87,880	(13,509)	228,570
Guarantor Subsidiaries
OPERATING REVENUE
Oil, Natural Gas and NGL Sales	37,429	73,343	136,981	227,547
Other Revenue	8	18	30	92
TOTAL OPERATING REVENUE	37,437	73,361	137,011	227,639
OPERATING EXPENSES
Production and Lease Operating Expense	30,565	27,670	90,164	69,328
General and Administrative Expense	5,434	7,709	18,587	22,811
(Gain) Loss on Disposal of Asset	(230)	174	(465)	468
Impairment Expense	139,837		264,693	41
Exploration Expense	628	1,452	1,972	4,877
Depreciation, Depletion, Amortization and Accretion	27,370	26,536	83,427	66,812
Other Operating Expense (Income)	183	(24)	5,304	3
TOTAL OPERATING EXPENSES	203,787	63,517	463,682	164,340
INCOME (LOSS) FROM OPERATIONS	(166,350)	9,844	(326,671)	63,299
OTHER INCOME (EXPENSE)
Interest Expense	(53)	(56)	(195)	(86)
Gain on Derivatives, Net	27,499	12,316	44,553	1,232
Other Income	20	3	119	20
Loss on Equity Method Investments		(202)	(411)	(610)
Income (Loss) From Equity in Consolidated Subsidiaries	(1,063)	18	(1,083)	(65)
TOTAL OTHER INCOME (EXPENSE)	26,403	12,079	42,983	491
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX	(139,947)	21,923	(283,688)	63,790
Income Tax (Expense) Benefit	17,510	(8,853)	18,022	(22,964)
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	(122,437)	13,070	(265,666)	40,826
NET INCOME (LOSS)	(122,437)	13,070	(265,666)	40,826
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	(122,437)	13,070	(265,666)	40,826
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	(122,437)	13,070	(265,666)
Non-Guarantor Subsidiaries
OPERATING REVENUE
Oil, Natural Gas and NGL Sales	136	105	456	103
TOTAL OPERATING REVENUE	136	105	456	103
OPERATING EXPENSES
Production and Lease Operating Expense	51	4	146	10
General and Administrative Expense	12	24	45	72
Impairment Expense	1,003		1,014
Exploration Expense	179	10	275	13
Depreciation, Depletion, Amortization and Accretion	27	36	133	109
TOTAL OPERATING EXPENSES	1,272	74	1,613	204
INCOME (LOSS) FROM OPERATIONS	(1,136)	31	(1,157)	(101)
OTHER INCOME (EXPENSE)
Income (Loss) From Equity in Consolidated Subsidiaries	1,063	(18)	1,083	65
TOTAL OTHER INCOME (EXPENSE)	1,063	(18)	1,083	65
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX	(73)	13	(74)	(36)
Income Tax (Expense) Benefit	74	(515)	74	(2,214)
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	1	(502)		(2,250)
Income (Loss) From Discontinued Operations, Net of Income Tax	34,557	1,836	39,341	7,597
NET INCOME (LOSS)	34,558	1,334	39,341	5,347
Net Income (Loss) Attributable to Noncontrolling Interests of Discontinued Operations	(1)	895	2,245	3,340
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	34,559	439	37,096	2,007
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	34,559	439	37,096
Parent Company
OPERATING EXPENSES
General and Administrative Expense	(70)	1,555	4,875	4,296
TOTAL OPERATING EXPENSES	(70)	1,555	4,875	4,296
INCOME (LOSS) FROM OPERATIONS	70	(1,555)	(4,875)	(4,296)
OTHER INCOME (EXPENSE)
Interest Expense	(11,833)	(10,890)	(35,902)	(25,150)
Gain on Derivatives, Net	1,150		934	1,083
Income (Loss) From Equity in Consolidated Subsidiaries	(86,517)	12,840	(227,955)	39,667
TOTAL OTHER INCOME (EXPENSE)	(97,200)	1,950	(262,923)	15,600
INCOME (LOSS) FROM CONTINUING OPERATIONS BEFORE INCOME TAX	(97,130)	395	(267,798)	11,304
Income Tax (Expense) Benefit	2,453	5,299	2,557	11,339
NET INCOME (LOSS) FROM CONTINUING OPERATIONS	(94,677)	5,694	(265,241)	22,643
NET INCOME (LOSS)	(94,677)	5,694	(265,241)	22,643
NET INCOME (LOSS) ATTRIBUTABLE TO REX ENERGY	(94,677)	5,694	(265,241)	$ 22,643
Preferred Stock Dividends	2,415		7,245
NET INCOME (LOSS) ATTRIBUTABLE TO COMMON SHAREHOLDERS	$ (97,092)	$ 5,694	$ (272,486)

Condensed Consolidating State80

Condensed Consolidating Statements of Cash Flows (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	$ (94,676)	$ 6,589	$ (262,996)	$ 25,982
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Loss from Equity Method Investments		202	411	610
Non-cash Expenses			5,691	5,146
Depreciation, Depletion, Amortization and Accretion			82,866	69,014
Deferred Income Tax Expense (Benefit)				14,592
Gain on Derivatives	(28,649)	(12,316)	(45,487)	(2,315)
Cash Settlements of Derivatives			40,102	(3,331)
Dry Hole Expense			468	237
Gain on Sale of Asset			(509)	385
Gain on Sale of Water Solutions			(57,014)
Impairment Expense	139,810		264,677	41
Changes in operating assets and liabilities
Accounts Receivable			12,015	(9,854)
Inventory, Prepaid Expenses and Other Assets			1,092	(1,038)
Accounts Payable and Accrued Liabilities			(26,103)	36,060
Other Assets and Liabilities			(1,794)	(1,966)
NET CASH PROVIDED BY OPERATING ACTIVITIES			13,419	133,563
CASH FLOWS FROM INVESTING ACTIVITIES
Proceeds from Joint Venture Acreage Management			54	210
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets			76,251	412
Proceeds from Joint Venture			16,611
Acquisitions of Undeveloped Acreage			(26,511)	(153,628)
Capital Expenditures for Development of Oil & Gas Properties and Equipment			(163,207)	(310,353)
NET CASH USED IN INVESTING ACTIVITIES			(96,802)	(463,359)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from Long-Term Debt and Line of Credit			186,813	193,041
Repayments of Long-Term Debt and Line of Credit			(108,335)	(248,146)
Repayments of Loans and Other Notes Payable			(1,337)	(1,998)
Proceeds from Senior Notes, Net of Discounts and Premiums				325,000
Debt Issuance Costs			(629)	(6,731)
Proceeds from the Issuance of Preferred Stock, Net				155,011
Dividends Paid			(7,245)
Proceeds from the Exercise of Stock Options				421
Distributions by the Partners of Consolidated Joint Ventures			(830)	(1,080)
NET CASH PROVIDED BY FINANCING ACTIVITIES			68,437	415,518
NET INCREASE (DECREASE) IN CASH			(14,946)	85,722
CASH – BEGINNING			18,096	1,900
CASH – ENDING	3,150	87,622	3,150	87,622
Eliminations
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	87,880	(13,509)	228,570	(42,834)
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Depreciation, Depletion, Amortization and Accretion			(3,766)	(469)
Dry Hole Expense			(6)
Impairment Expense	(1,030)		(1,030)
Changes in operating assets and liabilities
Accounts Receivable			(2,538)	(1,574)
Accounts Payable and Accrued Liabilities			2,538	1,574
NET CASH PROVIDED BY OPERATING ACTIVITIES			223,768	(43,303)
CASH FLOWS FROM INVESTING ACTIVITIES
Intercompany loans to subsidiaries			(224,932)	39,669
Capital Expenditures for Development of Oil & Gas Properties and Equipment			1,164	3,634
NET CASH USED IN INVESTING ACTIVITIES			(223,768)	43,303
Guarantor Subsidiaries
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	(122,437)	13,070	(265,666)	40,826
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Loss from Equity Method Investments		202	411	610
Non-cash Expenses			(120)	(203)
Depreciation, Depletion, Amortization and Accretion			83,427	66,812
Deferred Income Tax Expense (Benefit)				22,964
Gain on Derivatives	(27,499)	(12,316)	(44,553)	(1,232)
Cash Settlements of Derivatives			39,168	(4,209)
Dry Hole Expense			199	237
Gain on Sale of Asset			(465)	469
Impairment Expense	139,837		264,693	41
Changes in operating assets and liabilities
Accounts Receivable			14,602	(9,510)
Inventory, Prepaid Expenses and Other Assets			1,342	(812)
Accounts Payable and Accrued Liabilities			(27,935)	22,975
Other Assets and Liabilities			(1,748)	(1,942)
NET CASH PROVIDED BY OPERATING ACTIVITIES			63,355	137,026
CASH FLOWS FROM INVESTING ACTIVITIES
Intercompany loans to subsidiaries			79,071	408,192
Proceeds from Joint Venture Acreage Management			54	210
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets			9,557	248
Proceeds from Joint Venture			16,611
Acquisitions of Undeveloped Acreage			(26,232)	(152,765)
Capital Expenditures for Development of Oil & Gas Properties and Equipment			(156,432)	(305,672)
NET CASH USED IN INVESTING ACTIVITIES			(77,371)	(49,787)
CASH FLOWS FROM FINANCING ACTIVITIES
Repayments of Loans and Other Notes Payable			(817)	(1,323)
NET CASH PROVIDED BY FINANCING ACTIVITIES			(817)	(1,323)
NET INCREASE (DECREASE) IN CASH			(14,833)	85,916
CASH – BEGINNING			17,978	1,386
CASH – ENDING	3,145	87,302	3,145	87,302
Non-Guarantor Subsidiaries
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	34,558	1,334	39,341	5,347
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Non-cash Expenses			(334)	233
Depreciation, Depletion, Amortization and Accretion			3,205	2,671
Deferred Income Tax Expense (Benefit)				2,967
Dry Hole Expense			275
Gain on Sale of Asset			(44)	(84)
Impairment Expense	1,003		1,014
Changes in operating assets and liabilities
Accounts Receivable			(478)	(3,455)
Inventory, Prepaid Expenses and Other Assets			(142)	(209)
Accounts Payable and Accrued Liabilities			(4,816)	(1,007)
Other Assets and Liabilities			(73)	(24)
NET CASH PROVIDED BY OPERATING ACTIVITIES			37,948	6,439
CASH FLOWS FROM INVESTING ACTIVITIES
Intercompany loans to subsidiaries			(38,532)	248
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets			559	164
Acquisitions of Undeveloped Acreage			(279)	(863)
Capital Expenditures for Development of Oil & Gas Properties and Equipment			(7,939)	(8,315)
NET CASH USED IN INVESTING ACTIVITIES			(46,191)	(8,766)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from Long-Term Debt and Line of Credit			35,813	22,041
Repayments of Long-Term Debt and Line of Credit			(26,335)	(18,146)
Repayments of Loans and Other Notes Payable			(520)	(675)
Debt Issuance Costs			(3)	(7)
Distributions by the Partners of Consolidated Joint Ventures			(830)	(1,080)
NET CASH PROVIDED BY FINANCING ACTIVITIES			8,125	2,133
NET INCREASE (DECREASE) IN CASH			(118)	(194)
CASH – BEGINNING			118	509
CASH – ENDING		315		315
Parent Company
CASH FLOWS FROM OPERATING ACTIVITIES
Net Income (Loss)	(94,677)	5,694	(265,241)	22,643
Adjustments to Reconcile Net Income (Loss) to Net Cash Provided by Operating Activities
Non-cash Expenses			6,145	5,116
Deferred Income Tax Expense (Benefit)				(11,339)
Gain on Derivatives	(1,150)		(934)	(1,083)
Cash Settlements of Derivatives			934	878
Gain on Sale of Water Solutions			(57,014)
Changes in operating assets and liabilities
Accounts Receivable			429	4,685
Inventory, Prepaid Expenses and Other Assets			(108)	(17)
Accounts Payable and Accrued Liabilities			4,110	12,518
Other Assets and Liabilities			27
NET CASH PROVIDED BY OPERATING ACTIVITIES			(311,652)	33,401
CASH FLOWS FROM INVESTING ACTIVITIES
Intercompany loans to subsidiaries			184,393	(448,109)
Proceeds from the Sale of Oil and Gas Properties, Prospects and Other Assets			66,135
NET CASH USED IN INVESTING ACTIVITIES			250,528	(448,109)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from Long-Term Debt and Line of Credit			151,000	171,000
Repayments of Long-Term Debt and Line of Credit			(82,000)	(230,000)
Proceeds from Senior Notes, Net of Discounts and Premiums				325,000
Debt Issuance Costs			(626)	(6,724)
Proceeds from the Issuance of Preferred Stock, Net				155,011
Dividends Paid			(7,245)
Proceeds from the Exercise of Stock Options				421
NET CASH PROVIDED BY FINANCING ACTIVITIES			61,129	414,708
NET INCREASE (DECREASE) IN CASH			5
CASH – BEGINNING				5
CASH – ENDING	$ 5	$ 5	$ 5	$ 5