Alta Mesa 10-Q 14 Aug 15 2015 Q2 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - Jun. 30, 2015 - shares	Total
Document And Entity Information [Abstract]
Entity Registrant Name	Alta Mesa Holdings, LP
Entity Central Index Key	1,518,403
Document Type	10-Q
Document Period End Date	Jun. 30, 2015
Amendment Flag	false
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding	0

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
CURRENT ASSETS
Cash and cash equivalents	$ 8,529	$ 1,349
Short-term restricted cash	105	23,793
Accounts receivable, net of allowance of $1,292 and $1,449, respectively	37,139	43,581
Other receivables	5,787	8,238
Receivable due from affiliate	2,838	25,500
Prepaid expenses and other current assets	12,280	2,132
Derivative financial instruments	20,609	59,803
Total current assets	87,287	164,396
PROPERTY AND EQUIPMENT
Oil and natural gas properties, successful efforts method, net	620,896	686,176
Other property and equipment, net	10,892	11,505
Total property and equipment, net	631,788	697,681
OTHER ASSETS
Long-term restricted cash		900
Investment in LLC - cost	9,000	9,000
Deferred financing costs, net	10,880	8,100
Notes receivable due from affiliate	8,847	8,500
Advances to operators	245	619
Deposits and other assets	1,134	1,124
Derivative financial instruments	19,672	27,271
Total other assets	49,778	55,514
TOTAL ASSETS	768,853	917,591
CURRENT LIABILITIES
Accounts payable and accrued liabilities	87,015	117,560
Current portion, asset retirement obligations	710	1,136
Total current liabilities	87,725	118,696
LONG-TERM LIABILITIES
Asset retirement obligations, net of current portion	62,504	61,736
Long-term debt	792,429	767,608
Notes payable to founder	25,139	24,540
Derivative financial instruments	64
Other long-term liabilities	14,968	6,457
Total long-term liabilities	895,104	860,341
TOTAL LIABILITIES	$ 982,829	$ 979,037
Commitments and Contingencies (Note 10)
PARTNERS' DEFICIT	$ (213,976)	$ (61,446)
TOTAL LIABILITIES AND PARTNERS' DEFICIT	$ 768,853	$ 917,591

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Consolidated Balance Sheets [Abstract]
Allowance for doubtful accounts	$ 1,292	$ 1,449

Consolidated Statements Of Oper

Consolidated Statements Of Operations - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
OPERATING REVENUES AND OTHER
Oil	$ 60,212	$ 92,586	$ 109,644	$ 172,328
Natural gas	8,181	17,855	16,422	36,540
Natural gas liquids	3,141	4,924	5,817	9,866
Other revenues	221	225	414	288
Total operating revenues	71,755	115,590	132,297	219,022
Gain (loss) on sale of assets	25	(4,607)	159	68,551
Gain (loss) - oil and natural gas derivative contracts	(15,160)	(24,729)	11,599	(35,428)
Total operating revenues and other	56,620	86,254	144,055	252,145
OPERATING EXPENSES
Lease and plant operating expense	15,494	17,528	33,888	36,582
Production and ad valorem taxes	4,264	6,952	8,537	14,628
Workover expense	(67)	2,198	3,255	4,963
Exploration expense	5,833	18,757	30,341	28,236
Depreciation, depletion, and amortization expense	38,247	33,198	78,972	62,477
Impairment expense	4,311	18,300	77,361	19,202
Accretion expense	456	613	1,000	1,171
General and administrative expense	11,963	13,894	29,659	38,611
Total operating expenses	80,501	111,440	263,013	205,870
INCOME (LOSS) FROM OPERATIONS	(23,881)	(25,186)	(118,958)	46,275
OTHER INCOME (EXPENSE)
Interest expense	(15,306)	(13,632)	(29,615)	(27,920)
Interest income	254	6	429	9
Total other income (expense)	(15,052)	(13,626)	(29,186)	(27,911)
INCOME (LOSS) BEFORE STATE INCOME TAXES	(38,933)	(38,812)	(148,144)	18,364
(Provision) for state income taxes	(576)		(576)	(283)
NET INCOME (LOSS)	$ (39,509)	$ (38,812)	$ (148,720)	$ 18,081

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014
CASH FLOWS FROM OPERATING ACTIVITIES:
Net income (loss)	$ (148,720)	$ 18,081
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion, and amortization expense	78,972	62,477
Impairment expense	77,361	19,202
Accretion expense	1,000	1,171
Amortization of loan costs	1,513	1,433
Amortization of debt discount	255	255
Dry hole expense	18,994	20,120
Expired leases	517	359
(Gain) loss - oil and natural gas derivative contracts	(11,599)	35,428
Settlements on derivative contracts	58,456	(4,561)
Interest converted into debt	599	600
Interest on notes receivable	(347)
(Gain) on sale of assets	(159)	(68,551)
Changes in assets and liabilities:
Accounts receivable	6,442	(8,747)
Other receivables	2,450	1,519
Receivable due from affiliate	22,662
Prepaid expenses and other non-current assets	(9,784)	3,345
Settlement of asset retirement obligation	(1,275)	(1,617)
Accounts payable, accrued liabilities, and other long-term liabilities	10,598	8,153
NET CASH PROVIDED BY OPERATING ACTIVITIES	107,935	88,667
CASH FLOWS FROM INVESTING ACTIVITIES:
Capital expenditures for property and equipment	(141,806)	(165,165)
Proceeds from sale of property		168,097
Investment in restricted cash related to property divestitures	24,588
NET CASH (USED IN) PROVIDED BY INVESTING ACTIVITIES	(117,218)	2,932
CASH FLOWS FROM FINANCING ACTIVITIES:
Proceeds from long-term debt	185,500	79,500
Repayments of long-term debt	(160,934)	(169,270)
Additions to deferred financing costs	(4,293)
Capital distributions	(3,810)
NET CASH PROVIDED BY (USED IN) FINANCING ACTIVITIES	16,463	(89,770)
NET INCREASE IN CASH AND CASH EQUIVALENTS	7,180	1,829
CASH AND CASH EQUIVALENTS, beginning of period	1,349	6,537
CASH AND CASH EQUIVALENTS, end of period	8,529	8,366
SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION
Cash paid during the period for interest	26,435	24,964
Cash paid (received) during the period for state taxes	750	(125)
Change in asset retirement obligations	110	2,838
Change in accruals or liabilities for capital expenditures	$ (32,115)	$ 11,642

Description Of Business

Description Of Business	6 Months Ended
	Jun. 30, 2015
Description Of Business [Abstract]
Description Of Business	1. DESCRIPTION OF BUSINESS Alta Mesa Holdings, LP and its subsidiaries (“we,” “us,” “our,” the “Company,” and “Alta Mesa”) is an independent energy company engaged primarily in the acquisition, exploration, development, and production of onshore oil and natural gas properties. Our core properties are located primarily in Oklahoma, Louisiana, and Texas.

Summary Of Significant Accounti

Summary Of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2015
Summary Of Significant Accounting Policies [Abstract]
Summary Of Significant Accounting Policies	2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES The Company has provided a discussion of significant accounting policies in Note 2 in its Annual Report on Form 10-K for the year ended December 31, 2014 (the “2014 Annual Report”). There have been no changes to the Company’s significant accounting policies since December 31, 2014. Principles of Consolidation and Reporting The consolidated financial statements reflect our accounts after elimination of all significant intercompany transactions and balances. The financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our annual consolidated financial statements for the year ended December 31, 2014, which were filed with the Securities and Exchange Commission in our 2014 Annual Report. The consolidated financial statements included herein as of June 30, 2015 , and for the three and six months ended June 30, 2015 and 2014 , are unaudited, and in the opinion of management, the information furnished reflects all material adjustments, consisting of normal recurring adjustments, necessary for a fair presentation of consolidated financial position and of the results of operations for the interim periods presented. The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the U.S. (“GAAP”) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete fin ancial statements. Certain reclassifications of prior period consolidated financial statements have been made to conform to current reporting practices. The Company reclassified $25.5 million of other receivables as of December 31, 2014 to receivables due from affiliate to conform to current reporting presentation on the consolidated balance sheets. The $25.5 million was paid subsequent to year-end on January 2, 2015. The reclassifications had no impact on net income (loss) or partners’ (deficit). The consolidated results of operations for interim periods are not necessarily indicative of results to be expected for a full year. Use of Estimates The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Reserve estimates significantly impact depreciation, depletion and amortization expense and potential impairments of oil and natural gas properties and are subject to change based on changes in oil and natural gas prices and trends and changes in estimated reserve quantities. We analyze estimates, including those related to oil and natural gas reserves, oil and natural gas revenues, the value of oil and natural gas properties, bad debts, asset retirement obligations, derivative contracts, and contingencies and litigation. We base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances. Actual results may differ from these estimates. Recent Accounting Pronouncements In March 2015, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2015-03, Simplifying the Presentation of Debt Issuance Costs. The amendments in this update require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this update. The guidance is effective for interim periods and annual periods beginning after December 15, 2015; however early adoption is permitted. The adoption of this guidance will not have a material impact on its financial position, results of operations or cash flows. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers . The update provides guidance concerning the recognition and measurement of revenue from contracts with customers. ASU 2014-09 is effective for annual and interim periods beginning after December 15, 2016. The standard is required to be adopted using either the full retrospective approach, with all prior periods presented adjusted, or the modified retrospective approach, with a cumulative adjustment to retained earnings on the opening balance sheet. In April 2015, the FASB proposed to delay the effective date one year, beginning in fiscal year 2018. The proposal will be subject to the FASB’s due process requirement, which includes a period for public comments. We are currently evaluating the impact of adopting this standard on our consolidated financial statements.

Significant Divestiture

Significant Divestiture	6 Months Ended
	Jun. 30, 2015
Acquisition and Divestiture [Abstract]
Significant Divestitures	3. SIGNIFICANT DIVESTITURES Eagleville Divestiture On March 25, 2014 we closed the sale of certain of our properties located primarily in Karnes County, Texas to Memorial Production Operating LLC, comprising a portion of our Eagleville field (“Eagleville divestiture”). The properties sold included a working interest in all of our producing wells as of the effective date of January 1, 2014 . We retained a net profits interest in these wells based on 50% of our original working interest in 2014, declining to 30% in 2015, 15% in 2016, and zero in 2017. Also included in the sale was a 30% undivided interest in all our Eagleville mineral leases and interests, and 30% of our working interest in all our wells in progress on December 31, 2013 or drilled after January 1, 2014. The Company received cash consideration of approximately $171 million after customary closing adjustments. We estimate the proved developed and undeveloped reserves sold were approximately 7.5 MMBOE, and we retained proved reserves of approximately 7.7 MMBOE, 67% of which were proved undeveloped as of December 31, 2014. We recorded a gain on sale from the Eagleville divestiture of $72.5 million during 2014, based on an allocation of basis between the properties sold and properties retained. The portion of Eagleville field sold contributed approximately $6.6 million in pre-tax profit in the first quarter of 2014 .

Property And Equipment

Property And Equipment	6 Months Ended
	Jun. 30, 2015
Property And Equipment [Abstract]
Property And Equipment	4. PROPERTY AND EQUIPMENT Property and equipment consists of the following: June 30, December 31, 2015 2014 (in thousands) (unaudited) OIL AND NATURAL GAS PROPERTIES Unproved properties $ $ Accumulated impairment Unproved properties, net Proved oil and natural gas properties Accumulated depreciation, depletion, amortization and impairment Proved oil and natural gas properties, net TOTAL OIL AND NATURAL GAS PROPERTIES, net LAND OTHER PROPERTY AND EQUIPMENT Office furniture and equipment, vehicles Accumulated depreciation OTHER PROPERTY AND EQUIPMENT, net TOTAL PROPERTY AND EQUIPMENT, net $ $

Fair Value Disclosures

Fair Value Disclosures	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Fair Value Disclosures	5. FAIR VALUE DISCLOSURES We follow the guidance of ASC 820, “Fair Value Measurements and Disclosures,” in the estimation of fair values. ASC 820 provides a hierarchy of fair value measurements, based on the inputs to the fair value estimation process. It requires disclosure of fair values classified according to defined “levels,” which are based on the reliability of the evidence used to determine fair value, with Level 1 being the most reliable and Level 3 the least reliable. Level 1 evidence consists of observable inputs, such as quoted prices in an active market. Level 2 inputs typically correlate the fair value of the asset or liability to a similar, but not identical item which is actively traded. Level 3 inputs include at least some unobservable inputs, such as valuation models developed using the best information available in the circumstances. The fair value of cash, accounts receivable, other current assets, and current liabilities approximate book value due to their short-term nature. The estimate of fair value of long-term debt under our senior secured revolving credit facility is not considered to be materially different from carrying value due to market rates of interest. The fair value of the notes payable to our founder is not practicable to determine because the transactions cannot be assumed to have been consummated at arm’s length, the terms are not deemed to be market terms, there are no quoted values available for this instrument, and an independent valuation would not be practicable due to the lack of data regarding similar instruments, if any, and the associated potential costs. Our senior notes are carried at historical cost, net of amortized discount; we estimate the fair value of the senior notes for disclosure purposes. We have estimated the fair value of our $450 million senior notes payable to be $331.9 million at June 30, 2015. This estimation is based on the most recent trading values of the notes at or near the reporting dates, which is a Level 1 determination. See Note 8 for information on long-term debt. We utilize the modified Black-Scholes and the Turnbull Wakeman option pricing models to estimate the fair values of oil and natural gas derivative contracts. Inputs to these models include observable inputs from the New York Mercantile Exchange (“NYMEX”) for futures contracts, and inputs derived from NYMEX observable inputs, such as implied volatility of oil and natural gas prices. We have classified the fair values of all our oil and natural gas derivative contracts as Level 2. Oil and natural gas properties are subject to impairment testing and potential impairment write down. Oil and natural gas properties with a carrying amount of $280.2 million were written down to their fair value of $202.8 million, resulting in an impairment charge of $77.4 million for the six months ended June 30, 2015 . Oil and natural gas properties with a carrying amount of $60.3 million were written down to their fair value of $41.1 million, resulting in an impairment charge of $19.2 million for the six months ended June 30, 2014 . Oil and natural gas properties with a carrying amount of $8.2 million were written down to their fair value of $3.9 million, resulting in an impairment charge of $4.3 million for the three months ended June 30, 2015 . For the three months ended June 30, 2014 , oil and natural gas properties with a carrying amount of $59.1 million were written down to their fair value of $40.8 million, resulting in an impairment charge of $18.3 million. Significant Level 3 assumptions used in the calculation of estimated discounted cash flows in the impairment analysis included our estimate of future oil and natural gas prices, production costs, development expenditures, estimated timing of production of proved reserves, appropriate risk-adjusted discount rates, and other relevant data. New additions to asset retirement obligations result from estimations for new properties, and fair values for them are categorized as Level 3. Such estimations are based on present value techniques that utilize company-specific information for such inputs as cost and timing of plugging and abandonment of wells and facilities. We recorded $0.7 million and $0.4 million in additions to asset retirement obligations measured at fair value during the six months ended June 30, 2015 and 2014 respectively . The following table presents information about our financial assets and liabilities measured at fair value on a recurring basis as of June 30, 2015 and December 31, 2014, and indicates the fair value hierarchy of the valuation techniques we utilized to determine such fair value: Level 1 Level 2 Level 3 Total (in thousands) At June 30, 2015 (unaudited): Financial Assets: Derivative contracts for oil and natural gas — $ — $ Financial Liabilities: Derivative contracts for oil and natural gas — $ — $ At December 31, 2014: Financial Assets: Derivative contracts for oil and natural gas — $ — $ Financial Liabilities: Derivative contracts for oil and natural gas — $ — $ The amounts above are presented on a gross basis; presentation on our consolidated balance sheets utilizes netting of assets and liabilities with the same counterparty where master netting agreements are in place. For additional information on derivative contracts, see Note 6.

Derivative Financial Instrument

Derivative Financial Instruments	6 Months Ended
	Jun. 30, 2015
Derivative Financial Instruments [Abstract]
Derivative Financial Instruments	6. DERIVATIVE FINANCIAL INSTRUMENTS We account for our derivative contracts under the provisions of ASC 815, “Derivatives and Hedging.” We have entered into forward-swap contracts and collar contracts to reduce our exposure to price risk in the spot market for oil and natural gas. We also have utilized financial basis swap contracts, which address the price differential between market-wide benchmark prices and other benchmark pricing referenced in certain of our crude oil and natural gas sales contracts. Substantially all of our hedging agreements are executed by affiliates of our lenders under the credit facility described in Note 8, and are collateralized by the security interests of the respective affiliated lenders in certain of our assets under the credit facility. The contracts settle monthly and are scheduled to coincide with either oil production equivalent to barrels (Bbl) per month or gas production equivalent to volumes in millions of British thermal units (MMbtu) per month. The contracts represent agreements between us and the counter-parties to exchange cash based on a designated price, or in the case of financial basis hedging contracts, based on a designated price differential between various benchmark prices. Cash settlement occurs monthly. No derivative contracts have been entered into for trading or speculative purposes. We have not designated any of our derivative contracts as fair value or cash flow hedges; accordingly we use mark-to-market accounting, recognizing changes in the fair value of derivative contracts in the consolidated statement of operations at each reporting date. Derivative contracts are subject to master netting arrangements and are presented on a net basis in the consolidated balance sheets. This netting can cause derivative assets to be ultimately presented in a (liability) account on the consolidated balance sheets. Likewise, derivative (liabilities) could be presented in an asset account. The following table summarizes the fair value (see Note 5 for further discussion of fair value) and classification of our derivative instruments, none of which have been designated as hedging instruments under ASC 815. Fair Values of Derivative Contracts Net Fair Gross Gross amounts Value of Assets June 30, 2015 Fair Value offset against assets presented in Balance sheet location of Assets in the Balance Sheet the Balance Sheet (in thousands) (unaudited) Derivative financial instruments, current assets $ $ $ Derivative financial instruments, long-term assets Total $ $ $ Net Fair Gross Gross amounts Value of Liabilities June 30, 2015 Fair Value offset against liabilities presented in Balance sheet location of Liabilities in the Balance Sheet the Balance Sheet (in thousands) (unaudited) Derivative financial instruments, current liabilities $ $ $ — Derivative financial instruments, long-term liabilities Total $ $ $ Net Fair Gross Gross amounts Value of Assets December 31, 2014 Fair Value offset against assets presented in Balance sheet location of Assets in the Balance Sheet the Balance Sheet (in thousands) Derivative financial instruments, current assets $ $ $ Derivative financial instruments, long-term assets Total $ $ $ Net Fair Gross Gross amounts Value of Liabilities December 31, 2014 Fair Value offset against liabilities presented in Balance sheet location of Liabilities in the Balance Sheet the Balance Sheet (in thousands) Derivative financial instruments, current liabilities $ $ $ — Derivative financial instruments, long-term liabilities — Total $ $ $ — The following table summarizes the effect of our derivative instruments in the consolidated statements of operations: Derivatives not Three Months Ended Six Months Ended designated as hedging Location of June 30, June 30, instruments under ASC 815 Gain (Loss) 2015 2014 2015 2014 (in thousands) (unaudited) Oil commodity contracts Gain (loss) — oil and natural gas derivative contracts $ $ $ $ Natural gas commodity contracts Gain (loss) — oil and natural gas derivative contracts Total gains (losses) from derivatives not designated as hedges $ $ $ $ Although our counterparties provide no collateral, the master derivative agreements with each counterparty effectively allow us, so long as we are not a defaulting party, after a default or the occurrence of a termination event, to set-off an unpaid hedging agreement receivable against the interest of the counterparty in any outstanding balance under the credit facility. If a counterparty were to default in payment of an obligation under the master derivative agreements, we could be exposed to commodity price fluctuations, and the protection intended by the hedge could be lost. The value of our derivative financial instruments would be impacted. We had the following open derivative contracts for crude oil at June 30, 2015 (unaudited) : OIL DERIVATIVE CONTRACTS Volume Weighted Range Period and Type of Contract in Bbls Average High Low 2015 Price Swap Contracts $ $ $ Collar Contracts Short Call Options Long Put Options Short Put Options 2016 Price Swap Contracts Collar Contracts Short Call Options Long Put Options Short Put Options 2017 Collar Contracts Short Call Options Long Put Options Short Put Options 2018 Collar Contracts Short Call Options Long Put Options Short Put Options 2019 Collar Contracts Short Call Options Long Put Options Short Put Options We had the following open derivative contracts for natural gas at June 30, 2015 (unaudited) : NATURAL GAS DERIVATIVE CONTRACTS Volume in Weighted Range Period and Type of Contract MMBtu Average High Low 2015 Price Swap Contracts $ $ $ Collar Contracts Long Put Options Short Put Options 2017 Collar Contracts Short Call Options Long Put Options Short Put Options 2018 Collar Contracts Short Call Options Long Put Options Short Put Options In those instances where contracts are identical as to time period, volume and strike price, and counterparty, but opposite as to direction (long and short), the volumes and average prices have been netted in the two tables above. Prices stated in the table above for oil may settle against either the NYMEX or Brent ICE indices or may reflect a mix of positions settling on these two indices.

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2015
Asset Retirement Obligations [Abstract]
Asset Retirement Obligations	7. ASSET RETIREMENT OBLIGATIONS A summary of the changes in asset retirement obligations is included in the table below: Six Months Ended June 30, 2015 (in thousands) (unaudited) Balance, beginning of year $ Liabilities incurred Liabilities settled Revisions to estimates Accretion expense Balance, June 30, 2015 Less: Current portion Long-term portion $ The total revisions include $0.6 million related to reduction to oil and natural gas properties.

Long-Term Debt And Notes Payabl

Long-Term Debt And Notes Payable To Founder	6 Months Ended
	Jun. 30, 2015
Long-Term Debt And Notes Payable To Founder [Abstract]
Long-Term Debt And Notes Payable To Founder	8. LONG-TERM DEBT AND NOTES PAYABLE TO FOUNDER Long-term debt and notes payable to founder consists of the following: June 30, December 31, 2015 2014 (in thousands) (unaudited) Credit Facility $ $ Senior Secured Term Loan — Senior Notes , net of discount Total long-term debt $ $ Notes payable to founder $ $ Credit Facility. On June 2, 2015, we entered into an Agreement and Amendment No. 11 (the “Eleventh Amendment”) to Sixth Amended and Restated Credit Agreement, dated as of May 13, 2010 (as amended, the “credit facility”), with Wells Fargo Bank, National Association, as administrative agent, and the lenders signatory thereto. The Eleventh Amendment, among other things, (i) redetermined and decreased the borrowing base from $375 million to $300 million, and (ii) extended the maturity date of the credit facility to October 13, 2017 . The credit facility is secured by substantially all of our oil and natural gas properties and is based on our proved reserves and the value attributed to those reserves. The credit facility borrowing base is redetermined periodically semi-annually in May and November. The credit facility bears interest at LIBOR plus applicable margins between 2.00% and 2.75% or a “Reference Rate,” which is based on the prime rate of Wells Fargo Bank, N. A., plus a margin ranging from 1.00% to 1.75% , depending on the utilization of our borrowing base. The weighted average rate on outstanding borrowings was 2.50% as of June 30, 2015 and 2.89% as of December 31, 2014. The letters of credit outstanding as of June 30, 2015 were $0.9 million. The credit facility contains customary covenants including, among others, defined financial covenants, including minimum working capital levels (the ratio of current assets plus the unused borrowing base, to current liabilities, excluding assets and liabilities related to derivative contracts) of 1.0 to 1.0, minimum coverage of interest expenses of 3.0 to 1.0, and maximum leverage of 4.00 to 1.00. The interest coverage and leverage ratios refer to the ratio of earnings before interest, taxes, depreciation, depletion, amortization, and exploration expense (“EBITDAX”, as defined more specifically in the credit agreement) to interest expense and to total debt (as defined), respectively. Financial ratios are calculated quarterly using EBITDAX for the most recent twelve months. As of June 30, 2015 , we were in compliance with all covenants of the cred it facility. Senior Secured Term Loan. On June 2, 2015, we entered into a second lien Senior Secured Term Loan Agreement (the “Term Loan Facility”) with Morgan Stanley Energy Capital Inc . , as administrative agent, and the lenders party thereto, pursuant to which we borrowed $125 million. The Term Loan Facility includes an accordion feature which allows us to borrow up to an additional $50 million of additional term loans under the Term Loan Facility within one year following the closing, subject to certain conditions. The net proceeds of approximately $121 million from the Term Loan Facility, after payment of transaction-related fees and expenses, were used to pay down our outstanding amounts under our existing credit facility. The Term Loan Facility matures on April 15, 2018 . Borrowings under the Term Loan Facility bear interest at adjusted LIBOR plus 8% . The covenants in the Term Loan Facility require, among other things, maintenance of certain ratios, measured on a quarterly basis, as follows: (i) current assets to current liabilities of at least 1.0 to 1.0, (ii) debt to EBITDAX of no more than 4.5 to 1.0, (iii) PV-9 of total proved reserves to total secured debt of at least 1.5 to 1.0, and (iv) EBITDAX to interest expense of at least 2.5 to 1.0. Obligations under the Term Loan Facility are guaranteed by certain of the Company’s subsidiaries and affiliates and is secured by second priority liens on substantially all of our and our subsidiaries assets that serve as collateral under the credit facility. As of June 30, 2015, we were in compliance with all covenants of the Term Loan Facility. We have the option to prepay all or a portion of the Term Loan Facility at any time. The Term Loan Facility is subject to mandatory prepayments of 75% of the net cash proceeds from asset sales, subject to a limited right to reinvest proceeds in capital expenditures, or an initial public offering. Such prepayments are subject to a premium of between 3% declining to 1% prior to the maturity date, and, if made prior to the first anniversary of the closing date, are also subject to a make whole premium to ensure that the lenders receive the total amount of interest that would have been paid from the date of prepayment to such first anniversary. Senior Notes. We have $450 million in outstanding registered senior notes due October 15, 2018 that carry a stated interest rate of 9.625% and an effective rate of 9.7825% . Interest is payable semi-annually each April 15th and October 15th . The senior notes are unsecured and are general obligations of the Company, and effectively rank junior to any of our existing or future secured indebtedness, which includes the credit facility and the Term Loan Facility. The senior notes are unconditionally guaranteed on a senior unsecured basis by each of our material subsidiaries. The balance is presented net of unamortized discount of $1.7 million and $1.9 million at June 30, 2015 and December 31, 2014, respectively. The senior notes contain an optional redemption provision that began on October 15, 2014 allowing us to retire the principal outstanding, in whole or in part, at 104.813% . Additional optional redemption provisions allow for retirement at 102.406% and 100.0% beginning on each of October 15, 2015 and 2016, respectively. Notes Payable to Founder. We have notes payable to our founder that bear simple interest at 10% with a balance of $25.1 million and $24.5 million at June 30, 2015 and December 31, 2014, respectively. The maturity date was extended from December 31, 2018 to December 31, 2021 on March 25, 2014. Interest and principal are payable at maturity. The notes are convertible into shares of our Class B partner, High Mesa, Inc. (“High Mesa”), common stock upon certain conditions in the event of an initial public offering. These founder notes are unsecured and subordinate to all debt. In connection with the March 25, 2014 recapitalization of our Class B partner described in Note 12, the founder notes were amended and restated to subordinate them to the paid in kind (“PIK”) notes of our Class B partner. The founder notes were also subordinated to the rights of the holders of Class B units to receive distributions under our amended partnership agreement and subordinated to the rights of the holders of Series B Preferred Stock to receive payments. Interest on the notes payable to our founder amounted to $0.6 m illion for each of the six months ended June 30, 2015 and 2014 and $0.3 million for each of the three months ended June 30, 2015 and 2014. Such amounts have been added to the balance of the founder notes.

Accounts Payable And Accrued Li

Accounts Payable And Accrued Liabilities	6 Months Ended
	Jun. 30, 2015
Accounts Payable And Accrued Liabilities [Abstract]
Accounts Payable And Accrued Liabilities	9. ACCOUNTS PAYABLE AND ACCRUED LIABILITIES The following provides the detail of accounts payable and accrued liabilities: June 30, December 31, 2015 2014 (in thousands) (unaudited) Capital expenditures $ $ Revenues and royalties payable Operating expenses/taxes Interest Compensation Other Total accrued liabilities Accounts payable Accounts payable and accrued liabilities $ $

Commitments And Contingencies

Commitments And Contingencies	6 Months Ended
	Jun. 30, 2015
Commitments And Contingencies [Abstract]
Commitments And Contingencies	10. COMMITMENTS AND CONTINGENCIES Contingencies Environmental claims : Various landowners have sued the Company and/or our wholly owned subsidiaries, in lawsuits concerning several fields in which we have or historically had operations in Louisiana. The lawsuits seek injunctive relief and other relief, including unspecified amounts in both actual and punitive damages for alleged breaches of mineral leases and alleged failure to restore the plaintiffs’ lands from alleged contamination and otherwise from our oil and natural gas operations. We are unable to express an opinion with respect to the likelihood of an unfavorable outcome of the various environmental claims or to estimate the amount or range of potential loss should the outcome be unfavorable. Therefore, we have not provided any material amounts for these claims in our consolidated financial statements at June 30, 2015 . Due to the nature of our business, some contamination of the real estate property owned or leased by us is possible. Environmental site assessments of the property would be necessary to adequately determine remediation costs, if any. Management has established a liability for soil contamination in Florida of $1.2 million and $1.1 million at June 30, 2015 and December 31, 2014, respectively, based on our undiscounted engineering estimates. The obligations are included in other long-term liabilities in the accompanying consolidated balance sheets. Title/lease disputes : Title and lease disputes may arise in the normal course of our operations. These disputes are usually small but could result in an increase or decrease in reserves and/or other forms of settlement, such as cash, once a final resolution to the title dispute is made. Litigation: On April 13, 2005, Henry Sarpy and several other plaintiffs filed a petition against Exxon, Extex, The Meridian Resource Company (“TMRC” our wholly-owned subsidiary), and the State of Louisiana for contamination of their land in the New Sarpy and/or Good Hope Field in St. Charles Parish. Petitioners claim they are owners of land upon which oil field waste pits containing dangerous and contaminating substances are located. Plaintiffs alleged that they discovered in May 2004 that their property is contaminated with oil field wastes greater than represented by Exxon. The property was originally owned by Exxon and was sold to TMRC. TMRC subsequently sold the property to Extex. We have been defending this ongoing case and investigating the scope of the Plaintiffs’ alleged damage. On April 14, 2015, TMRC entered into a Memorandum of Understanding with Exxon to settle the claims in this ongoing matter. On July 10, 2015, the settlement and comprised agreements were finalized and signed by the Plaintiffs’ and Exxon. On July 28, 2015, the State of Louisiana issued a letter of no objection to the settlement. As of June 30, 2015 , we have accrued approximately $5.0 million as the outcome of the litigation was deemed probable and estimable. Other contingencies : We are subject to legal proceedings, claims and liabilities arising in the ordinary course of business for which the outcome cannot be reasonably estimated; however, in the opinion of management, such litigation and claims will be resolved without material adverse effect on our financial position, results of operations or cash flows. Accruals for losses associated with litigation are made when losses are deemed probable and can be reasonably estimated. Performance appreciation rights: In the third quarter of 2014, we adopted the Alta Mesa Holdings, LP Amended and Restated Performance Appreciation Rights Plan (the “Plan”), effective September 24, 2014. The Plan is intended to provide incentive compensation to key employees and consultants who make significant contributions to the Company. Under the Plan, participants are granted Performance Appreciation Rights (“PARs”) with a stipulated initial value. The PARs vest over time (as specified in each grant, typically five years) and entitle the owner to receive a cash amount equal to the increase, if any, between the initial stipulated value and the designated value of the PAR on the payment valuation date. The payment valuation date is the earlier of a liquidity event (as defined in the Plan, but generally intended to be either a recapitalization or an initial public offering of Company equity) or as selected by the participant, but no earlier than five years from the end of the year of the grant. Both the initial designated value and the designated payment value of the PAR are determined by the Plan’s administrative committee, composed of members of our board of directors. In the case of a liquidity event, the designated value of all PARs is to be based on the net sale proceeds (as defined in the Plan) from the liquidity event. After any payment valuation date, regardless of payment or none, vested PARs expire. During the first six months of 2015, no new PARs were granted and 27,500 PARs were terminated, resulting in 244,000 outstanding PARs. We are unable to express an opinion with respect to the likelihood of a qualifying liquidity event which would result in any payment under the Plan or to estimate any amount which may become payable under the Plan. We consider the possibility of payment at a fixed determination date absent a positive liquidity event to be remote. Therefore, we have not provided any amount for this contingent liability in our consolidated financial statements at June 30, 2015 or December 31, 2014.

Significant Risks And Uncertain

Significant Risks And Uncertainties	6 Months Ended
	Jun. 30, 2015
Significant Risks And Uncertainties [Abstract]
Significant Risks And Uncertainties	11. SIGNIFICANT RISKS AND UNCERTAINTIES Our business makes us vulnerable to changes in wellhead prices of crude oil and natural gas. Historically, world-wide oil and natural gas prices and markets have been volatile, and may continue to be volatile in the future. In particular, the prices of oil and natural gas were highly volatile in 2014 and declined dramatically in the second half of 2014 and remain depressed as of June 30, 2015 . Continued depressed oil and natural gas prices, further price declines or any other unfavorable market conditions could have a material adverse effect on our financial condition and on the carrying value of our proved reserves. Sustained low oil or natural gas prices may require us to further write down the value of our oil and natural gas properties and/or revise our development plans, which may cause certain of our undeveloped well locations to no longer be deemed proved. As a result of the depressed commodity prices and in order to preserve our liquidity, we have reduced our budgeted capital expenditures for 2015. Low prices may also reduce our cash available for distribution, acquisitions and for servicing our indebtedness. We mitigate some of this vulnerability by entering into oil and natural gas price derivative contracts. See Note 6.

Partners' Capital (Deficit)

Partners' Capital (Deficit)	6 Months Ended
	Jun. 30, 2015
Partners' Capital (Deficit) [Abstract]
Partners' Capital (Deficit)	12. PARTNERS’ CAPITAL (DEFICIT) Management and Control: Our business and affairs are managed by Alta Mesa Holdings GP, LLC, our general partner (“General Partner”). With certain exceptions, the General Partner may not be removed except for the reasons of “cause,” which are defined in the Partnership Agreement. Our partnership agreement provides for two classes of limited partners. Class A partners include our founder and other parties. Our Class B partner is High Mesa Inc. (“High Mesa”). The Class B limited partner has certain approval rights, generally over capital plans and significant transactions in the areas of finance, acquisition, and divestiture. Ownership of High Mesa is distributed among two classes of equity. Highbridge Principal Strategies LLC (“Highbridge”) owns all of the convertible PIK preferred stock of High Mesa. The common stock of High Mesa is owned by our Class A partners. Highbridge also holds senior PIK notes issued by High Mesa. Distribution and Income Allocation: In connection with the recapitalization on March 25, 2014, our partnership agreement was amended and restated to provide, among other things, that all distributions under the partnership agreement shall first be made to holders of Class B Units, until all principal and interest has been extinguished under the senior PIK notes issued by High Mesa to Highbridge. After such extinguishment of the senior PIK notes, distributions shall then be made to holders of Class A and Class B Units pursuant to the distribution formulas set forth in the amended partnership agreement. The Class B Partner may require the General Partner to make distributions; however, any distribution must be permitted under the terms of our credit facility, Term Loan Facility, and our senior notes. Distribution of net cash flow from a Liquidity Event is distributed to the Class A and Class B Partners according to a variable formula as defined in the Partnership Agreement. A “Liquidity Event” is any event in which we receive cash proceeds outside the ordinary course of our business. The Class B Partner can, without consent of any other partners, request that the General Partner take action to cause us, or our assets, to be sold to one or more third parties. For the six months ended June 30, 2015, we made distributions to High Mesa of approximately $3.8 million.

Subsidiary Guarantors

Subsidiary Guarantors	6 Months Ended
	Jun. 30, 2015
Subsidiary Guarantors [Abstract]
Subsidiary Guarantors	13. SUBSIDIARY GUARANTORS All of our material wholly-owned subsidiaries are guarantors under the terms of both our senior notes, our credit facility and our Term Loan Facility. Our consolidated financial statements reflect the combined financial position of these subsidiary guarantors. The parent company, Alta Mesa Holdings, LP, has no independent operations, assets, or liabilities. The guarantees are full and unconditional (except for customary release provisions) and joint and several. Those subsidiaries which are not wholly owned and are not guarantors are minor. There are no restrictions on dividends, distributions, loans, or other transfers of funds from the subsidiary guarantors to the parent company.

Subsequent Events

Subsequent Events	6 Months Ended
	Jun. 30, 2015
Subsequent Events [Abstract]
Subsequent Events	1 4 . SUBSEQUENT EVENTS On August 1 3 , 2015 , High Mesa contributed $20 million to us in connection with the issuance of Series C PIK convertible preferred stock of High Mesa (“Series C Issuance”) to Highbridge for gross proceeds of $25 million. In connection with the Series C Issuance, Alta Mesa Holdings GP, LLC , High Mesa, as holder of 100% of our Class B Units, and all of our Class A Limited Partners entered into a Third Amended and Restated Limited Partnership Agreement to provide for the Series C Issuance in the distribution formula and certain other provisions of the amended partnership agreement. We will use the capital to pay down amounts owed under the credit facility and for other general corporate purposes.

Summary Of Significant Accoun20

Summary Of Significant Accounting Policies (Policy)	6 Months Ended
	Jun. 30, 2015
Summary Of Significant Accounting Policies [Abstract]
Principles Of Consolidation And Reporting	Principles of Consolidation and Reporting The consolidated financial statements reflect our accounts after elimination of all significant intercompany transactions and balances. The financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our annual consolidated financial statements for the year ended December 31, 2014, which were filed with the Securities and Exchange Commission in our 2014 Annual Report. The consolidated financial statements included herein as of June 30, 2015 , and for the three and six months ended June 30, 2015 and 2014 , are unaudited, and in the opinion of management, the information furnished reflects all material adjustments, consisting of normal recurring adjustments, necessary for a fair presentation of consolidated financial position and of the results of operations for the interim periods presented. The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the U.S. (“GAAP”) for interim financial information and with the instructions to Form 10-Q and Article 10 of Regulation S-X. Accordingly, they do not include all of the information and footnotes required by GAAP for complete fin ancial statements. Certain reclassifications of prior period consolidated financial statements have been made to conform to current reporting practices. The Company reclassified $25.5 million of other receivables as of December 31, 2014 to receivables due from affiliate to conform to current reporting presentation on the consolidated balance sheets. The $25.5 million was paid subsequent to year-end on January 2, 2015. The reclassifications had no impact on net income (loss) or partners’ (deficit). The consolidated results of operations for interim periods are not necessarily indicative of results to be expected for a full year.
Use Of Estimates	Use of Estimates The preparation of consolidated financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Reserve estimates significantly impact depreciation, depletion and amortization expense and potential impairments of oil and natural gas properties and are subject to change based on changes in oil and natural gas prices and trends and changes in estimated reserve quantities. We analyze estimates, including those related to oil and natural gas reserves, oil and natural gas revenues, the value of oil and natural gas properties, bad debts, asset retirement obligations, derivative contracts, and contingencies and litigation. We base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances. Actual results may differ from these estimates.
Recent Accounting Pronouncements	Recent Accounting Pronouncements In March 2015, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2015-03, Simplifying the Presentation of Debt Issuance Costs. The amendments in this update require that debt issuance costs related to a recognized debt liability be presented in the balance sheet as a direct deduction from the carrying amount of that debt liability, consistent with debt discounts. The recognition and measurement guidance for debt issuance costs are not affected by the amendments in this update. The guidance is effective for interim periods and annual periods beginning after December 15, 2015; however early adoption is permitted. The adoption of this guidance will not have a material impact on its financial position, results of operations or cash flows. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers . The update provides guidance concerning the recognition and measurement of revenue from contracts with customers. ASU 2014-09 is effective for annual and interim periods beginning after December 15, 2016. The standard is required to be adopted using either the full retrospective approach, with all prior periods presented adjusted, or the modified retrospective approach, with a cumulative adjustment to retained earnings on the opening balance sheet. In April 2015, the FASB proposed to delay the effective date one year, beginning in fiscal year 2018. The proposal will be subject to the FASB’s due process requirement, which includes a period for public comments. We are currently evaluating the impact of adopting this standard on our consolidated financial statements.

Fair Value Disclosures (Policy)

Fair Value Disclosures (Policy)	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements And Disclosures	We follow the guidance of ASC 820, “Fair Value Measurements and Disclosures,” in the estimation of fair values. ASC 820 provides a hierarchy of fair value measurements, based on the inputs to the fair value estimation process. It requires disclosure of fair values classified according to defined “levels,” which are based on the reliability of the evidence used to determine fair value, with Level 1 being the most reliable and Level 3 the least reliable. Level 1 evidence consists of observable inputs, such as quoted prices in an active market. Level 2 inputs typically correlate the fair value of the asset or liability to a similar, but not identical item which is actively traded. Level 3 inputs include at least some unobservable inputs, such as valuation models developed using the best information available in the circumstances. The fair value of cash, accounts receivable, other current assets, and current liabilities approximate book value due to their short-term nature. The estimate of fair value of long-term debt under our senior secured revolving credit facility is not considered to be materially different from carrying value due to market rates of interest. The fair value of the notes payable to our founder is not practicable to determine because the transactions cannot be assumed to have been consummated at arm’s length, the terms are not deemed to be market terms, there are no quoted values available for this instrument, and an independent valuation would not be practicable due to the lack of data regarding similar instruments, if any, and the associated potential costs. Our senior notes are carried at historical cost, net of amortized discount; we estimate the fair value of the senior notes for disclosure purposes. We have estimated the fair value of our $450 million senior notes payable to be $331.9 million at June 30, 2015. This estimation is based on the most recent trading values of the notes at or near the reporting dates, which is a Level 1 determination. See Note 8 for information on long-term debt. We utilize the modified Black-Scholes and the Turnbull Wakeman option pricing models to estimate the fair values of oil and natural gas derivative contracts. Inputs to these models include observable inputs from the New York Mercantile Exchange (“NYMEX”) for futures contracts, and inputs derived from NYMEX observable inputs, such as implied volatility of oil and natural gas prices. We have classified the fair values of all our oil and natural gas derivative contracts as Level 2.

Derivative Financial Instrume22

Derivative Financial Instruments (Policy)	6 Months Ended
	Jun. 30, 2015
Derivative Financial Instruments [Line Items]
Derivatives And Hedging	We have not designated any of our derivative contracts as fair value or cash flow hedges; accordingly we use mark-to-market accounting, recognizing changes in the fair value of derivative contracts in the consolidated statement of operations at each reporting date. Derivative contracts are subject to master netting arrangements and are presented on a net basis in the consolidated balance sheets. This netting can cause derivative assets to be ultimately presented in a (liability) account on the consolidated balance sheets. Likewise, derivative (liabilities) could be presented in an asset account.
Energy Related Derivative [Member]
Derivative Financial Instruments [Line Items]
Derivatives, Use of Derivatives	We account for our derivative contracts under the provisions of ASC 815, "Derivatives and Hedging." We have entered into forward-swap contracts and collar contracts to reduce our exposure to price risk in the spot market for oil and natural gas. We also have utilized financial basis swap contracts, which address the price differential between market-wide benchmark prices and other benchmark pricing referenced in certain of our crude oil and natural gas sales contracts. Substantially all of our hedging agreements are executed by affiliates of our lenders under the credit facility described in Note 8, and are collateralized by the security interests of the respective affiliated lenders in certain of our assets under the credit facility. The contracts settle monthly and are scheduled to coincide with either oil production equivalent to barrels (Bbl) per month or gas production equivalent to volumes in millions of British thermal units (MMbtu) per month. The contracts represent agreements between us and the counter-parties to exchange cash based on a designated price, or in the case of financial basis hedging contracts, based on a designated price differential between various benchmark prices. Cash settlement occurs monthly. No derivative contracts have been entered into for trading or speculative purposes.

Property And Equipment (Tables)

Property And Equipment (Tables)	6 Months Ended
	Jun. 30, 2015
Property And Equipment [Abstract]
Property And Equipment	June 30, December 31, 2015 2014 (in thousands) (unaudited) OIL AND NATURAL GAS PROPERTIES Unproved properties $ $ Accumulated impairment Unproved properties, net Proved oil and natural gas properties Accumulated depreciation, depletion, amortization and impairment Proved oil and natural gas properties, net TOTAL OIL AND NATURAL GAS PROPERTIES, net LAND OTHER PROPERTY AND EQUIPMENT Office furniture and equipment, vehicles Accumulated depreciation OTHER PROPERTY AND EQUIPMENT, net TOTAL PROPERTY AND EQUIPMENT, net $ $

Fair Value Disclosures (Tables)

Fair Value Disclosures (Tables)	6 Months Ended
	Jun. 30, 2015
Fair Value Disclosures [Abstract]
Measurement Of Fair Value Of Assets And Liabilities On Recurring Basis	Level 1 Level 2 Level 3 Total (in thousands) At June 30, 2015 (unaudited): Financial Assets: Derivative contracts for oil and natural gas — $ — $ Financial Liabilities: Derivative contracts for oil and natural gas — $ — $ At December 31, 2014: Financial Assets: Derivative contracts for oil and natural gas — $ — $ Financial Liabilities: Derivative contracts for oil and natural gas — $ — $

Derivative Financial Instrume25

Derivative Financial Instruments (Tables)	6 Months Ended
	Jun. 30, 2015
Derivative [Line Items]
Fair Values Of Derivative Contracts	Fair Values of Derivative Contracts Net Fair Gross Gross amounts Value of Assets June 30, 2015 Fair Value offset against assets presented in Balance sheet location of Assets in the Balance Sheet the Balance Sheet (in thousands) (unaudited) Derivative financial instruments, current assets $ $ $ Derivative financial instruments, long-term assets Total $ $ $ Net Fair Gross Gross amounts Value of Liabilities June 30, 2015 Fair Value offset against liabilities presented in Balance sheet location of Liabilities in the Balance Sheet the Balance Sheet (in thousands) (unaudited) Derivative financial instruments, current liabilities $ $ $ — Derivative financial instruments, long-term liabilities Total $ $ $ Net Fair Gross Gross amounts Value of Assets December 31, 2014 Fair Value offset against assets presented in Balance sheet location of Assets in the Balance Sheet the Balance Sheet (in thousands) Derivative financial instruments, current assets $ $ $ Derivative financial instruments, long-term assets Total $ $ $ Net Fair Gross Gross amounts Value of Liabilities December 31, 2014 Fair Value offset against liabilities presented in Balance sheet location of Liabilities in the Balance Sheet the Balance Sheet (in thousands) Derivative financial instruments, current liabilities $ $ $ — Derivative financial instruments, long-term liabilities — Total $ $ $ —
Effect Of Derivative Instruments In The Consolidated Statements Of Operations	Derivatives not Three Months Ended Six Months Ended designated as hedging Location of June 30, June 30, instruments under ASC 815 Gain (Loss) 2015 2014 2015 2014 (in thousands) (unaudited) Oil commodity contracts Gain (loss) — oil and natural gas derivative contracts $ $ $ $ Natural gas commodity contracts Gain (loss) — oil and natural gas derivative contracts Total gains (losses) from derivatives not designated as hedges $ $ $ $
Oil [Member]
Derivative [Line Items]
Open Derivative Contracts	Volume Weighted Range Period and Type of Contract in Bbls Average High Low 2015 Price Swap Contracts $ $ $ Collar Contracts Short Call Options Long Put Options Short Put Options 2016 Price Swap Contracts Collar Contracts Short Call Options Long Put Options Short Put Options 2017 Collar Contracts Short Call Options Long Put Options Short Put Options 2018 Collar Contracts Short Call Options Long Put Options Short Put Options 2019 Collar Contracts Short Call Options Long Put Options Short Put Options
Natural Gas [Member]
Derivative [Line Items]
Open Derivative Contracts	Volume in Weighted Range Period and Type of Contract MMBtu Average High Low 2015 Price Swap Contracts $ $ $ Collar Contracts Long Put Options Short Put Options 2017 Collar Contracts Short Call Options Long Put Options Short Put Options 2018 Collar Contracts Short Call Options Long Put Options Short Put Options

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2015
Asset Retirement Obligations [Abstract]
Summary Of Changes In Asset Retirement Obligations	Six Months Ended June 30, 2015 (in thousands) (unaudited) Balance, beginning of year $ Liabilities incurred Liabilities settled Revisions to estimates Accretion expense Balance, June 30, 2015 Less: Current portion Long-term portion $

Long-Term Debt And Notes Paya27

Long-Term Debt And Notes Payable To Founder (Tables)	6 Months Ended
	Jun. 30, 2015
Long-Term Debt And Notes Payable To Founder [Abstract]
Long-Term Debt And Notes Payable To Founder	June 30, December 31, 2015 2014 (in thousands) (unaudited) Credit Facility $ $ Senior Secured Term Loan — Senior Notes , net of discount Total long-term debt $ $ Notes payable to founder $ $

Accounts Payable And Accrued 28

Accounts Payable And Accrued Liabilities (Tables)	6 Months Ended
	Jun. 30, 2015
Accounts Payable And Accrued Liabilities [Abstract]
Detail Of Accounts Payable And Accrued Liabilities	June 30, December 31, 2015 2014 (in thousands) (unaudited) Capital expenditures $ $ Revenues and royalties payable Operating expenses/taxes Interest Compensation Other Total accrued liabilities Accounts payable Accounts payable and accrued liabilities $ $

Summary Of Significant Accoun29

Summary Of Significant Accounting Policies (Details) - USD ($) $ in Millions	Jan. 02, 2015	Dec. 31, 2014
Summary Of Significant Accounting Policies [Abstract]
Other receivables reclassified to receivables due from affiliate		$ 25.5
Amount of reclassification paid	$ 25.5

Significant Divestitures (Detai

Significant Divestitures (Details) bbl in Millions	3 Months Ended	6 Months Ended
	Mar. 31, 2014USD ($)	Jun. 30, 2015USD ($)	Dec. 31, 2014bbl
Business Acquisition [Line Items]
Percentage of reserves proved undeveloped			67.00%
Barrels of Oil Equivalent [Member]
Business Acquisition [Line Items]
Estimated proved reserves | bbl			7.7
Eagleville Divestiture [Member]
Business Acquisition [Line Items]
Date of acquisition or sale of properties		Mar. 25, 2014
Percentage of original working interest net profits interest in wells is retained on, 2014		50.00%
Percentage of original working interest net profits interest in wells is retained on, 2015		30.00%
Percentage of original working interest net profits interest in wells is retained on, 2016		15.00%
Percentage of original working interest net profits interest in wells is retained on, 2017		0.00%
Percentage of undivided interest in mineral leases and interests included in sale		30.00%
Percentage of working interest in all wells in progress on December 31, 2013 or drilled after January 1, 2014 included in sale		30.00%
Cash purchase price, net of costs of transaction		$ 171,000,000
Gain on sale of oil and gas properties		$ 72,500,000
Operating income from sold oil and gas properties	$ 6,600,000
Eagleville Divestiture [Member] | Barrels of Oil Equivalent [Member]
Business Acquisition [Line Items]
Estimated proved reserves | bbl			7.5

Property And Equipment (Details

Property And Equipment (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Property And Equipment [Abstract]
Unproved properties	$ 84,157	$ 84,620
Accumulated impairment	(3,385)	(3,749)
Unproved properties, net	80,772	80,871
Proved oil and natural gas properties	1,503,474	1,417,785
Accumulated depreciation, depletion, amortization and impairment	(963,350)	(812,480)
Proved oil and natural gas properties, net	540,124	605,305
TOTAL OIL AND NATURAL GAS PROPERTIES, net	620,896	686,176
LAND	2,822	2,820
Office furniture and equipment, vehicles	18,122	17,302
Accumulated depreciation	(10,052)	(8,617)
OTHER PROPERTY AND EQUIPMENT, net	8,070	8,685
Total property and equipment, net	$ 631,788	$ 697,681

Fair Value Disclosures (Narrati

Fair Value Disclosures (Narrative) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Fair Value Disclosures [Abstract]
Face value of senior notes issued	$ 450,000,000		$ 450,000,000
Fair value of senior notes payable	331,900,000		331,900,000
Carrying value of oil and gas properties	8,200,000	$ 59,100,000	280,200,000	$ 60,300,000
Written down fair value of oil and gas properties	3,900,000	40,800,000	202,800,000	41,100,000
Impairment charges to oil and gas properties	$ 4,311,000	$ 18,300,000	77,361,000	19,202,000
Asset retirement obligation measured at fair value			$ 700,000	$ 400,000

Fair Value Disclosures (Measure

Fair Value Disclosures (Measurement Of Fair Value Of Assets And Liabilities On Recurring Basis) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Financial Assets:
Derivative contracts for oil and natural gas, gross	$ 91,369	$ 140,652
Financial Liabilities:
Derivative contracts for oil and natural gas, gross	$ 51,152	$ 53,578
Level 1 [Member]
Financial Assets:
Derivative contracts for oil and natural gas, gross
Financial Liabilities:
Derivative contracts for oil and natural gas, gross
Level 2 [Member]
Financial Assets:
Derivative contracts for oil and natural gas, gross	$ 91,369	$ 140,652
Financial Liabilities:
Derivative contracts for oil and natural gas, gross	$ 51,152	$ 53,578
Level 3 [Member]
Financial Assets:
Derivative contracts for oil and natural gas, gross
Financial Liabilities:
Derivative contracts for oil and natural gas, gross

Derivative Financial Instrume34

Derivative Financial Instruments (Fair Values Of Derivative Contracts) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Derivatives, Fair Value [Line Items]
Derivative assets, Gross Fair Value of Assets	$ 91,595	$ 146,666
Derivative assets, Gross, offset against assets for presentation in the Balance Sheet	(51,314)	(59,592)
Derivative Assets, Current	20,609	59,803
Derivative Assets, Noncurrent	19,672	27,271
Derivative assets, net, total	40,281	87,074
Derivative liabilities, Gross Fair Value of Liabilities	51,378	59,592
Derivative liabilities, Gross, offset against liabilities for presentation in the Balance Sheet	(51,314)	$ (59,592)
Derivative Liabilities, Noncurrent	64
Derivative liabilities, net, total	64
Derivative Assets Current [Member]
Derivatives, Fair Value [Line Items]
Derivative assets, Gross Fair Value of Assets	37,295	$ 91,341
Derivative assets, Gross, offset against assets for presentation in the Balance Sheet	(16,686)	(31,538)
Derivative Assets, Current	20,609	59,803
Derivative Asset Non-Current [Member]
Derivatives, Fair Value [Line Items]
Derivative assets, Gross Fair Value of Assets	54,300	55,325
Derivative assets, Gross, offset against assets for presentation in the Balance Sheet	(34,628)	(28,054)
Derivative Assets, Noncurrent	19,672	27,271
Derivative Liabilities Current [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities, Gross Fair Value of Liabilities	16,686	31,538
Derivative liabilities, Gross, offset against liabilities for presentation in the Balance Sheet	$ (16,686)	$ (31,538)
Derivative Liabilities, Current
Derivative Liabilities Non Current [Member]
Derivatives, Fair Value [Line Items]
Derivative liabilities, Gross Fair Value of Liabilities	$ 34,692	$ 28,054
Derivative liabilities, Gross, offset against liabilities for presentation in the Balance Sheet	(34,628)	$ (28,054)
Derivative Liabilities, Noncurrent	$ 64

Derivative Financial Instrume35

Derivative Financial Instruments (Effect Of Derivative Instruments In The Consolidated Statements Of Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) from oil and natural gas commodity contracts	$ (15,160)	$ (24,729)	$ 11,599	$ (35,428)
Not Designated As Hedging Instrument [Member] | Oil Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) from oil and natural gas commodity contracts	(14,545)	(23,541)	6,196	(28,510)
Not Designated As Hedging Instrument [Member] | Natural Gas Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Total gains (losses) from oil and natural gas commodity contracts	$ (615)	$ (1,188)	$ 5,403	$ (6,918)

Derivative Financial Instrume36

Derivative Financial Instruments (Oil Derivative Contracts) (Details) - Jun. 30, 2015 - Oil Derivative Contracts [Member]	$ / bblbbl
Price Swap Contracts [Member] | 2015 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	1,794,050
Weighted Average Swap Price	66.02
Price Swap Contracts [Member] | 2015 [Member] | Maximum [Member]
Derivative [Line Items]
Swap Price	93
Price Swap Contracts [Member] | 2015 [Member] | Minimum [Member]
Derivative [Line Items]
Swap Price	55.56
Price Swap Contracts [Member] | 2016 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	1,771,300
Weighted Average Swap Price	68.17
Price Swap Contracts [Member] | 2016 [Member] | Maximum [Member]
Derivative [Line Items]
Swap Price	94.92
Price Swap Contracts [Member] | 2016 [Member] | Minimum [Member]
Derivative [Line Items]
Swap Price	60
Short Call Options [Member] | 2015 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	73,600
Weighted Average Option Price	95.50
Short Call Options [Member] | 2015 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	95.50
Short Call Options [Member] | 2015 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	95.50
Short Call Options [Member] | 2016 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	1,042,700
Weighted Average Option Price	102.18
Short Call Options [Member] | 2016 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	130
Short Call Options [Member] | 2016 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	75
Short Call Options [Member] | 2017 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	1,595,150
Weighted Average Option Price	90.17
Short Call Options [Member] | 2017 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	113.83
Short Call Options [Member] | 2017 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	71.35
Short Call Options [Member] | 2018 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	1,183,000
Weighted Average Option Price	80.51
Short Call Options [Member] | 2018 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	104.65
Short Call Options [Member] | 2018 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	72
Short Call Options [Member] | 2019 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	821,250
Weighted Average Option Price	75.17
Short Call Options [Member] | 2019 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	75.70
Short Call Options [Member] | 2019 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	74.50
Long Put Options [Member] | 2015 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	745,250
Weighted Average Option Price	78.58
Long Put Options [Member] | 2015 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	90
Long Put Options [Member] | 2015 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	60
Long Put Options [Member] | 2016 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	1,042,700
Weighted Average Option Price	81.95
Long Put Options [Member] | 2016 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	95
Long Put Options [Member] | 2016 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	63
Long Put Options [Member] | 2017 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	1,412,650
Weighted Average Option Price	72.27
Long Put Options [Member] | 2017 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	90
Long Put Options [Member] | 2017 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	60
Long Put Options [Member] | 2018 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	1,183,000
Weighted Average Option Price	67.05
Long Put Options [Member] | 2018 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	80
Long Put Options [Member] | 2018 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	62.50
Long Put Options [Member] | 2019 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	821,250
Weighted Average Option Price	62.50
Long Put Options [Member] | 2019 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	62.50
Long Put Options [Member] | 2019 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	62.50
Short Put Options [Member] | 2015 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	763,650
Weighted Average Option Price	71.93
Short Put Options [Member] | 2015 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	90
Short Put Options [Member] | 2015 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	60
Short Put Options [Member] | 2016 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	1,225,700
Weighted Average Option Price	68.67
Short Put Options [Member] | 2016 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	75
Short Put Options [Member] | 2016 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	60
Short Put Options [Member] | 2017 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	1,412,650
Weighted Average Option Price	54.63
Short Put Options [Member] | 2017 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	70
Short Put Options [Member] | 2017 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	45
Short Put Options [Member] | 2018 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	1,183,000
Weighted Average Option Price	48.90
Short Put Options [Member] | 2018 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	60
Short Put Options [Member] | 2018 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	45
Short Put Options [Member] | 2019 [Member]
Derivative [Line Items]
Volume in Bbls | bbl	821,250
Weighted Average Option Price	45
Short Put Options [Member] | 2019 [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	45
Short Put Options [Member] | 2019 [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	45

Derivative Financial Instrume37

Derivative Financial Instruments (Natural Gas Derivative Contracts) (Details) - Jun. 30, 2015 - Natural Gas Derivative Contracts [Member]	MMBTU$ / MMBTU
2015 [Member] | Price Swap Contracts [Member]
Derivative [Line Items]
Volume in MMbtu | MMBTU	414,000
Weighted Average Swap Price	2.80
2015 [Member] | Price Swap Contracts [Member] | Maximum [Member]
Derivative [Line Items]
Swap Price	2.80
2015 [Member] | Price Swap Contracts [Member] | Minimum [Member]
Derivative [Line Items]
Swap Price	2.80
2015 [Member] | Long Put Options [Member]
Derivative [Line Items]
Volume in MMbtu | MMBTU	388,250
Weighted Average Option Price	3.50
2015 [Member] | Long Put Options [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	3.50
2015 [Member] | Long Put Options [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	3.50
2015 [Member] | Short Put Options [Member]
Derivative [Line Items]
Volume in MMbtu | MMBTU	388,250
Weighted Average Option Price	3.50
2015 [Member] | Short Put Options [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	3.50
2015 [Member] | Short Put Options [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	3.50
2017 [Member] | Short Call Options [Member]
Derivative [Line Items]
Volume in MMbtu | MMBTU	6,570,000
Weighted Average Option Price	5
2017 [Member] | Short Call Options [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	5
2017 [Member] | Short Call Options [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	4.98
2017 [Member] | Long Put Options [Member]
Derivative [Line Items]
Volume in MMbtu | MMBTU	6,570,000
Weighted Average Option Price	4.50
2017 [Member] | Long Put Options [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	4.50
2017 [Member] | Long Put Options [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	4.50
2017 [Member] | Short Put Options [Member]
Derivative [Line Items]
Volume in MMbtu | MMBTU	6,570,000
Weighted Average Option Price	4
2017 [Member] | Short Put Options [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	4
2017 [Member] | Short Put Options [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	4
2018 [Member] | Short Call Options [Member]
Derivative [Line Items]
Volume in MMbtu | MMBTU	5,475,000
Weighted Average Option Price	5.50
2018 [Member] | Short Call Options [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	5.53
2018 [Member] | Short Call Options [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	5.48
2018 [Member] | Long Put Options [Member]
Derivative [Line Items]
Volume in MMbtu | MMBTU	5,475,000
Weighted Average Option Price	4.50
2018 [Member] | Long Put Options [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	4.50
2018 [Member] | Long Put Options [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	4.50
2018 [Member] | Short Put Options [Member]
Derivative [Line Items]
Volume in MMbtu | MMBTU	5,475,000
Weighted Average Option Price	4
2018 [Member] | Short Put Options [Member] | Maximum [Member]
Derivative [Line Items]
Option Price	4
2018 [Member] | Short Put Options [Member] | Minimum [Member]
Derivative [Line Items]
Option Price	4

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Dec. 31, 2014
Asset Retirement Obligations [Abstract]
Balance, beginning of year			$ 62,872
Liabilities incurred			722
Liabilities settled			(1,275)
Revisions to estimates			(105)
Accretion expense	$ 456	$ 613	1,000	$ 1,171
Balance, end of period	63,214		62,872		$ 62,872
Less: Current portion	710				1,136
Long-term portion	$ 62,504				$ 61,736
Reductions to PPE included in ARO revisions			$ 600

Long-Term Debt And Notes Paya39

Long-Term Debt And Notes Payable To Founder (Narrative) (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2015	Jun. 30, 2014	Jun. 30, 2015	Jun. 30, 2014	Jun. 02, 2015	Jun. 01, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Amount borrowed	$ 125,000,000		$ 125,000,000
Face value of senior notes issued	450,000,000		450,000,000
Notes payable to founder	$ 25,139,000		25,139,000				$ 24,540,000
Interest on notes payable to founder			599,000	$ 600,000
Amortization of deferred financing costs			$ 1,513,000	1,433,000
Credit Facility [Member]
Debt Instrument [Line Items]
Credit facility borrowing base					$ 300,000,000	$ 375,000,000
Date of maturity of credit facility			Oct. 13, 2017
Credit facility interest rate	2.50%		2.50%				2.89%
Letter of credit outstanding	$ 900,000		$ 900,000
Minimum Working Capital Ratio			1
Minimum Coverage of Interest Expense Ratio			3
Maximum Leverage Ratio			4
Debt instrument collateral			The credit facility is secured by substantially all of our oil and natural gas properties and is based on our proved reserves and the value attributed to those reserves. The credit facility borrowing base is redetermined periodically semi-annually in May and November.
Debt covenants description			The credit facility contains customary covenants including, among others, defined financial covenants, including minimum working capital levels (the ratio of current assets plus the unused borrowing base, to current liabilities, excluding assets and liabilities related to derivative contracts) of 1.0 to 1.0, minimum coverage of interest expenses of 3.0 to 1.0, and maximum leverage of 4.00 to 1.00. The interest coverage and leverage ratios refer to the ratio of earnings before interest, taxes, depreciation, depletion, amortization, and exploration expense ("EBITDAX", as defined more specifically in the credit agreement) to interest expense and to total debt (as defined), respectively. Financial ratios are calculated quarterly using EBITDAX for the most recent twelve months.
Debt covenant compliance description			As of June 30, 2015, we were in compliance with all covenants of the credit facility.
Credit Facility [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument [Line Items]
Credit facility applicable interest rate, description			LIBOR plus applicable margins between 2.00% and 2.75%
Credit Facility [Member] | Prime Rate [Member]
Debt Instrument [Line Items]
Credit facility applicable interest rate, description			prime rate of Wells Fargo Bank, N. A., plus a margin ranging from 1.00% to 1.75%
Credit Facility [Member] | Minimum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument [Line Items]
Margin interest rate			2.00%
Credit Facility [Member] | Minimum [Member] | Prime Rate [Member]
Debt Instrument [Line Items]
Margin interest rate			1.00%
Credit Facility [Member] | Maximum [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument [Line Items]
Margin interest rate			2.75%
Credit Facility [Member] | Maximum [Member] | Prime Rate [Member]
Debt Instrument [Line Items]
Margin interest rate			1.75%
Senior Notes [Member]
Debt Instrument [Line Items]
Face value of senior notes issued	$ 450,000,000		$ 450,000,000
Maturity Date of Debt			Oct. 15, 2018
Stated interest rate of senior notes	9.625%		9.625%
Effective rate of interest	9.7825%		9.7825%
Senior notes interest payable date			. Interest is payable semi-annually each April 15th and October 15th
Debt instrument collateral			The senior notes are unsecured and are general obligations of the Company, and effectively rank junior to any of our existing or future secured indebtedness, which includes the credit facility and the Term Loan Facility. The senior notes are unconditionally guaranteed on a senior unsecured basis by each of our material subsidiaries.
Remaining unamortized discount	$ 1,700,000		$ 1,700,000				$ 1,900,000
Senior Notes [Member] | Twelve Mos Beginning October 15, 2014 [Member]
Debt Instrument [Line Items]
Optional redemption price of Senior Notes			104.813%
Senior Notes [Member] | Twelve Mos Beginning October 15, 2015 [Member]
Debt Instrument [Line Items]
Optional redemption price of Senior Notes			102.406%
Senior Notes [Member] | Twelve Mos Beginning October 15, 2016 [Member]
Debt Instrument [Line Items]
Optional redemption price of Senior Notes			100.00%
Notes Payable To Founder [Member]
Debt Instrument [Line Items]
Maturity Date of Debt			Dec. 31, 2021
Effective rate of interest	10.00%		10.00%
Debt instrument collateral			These founder notes are unsecured and subordinate to all debt. In connection with the March 25, 2014 recapitalization of our Class B partner described in Note 12, the founder notes were amended and restated to subordinate them to the paid in kind ("PIK") notes of our Class B partner. The founder notes were also subordinated to the rights of the holders of Class B units to receive distributions under our amended partnership agreement and subordinated to the rights of the holders of Series B Preferred Stock to receive payments.
Notes payable to founder	$ 25,100,000		$ 25,100,000				$ 24,500,000
Payment terms, notes payable to founder			Interest and principal are payable at maturity.
Interest on notes payable to founder	$ 300,000	$ 300,000	$ 600,000	$ 600,000
Conversion feature, notes payable to founder			The notes are convertible into shares of our Class B partner, High Mesa, Inc. ("High Mesa"), common stock upon certain conditions in the event of an initial public offering.
Senior Secured Term Loan [Member]
Debt Instrument [Line Items]
Minimum Working Capital Ratio			1
Maximum Debt To EBITDAX Ratio			4.5
Minimum PV-9 Of Total Proved Reserves To Total Secured Debt Ratio			1.5
Minimum EBITDAX To Interest Expense Ratio			2.5
Amount borrowed					125,000,000
Additional borrowings allowed					$ 50,000,000
Period following closing additional borrowings can be made			1 year
Net proceeds used to pay down outstanding amounts under existing credit facility			$ 121,000,000
Mandatory prepayments of percentage of net cash proceeds from asset sales			75.00%
Maturity Date of Debt			Apr. 15, 2018
Senior Secured Term Loan [Member] | London Interbank Offered Rate (LIBOR) [Member]
Debt Instrument [Line Items]
Margin interest rate			8.00%
Senior Secured Term Loan [Member] | Minimum [Member]
Debt Instrument [Line Items]
Premium percentage prepayments are subject to			1.00%
Senior Secured Term Loan [Member] | Maximum [Member]
Debt Instrument [Line Items]
Premium percentage prepayments are subject to			3.00%

Long-Term Debt And Notes Paya40

Long-Term Debt And Notes Payable To Founder (Long-Term Debt And Notes Payable To Founder) (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Long-Term Debt And Notes Payable To Founder [Abstract]
Credit Facility	$ 219,086	$ 319,520
Senior Secured Term Loan	125,000
Senior Notes, net of discount	448,343	448,088
Total long-term debt	792,429	767,608
Notes payable to founder	$ 25,139	$ 24,540

Accounts Payable And Accrued 41

Accounts Payable And Accrued Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2015	Dec. 31, 2014
Accounts Payable And Accrued Liabilities [Abstract]
Capital expenditures	$ 14,149	$ 32,990
Revenues and royalties payable	4,970	7,302
Operating expenses/taxes	20,104	20,716
Interest	9,949	9,136
Compensation	10,130	10,586
Other	5,919	2,605
Total accrued liabilities	65,221	83,335
Accounts payable	21,794	34,225
Accounts payable and accrued liabilities	$ 87,015	$ 117,560

Commitments and Contingencies (

Commitments and Contingencies (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2015	Dec. 31, 2014
Commitments And Contingencies [Abstract]
Liability for soil contamination	$ 1.2	$ 1.1
Vesting period, PARs	5 years
Number of performance appreciation rights granted	0
Number of performance appreciation rights terminated	27,500
Number of performance appreciation rights	244,000
Estimated litigation liability	$ 5

Partners' Capital (Deficit) (De

Partners' Capital (Deficit) (Details) $ in Millions	6 Months Ended
	Jun. 30, 2015USD ($)
Partners' Capital (Deficit) [Abstract]
Limited Partners' Capital Account, Distribution Amount	$ 3.8

Subsequent Events (Details)

Subsequent Events (Details) - USD ($) $ in Millions	Aug. 13, 2015	Jun. 30, 2015
Subsequent Event [Line Items]
Percentage of Class B Units held by High Mesa		100.00%
Series C PIK Convertible Preferred Stock [Member] | Subsequent Event [Member]
Subsequent Event [Line Items]
Amount contributed by High Mesa in connection with issuance of preferred stock	$ 20
Proceeds from issuance of convertible preferred stock	$ 25