Amplify Energy (AMPY) 10-K 24 Mar 14 2013 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Mar. 18, 2014	Jun. 28, 2013
Document and Entity Information	'	'	'
Entity Registrant Name	'Midstates Petroleum Company, Inc.	'	'
Entity Central Index Key	'0001533924	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Amendment Flag	'false	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Well-known Seasoned Issuer	'No	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Entity Filer Category	'Accelerated Filer	'	'
Entity Public Float	'	'	$180
Entity Common Stock, Shares Outstanding	'	70,420,804	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'

CONSOLIDATED_BALANCE_SHEETS

CONSOLIDATED BALANCE SHEETS (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
CURRENT ASSETS:	'	'
Cash and cash equivalents	$33,163	$18,878
Accounts receivable:	'	'
Oil and gas sales	102,483	35,618
Joint interest billing	42,631	10,815
Other	1,090	3,866
Commodity derivative contracts	700	5,695
Deferred income taxes	11,837	6,027
Other current assets	693	8,573
Total current assets	192,597	89,472
PROPERTY AND EQUIPMENT:	'	'
Oil and gas properties, on the basis of full-cost accounting	3,060,661	1,836,664
Other property and equipment	11,113	5,038
Less accumulated depreciation, depletion, amortization and impairment	-976,880	-274,294
Net property and equipment	2,094,894	1,567,408
OTHER ASSETS:	'	'
Commodity derivative contracts	19	1,717
Other noncurrent assets	54,597	25,413
Total other assets	54,616	27,130
TOTAL	2,342,107	1,684,010
CURRENT LIABILITIES:	'	'
Accounts payable	21,493	29,196
Accrued liabilities	204,381	98,649
Commodity derivative contracts	27,880	7,582
Total current liabilities	253,754	135,427
LONG-TERM LIABILITIES:	'	'
Asset retirement obligations	26,308	15,245
Commodity derivative contracts	3,651	3,943
Long-term debt	1,701,150	694,000
Deferred income taxes	15,291	156,737
Other long-term liabilities	1,954	1,189
Total long-term liabilities	1,748,354	871,114
COMMITMENTS AND CONTINGENCIES (Note 14)	'	'
STOCKHOLDERS' EQUITY	'	'
Preferred stock, $0.01 par value, 49,675,000 shares authorized; no shares issued or outstanding	'	'
Common stock, $0.01 par value, 300,000,000 shares authorized; 68,925,745 shares issued and 68,807,043 shares outstanding at December 31, 2013 and 66,619,711 shares issued and outstanding at December 31, 2012	689	666
Treasury stock	-664	'
Additional paid-in-capital	871,047	863,891
Retained deficit	-531,076	-187,091
Total stockholders' equity	339,999	677,469
TOTAL	2,342,107	1,684,010
Series A mandatorily convertible preferred stock, $0.01 par value, $358,550 and $325,000 liquidation value at December 31, 2013 and December 31, 2012, respectively; 8% cumulative dividends; 325,000 shares issued and outstanding	'	'
STOCKHOLDERS' EQUITY	'	'
Preferred stock, $0.01 par value, 49,675,000 shares authorized; no shares issued or outstanding	3	3
Total stockholders' equity	$3	$3

CONSOLIDATED_BALANCE_SHEETS_Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Common stock, par value (in dollars per share)	$0.01	$0.01
Common stock, shares authorized	300,000,000	300,000,000
Common stock, shares issued	68,925,745	66,619,711
Common stock, shares outstanding	68,807,043	66,619,711
Preferred stock, $0.01 par value, 49,675,000 shares authorized; no shares issued or outstanding	'	'
Preferred stock, par value (in dollars per share)	$0.01	$0.01
Preferred stock, shares authorized	49,675,000	49,675,000
Preferred stock, shares issued	0	0
Preferred stock, shares outstanding	0	0
Series A mandatorily convertible preferred stock, $0.01 par value, $358,550 and $325,000 liquidation value at December 31, 2013 and December 31, 2012, respectively; 8% cumulative dividends; 325,000 shares issued and outstanding	'	'
Preferred stock, par value (in dollars per share)	$0.01	$0.01
Preferred stock, shares issued	325,000	325,000
Preferred stock, shares outstanding	325,000	325,000
Preferred stock, liquidation value (in dollars per share)	$358,550	$325,000
Preferred stock, cumulative dividends (as a percent)	8.00%	8.00%

CONSOLIDATED_STATEMENTS_OF_OPE

CONSOLIDATED STATEMENTS OF OPERATIONS (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
REVENUES:	'	'	'
Oil sales	$387,226	$218,430	$177,464
Natural gas liquid sales	62,340	23,617	15,683
Natural gas sales	63,187	16,030	20,665
Losses on commodity derivative contracts - net	-44,284	-11,158	-4,844
Other	1,037	754	465
Total revenues	469,506	247,673	209,433
EXPENSES:	'	'	'
Lease operating and workover	73,414	30,500	16,117
Gathering and transportation	5,455	'	'
Severance and other taxes	27,237	24,921	13,640
Asset retirement accretion	1,435	723	334
Depreciation, depletion, and amortization	250,396	125,561	91,699
Impairment in carrying value of oil and gas properties	453,310	'	'
General and administrative	53,250	30,541	68,915
Acquisition and transaction costs	11,803	14,884	'
Other	615	'	'
Total expenses	876,915	227,130	190,705
OPERATING INCOME (LOSS)	-407,409	20,543	18,728
OTHER INCOME (EXPENSE)	'	'	'
Interest income	33	245	23
Interest expense - net of amounts capitalized	-83,138	-12,999	-2,094
Total other income (expense)	-83,105	-12,754	-2,071
INCOME (LOSS) BEFORE TAXES	-490,514	7,789	16,657
Income tax benefit (expense)	146,529	-157,886	'
NET INCOME (LOSS)	-343,985	-150,097	16,657
Preferred stock dividend	-15,589	-6,500	'
NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS	($359,574)	($156,597)	$16,657
Basic and diluted net loss per share attributable to common shareholders (in dollars per share)	($5.47)	($2.61)	'
Basic and diluted weighted average number of common shares outstanding (in shares)	65,766	59,979	'

CONSOLIDATED_STATEMENT_OF_CHAN

CONSOLIDATED STATEMENT OF CHANGES IN STOCKHOLDERS'/MEMBERS' EQUITY (USD $)	Total	Common Stock	Treasury Stock	Capital Contributions	Additional Paid-in-Capital	Retained Deficit/Accumulated Loss	Series A Preferred Stock
In Thousands, unless otherwise specified
Balance at Dec. 31, 2010	$255,879	'	'	$309,530	'	($53,651)	'
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'	'	'
Distribution to members	-50,572	'	'	-50,572	'	'	'
Members' contribution	2,870	'	'	2,870	'	'	'
Reclassification of liability for share-based awards	60,668	'	'	60,668	'	'	'
Net income (loss)	16,657	'	'	'	'	16,657	'
Balance at Dec. 31, 2011	285,502	'	'	322,496	'	-36,994	'
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'	'	'
Issuance of common stock	'	476	'	-476	'	'	'
Reclassification of members' contributions	'	'	'	-322,020	322,020	'	'
Proceeds from the sale of common stock	213,569	180	'	'	213,389	'	'
Tax attributes contributed at IPO reorganization date by shareholding entities	33,888	'	'	'	33,888	'	'
Issuance of preferred stock as consideration in the Eagle Property Acquisition	291,956	'	'	'	291,953	'	3
Share-based compensation	2,651	10	'	'	2,641	'	'
Net income (loss)	-150,097	'	'	'	'	-150,097	'
Balance at Dec. 31, 2012	677,469	666	'	'	863,891	-187,091	3
Increase (Decrease) in Stockholders' Equity	'	'	'	'	'	'	'
Share-based compensation	7,179	23	'	'	7,156	'	'
Acquisition of treasury stock	-664	'	-664	'	'	'	'
Net income (loss)	-343,985	'	'	'	'	-343,985	'
Balance at Dec. 31, 2013	$339,999	$689	($664)	'	$871,047	($531,076)	$3

CONSOLIDATED_STATEMENTS_OF_CAS

CONSOLIDATED STATEMENTS OF CASH FLOWS (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2012
				Eagle Property Acquisition
CASH FLOWS FROM OPERATING ACTIVITIES:	'	'	'	'
Net loss	($343,985)	($150,097)	$16,657	'
Adjustments to reconcile net loss to net cash provided by operating activities:	'	'	'	'
Losses on commodity derivative contracts - net	44,284	11,158	4,844	'
Net cash paid for commodity derivative contracts not designated as hedging instruments	-17,585	-15,825	-16,733	'
Asset retirement accretion	1,435	723	334	'
Depreciation, depletion, and amortization	250,396	125,561	91,699	'
Impairment in carrying value of oil and gas properties	453,310	'	'	'
Share - based compensation, net of amounts capitalized to oil and gas properties	5,713	2,459	53,744	'
Deferred income taxes	-146,529	157,886	'	'
Amortization of deferred financing costs	5,955	1,530	850	'
Change in operating assets and liabilities:	'	'	'	'
Accounts receivable - oil and gas sales	-66,865	-11,826	-9,651	'
Accounts receivable - JIB and other	-28,488	-11,019	-3,125	'
Other current and noncurrent assets	-1,802	-218	-6,799	'
Accounts payable	-4,350	-646	3,059	'
Accrued liabilities	75,903	27,931	5,977	'
Other	-290	-368	694	'
Net cash provided by operating activities	227,102	137,249	141,550	'
CASH FLOWS FROM INVESTING ACTIVITIES:	'	'	'	'
Investment in property and equipment	-573,734	-422,332	-242,619	'
Investment in acquired property	-620,112	-351,276	'	'
Net cash used in investing activities	-1,193,846	-773,608	-242,619	'
CASH FLOWS FROM FINANCING ACTIVITIES:	'	'	'	'
Proceeds from long-term borrowings	1,041,450	744,667	145,200	'
Repayment of long-term borrowings	-34,300	-285,467	'	'
Proceeds from issuance of mandatorily redeemable convertible preferred units	'	65,000	'	'
Repayment of mandatorily redeemable convertible preferred units	'	-65,000	'	'
Proceeds from sale of common stock, net of initial public offering expenses of $6.4 million	'	213,569	'	'
Deferred financing costs	-25,457	-24,876	-863	'
Acquisition of treasury stock	-664	'	'	'
Cash received for units, pre - IPO	'	'	2,870	'
Distributions to members	'	'	-50,572	'
Other	'	'	-139	'
Net cash provided by financing activities	981,029	647,893	96,496	'
NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS	14,285	11,534	-4,573	'
Cash and cash equivalents, beginning of period	18,878	7,344	11,917	'
Cash and cash equivalents, end of period	33,163	18,878	7,344	'
SUPPLEMENTAL INFORMATION:	'	'	'	'
Non-cash transactions - investments in property and equipment accrued - not paid	106,500	87,812	61,590	'
Non-cash components of Business Acquisition Purchase Price:	'	'	'	'
Preferred stock issued for property	'	291,956	'	291,956
Deferred tax liability assumed	'	26,700	'	26,712
Asset retirement obligation assumed	'	'	'	2,662
Accrual for additional consideration	'	'	'	1,500
Cash paid for interest, net of capitalized interest of $32.2 million, $11.2 million and $2.6 million, respectively	72,085	'	1,594	'
Tax attributes contributed at IPO reorganization date by shareholding entities	'	33,888	'	'
Reclassification of share-based compensation to members' equity	'	'	$6,924	'

CONSOLIDATED_STATEMENTS_OF_CAS1

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
CONSOLIDATED STATEMENTS OF CASH FLOWS	'	'	'
Initial public offering expenses	'	$6.40	'
Capitalized interest	$32.20	$11.20	$2.60

Organization_and_Business

Organization and Business	12 Months Ended
	Dec. 31, 2013
Organization and Business	'
Organization and Business	'
	1. Organization and Business
	Midstates Petroleum Company, Inc., through its wholly-owned subsidiary Midstates Petroleum Company LLC, engages in the business of drilling for, and production of, oil, natural gas and natural gas liquids. Midstates Petroleum Company, Inc. was incorporated pursuant to the laws of the State of Delaware on October 25, 2011 to become a holding company for Midstates Petroleum Company LLC ("Midstates Sub"), which was previously a wholly-owned subsidiary of Midstates Petroleum Holdings LLC ("Holdings LLC"). Pursuant to the terms of a corporate reorganization that was completed in connection with the closing of Midstates Petroleum Company, Inc.'s initial public offering, all of the interests in Midstates Petroleum Holdings LLC were exchanged for newly issued common shares of Midstates Petroleum Company, Inc., and as a result, Midstates Petroleum Company LLC became a wholly-owned subsidiary of Midstates Petroleum Company, Inc. and Midstates Petroleum Holdings LLC ceased to exist as a separate entity. The terms "the Company," "we," "us," "our," and similar terms when used in the present tense, prospectively or for historical periods since April 25, 2012, refer to Midstates Petroleum Company, Inc. and its subsidiary, and for historical periods prior to April 25, 2012, refer to Midstates Petroleum Holdings LLC and its subsidiary, unless the context indicates otherwise. The term "Holdings LLC" refers solely to Midstates Petroleum Holdings LLC prior to the corporate reorganization.
	On April 25, 2012, the Company completed its initial public offering of common stock pursuant to a registration statement on Form S-1 (File 333-177966), as amended and declared effective by the SEC on April 19, 2012. Pursuant to the registration statement, the Company registered the offer and sale of 27,600,000 shares of $0.01 par value common stock, which included 6,000,000 shares of stock sold by the selling shareholders and 3,600,000 shares of common stock sold by the selling stockholders pursuant to an option granted to the underwriters to cover over-allotments. The Company's sale of the shares in its initial public offering closed on April 25, 2012 and its initial public offering terminated upon completion of the closing.
	The proceeds of the Company's initial public offering, based on the public offering price of $13.00 per share, were approximately $358.8 million. After subtracting underwriting discounts and commissions of $21.5 million and the net proceeds to the selling stockholders of $117.3 million, the Company received net proceeds of approximately $220.0 million from the registration and sale of 18,000,000 common shares (or $213.6 million net of offering expenses paid directly by the Company). The Company used $67.1 million of the net proceeds to redeem convertible preferred units in Holdings LLC, including interest and other charges, and $99.0 million to pay down a portion of the borrowings under its revolving credit facility. The Company used the remaining $47.5 million to fund the execution of its growth strategy through its drilling program. The Company did not receive any of the proceeds from the sale of the 9,600,000 shares by the selling stockholders. Immediately after the initial public offering and exercise of the over-allotment option granted to the underwriters, First Reserve Midstates Interholding LP and its affiliates owned approximately 41.4% of the Company's outstanding common stock.
	On October 1, 2012, the Company closed on the acquisition of all of Eagle Energy Production, LLC's producing properties as well as its developed and undeveloped acreage primarily in the Mississippian Lime liquids play in Oklahoma and Kansas for $325 million in cash and 325,000 shares of the Company's Series A Preferred Stock with an initial liquidation preference value of $1,000 per share (the "Eagle Property Acquisition"). The Company funded the cash portion of the Eagle Property Acquisition purchase price with a portion of the net proceeds from the private placement of $600 million in aggregate principal amount of 10.75% senior unsecured notes due 2020, which also closed on October 1, 2012 ("2020 Senior Notes").
	On May 31, 2013, the Company closed on the acquisition of producing properties and undeveloped acreage in the Anadarko Basin in Texas and Oklahoma from Panther Energy Company, LLC and its partners for approximately $618 million in cash (the "Anadarko Basin Acquisition"), before customary post-closing adjustments. The Company funded the purchase price with a portion of the net proceeds from the private placement of $700 million in aggregate principal amount of 9.25% senior unsecured notes due 2021, which also closed on May 31, 2013 ("2021 Senior Notes").
	Subsequent to the closing of the Eagle Property Acquisition and the Anadarko Basin Acquisition, the Company has oil and gas operations and properties in Louisiana, Oklahoma, Texas and Kansas. At December 31, 2013, the Company operated oil and natural gas properties as one reportable segment engaged in the exploration, development and production of oil, natural gas liquids and natural gas. The Company's management evaluated performance based on one reportable segment as there were not significantly different economic or operational environments within its oil and natural gas properties.
	All pro forma and per share information presented in the accompanying consolidated financial statements have been adjusted to reflect the effects of the Company's initial public offering.

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies	'
Summary of Significant Accounting Policies	'
	2. Summary of Significant Accounting Policies
	Basis of Presentation
	The accompanying consolidated financial statements of the Company have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission ("SEC") and have been prepared in accordance with generally accepted accounting principles in the United States of America ("GAAP").
	All intercompany transactions have been eliminated in consolidation. The consolidated financial statements as of and for the year ended December 31, 2013 include the results from the Anadarko Basin Acquisition beginning May 31, 2013. The consolidated financial statements as of and for the year ended December 31, 2012 include the results from the Eagle Property Acquisition beginning October 1, 2012.
	Use of Estimates
	The preparation of 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 financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
	Significant estimates include, but are not limited to, the amount of recoverable oil and natural gas reserves; future cash flows from oil and natural gas properties; the fair value of commodity derivative contracts; the fair value of share-based compensation; and the valuation of future asset retirement obligations.
	Cash and Cash Equivalents
	The Company considers all short-term investments with an original maturity of three months or less to be cash equivalents.
	Accounts Receivable and Allowance for Doubtful Accounts
	Accounts receivable are stated at the historical carrying amount net of allowance for uncollectible accounts. The carrying amount of the Company's accounts receivable approximate fair value because of the short-term nature of the instruments. The Company accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. As of December 31, 2013 and 2012, the Company had no allowance for doubtful accounts.
	Financial Instruments
	The Company's financial instruments consist of cash and cash equivalents, receivables, payables, debt, and commodity derivative contracts. Commodity derivative contracts are recorded at fair value (see Note 3). Based upon recent amendments to the Company's Credit Facility, the Company believes the carrying amount of the related floating-rate debt approximates fair value due to the variable nature of the interest rate and the current financing terms available to the Company. The carrying amount of the Company's other financial instruments approximate fair value because of the short-term nature of the items or variable pricing. See fair value discussion of Senior Notes and Series A Preferred Shares issued in October 2012 in Notes 8 and 10, respectively.
	Derivative financial instruments are recorded in the consolidated balance sheets as either an asset or liability measured at estimated fair value. Changes in the derivative's fair value are recognized currently in earnings as gains and losses in the period of change. The gains or losses are recorded in "Losses on commodity derivative contracts—net." The related cash flow impact is reflected within cash flows from operating activities.
	Other Noncurrent Assets
	At December 31, 2013, other noncurrent assets consisted of $44.7 million in deferred financing costs, $9.7 million in field inventory, and $0.2 million in other noncurrent assets. At December 31, 2012, other noncurrent assets consisted of $25.2 million in deferred financing costs and $0.2 million in other noncurrent assets. The increase in deferred financing costs is the result of approximately $19.3 million in deferred financing costs incurred during 2013 with the issuance of the 2021 Senior Notes.
	Property and Equipment
	Oil and Gas Properties
	The Company uses the full-cost method of accounting for its exploration and development activities. Under this method of accounting, the cost of both successful and unsuccessful exploration and development activities are capitalized as property and equipment. This includes any internal costs that are directly related to exploration and development activities, but does not include any costs related to production, general corporate overhead or similar activities. Proceeds from the sale or disposition of oil and gas properties are accounted for as a reduction to capitalized costs unless a significant portion of the Company's reserve quantities are sold that results in a significant alteration of the relationship between capitalized costs and remaining proved reserves, in which case a gain or loss is generally recognized in income.
	Unevaluated Property
	Oil and gas unevaluated properties and properties under development include costs that are not being depleted or amortized. These costs represent investments in unproved properties. The Company excludes these costs until proved reserves are found, until it is determined that the costs are impaired or until major development projects are placed in service, at which time the costs are moved into oil and natural gas properties subject to amortization. All unproved property costs are reviewed at least annually to determine if impairment has occurred.
	Oil and Gas Reserves
	Proved oil, NGLs and natural gas reserves utilized in the preparation of the consolidated financial statements are estimated in accordance with the rules established by the SEC and the Financial Accounting Standards Board (FASB), which require that reserve estimates be prepared under existing economic and operating conditions using a 12-month average price with no provision for price and cost escalations in future years except by contractual arrangements.
	Reserve estimates are inherently imprecise. Accordingly, the estimates are expected to change as more current information becomes available. The Company depletes its oil and gas properties using the units-of-production method. Capitalized costs of oil and natural gas properties subject to amortization are depleted over proved reserves. It is possible that, because of changes in market conditions or the inherent imprecision of reserve estimates, the estimates of future cash inflows, future gross revenues, the amount of oil and natural gas reserves, the remaining estimated lives of oil and natural gas properties, or any combination of the above may be increased or reduced. Increases in recoverable economic volumes generally reduce per unit depletion rates while decreases in recoverable economic volumes generally increase per unit depletion rates.
	Impairment of Oil and Gas Properties/Ceiling Test
	The Company performs a full-cost ceiling test on a quarterly basis. The test establishes a limit (ceiling) on the book value of oil and gas properties. The capitalized costs of proved oil and gas properties, net of accumulated depreciation, depletion and amortization (DD&A) and the related deferred income taxes, may not exceed this "ceiling." The ceiling limitation is equal to the sum of: (i) the present value of estimated future net revenues from the projected production of proved oil and gas reserves, excluding future cash outflows associated with settling asset retirement obligations accrued on the balance sheet, calculated using the average oil and natural gas sales price received by the Company as of the first trading day of each month over the preceding twelve months (such prices are held constant throughout the life of the properties) and a discount factor of 10%; (ii) the cost of unproved and unevaluated properties excluded from the costs being amortized; (iii) the lower of cost or estimated fair value of unproved properties included in the costs being amortized; and (iv) related income tax effects. If capitalized costs exceed this ceiling, the excess is charged to expense in the accompanying consolidated statements of operations. For the year ended December 31, 2013, capitalized costs exceeded the ceiling and an impairment of oil and gas properties of $319.6 million, after tax, was recorded.
	The most significant factors affecting the impairment related to the transfer of unevaluated property costs to the full cost pool during 2013 and negative reserve revisions in our Gulf Coast area. During 2013, we transferred $61.2 million of Gulf Coast unevaluated property costs to the full cost pool based upon our lack of future plans for further evaluation or development of those leases, and $168.4 million of Mississippian unevaluated property costs attributable to leases that expired during 2013 or that we currently intend to allow to expire in 2014. The negative reserve revisions in our Gulf Coast area were mainly attributable to variability in well performance, our decision during the second quarter to halt further development in our West Gordon field and unfavorable cost revisions. See Note 5.
	Depreciation, Depletion, and Amortization (DD&A)
	DD&A of oil and gas properties is calculated using the Units of Production Method (UOP). The UOP calculation, in its simplest terms, multiplies the percentage of estimated proved reserves produced by the cost of those reserves. The result is to recognize expense at the same pace that the reserves are estimated to be depleting. The amortization base in the UOP calculation includes the sum of proved property costs net of accumulated DD&A, estimated future development costs (future costs to access and develop proved reserves) and asset retirement costs that are not already included in oil and gas property, less related salvage value.
	Capitalized Interest
	Interest from external borrowings is capitalized on unevaluated properties using the weighted-average cost of outstanding borrowings until the project is substantially complete and ready for its intended use, which for oil and gas assets is at the first production from the field. Capitalized interest is depleted over the useful lives of the assets in the same manner as the depletion of the underlying assets. The Company paid cash interest of $104.3 million, $7.2 million, and $4.2 million for the years ended December 31, 2013, 2012 and 2011, respectively.
	Other Property and Equipment
	Other property and equipment consists of vehicles, furniture and fixtures, and computer hardware and software and are carried at cost. Depreciation is provided principally using the straight-line method over the estimated useful lives of the assets, which primarily range from three to seven years. Maintenance and repairs are charged to expense as incurred, while renewals and betterments are capitalized.
	Accrued Liabilities
	Accrued liabilities at December 31, 2013 consisted of $87.2 million in oil and gas capital expenditures, $64.4 million in accrued revenue and royalty distributions, $21.3 million in accrued interest, $8.3 million in accrued lease operating and workover expenses, $4.4 million in accrued taxes, and $18.8 million in other accrued liabilities. At December 31, 2012, the balance consisted of $69.0 million in oil and gas capital expenditures, $16.2 million in accrued interest, and $13.4 million in other accrued liabilities.
	Asset Retirement Obligations
	The legal obligations associated with the retirement of long-lived assets are recognized at estimated fair value at the time that the obligation is incurred.
	Oil and gas producing companies incur such a liability upon acquiring or drilling a well. The Company estimates the fair value of an asset retirement obligation in the period in which the obligation is incurred and can be reliably measured. The corresponding asset retirement cost is capitalized by increasing the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, any adjustment is recorded in the full cost pool. See Note 7.
	Share-Based Compensation
	We measure share-based compensation cost at fair value and generally recognize the corresponding compensation expense on a straight-line basis over the service period during which awards are expected to vest. We include share-based compensation expense, net of amounts capitalized to oil and gas properties, in "General and administrative expense" in our consolidated statements of operations. See Note 10.
	Revenue Recognition
	Oil, NGLs and natural gas revenues are recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred and collection of the revenues is reasonably assured. Cash received relating to future revenues is deferred and recognized when all revenue recognition criteria are met.
	The Company follows the sales method of accounting for oil and gas revenues, whereby revenue is recognized for all oil and gas sold to purchasers regardless of whether the sales are proportionate to the Company's ownership interest in the property. Production imbalances are recognized as a liability to the extent an imbalance on a specific property exceeds the Company's share of remaining proved oil and gas reserves. The Company had no significant imbalances at December 31, 2013 or 2012.
	Acquisition and Transaction Costs
	Acquisition related costs are expensed as incurred and as services are received. Such costs include finders' fees; advisory, legal, accounting, valuation and other professional and consulting fees; and acquisition related general and administrative costs. Costs incurred in 2013 relate to the Anadarko Basin Acquisition and costs incurred in 2012 relate to the Eagle Property Acquisition. See Note 6.
	Income Taxes
	Income taxes are provided for the tax effects of transactions reported in the financial statements and consist of taxes currently payable plus deferred income taxes related to certain income and expenses recognized in different periods for financial and income tax reporting purposes. Deferred income tax assets and liabilities represent the future tax return consequences of those differences, which will either be taxable or deductible when assets are recovered or liabilities are settled. Deferred income taxes also include tax credits and net operating losses that are available to offset future income taxes. Deferred income taxes are measured by applying currently enacted tax rates.
	The Company accounts for uncertainty in income taxes for tax positions taken or expected to be taken in a tax return. Only tax positions that meet the more-than-likely-than-not recognition threshold are recognized.
	Prior to its corporate reorganization (See Note 1), the Company was a limited liability company and not subject to federal income tax or state income tax (in most states). Accordingly, no provision for federal or state income taxes was recorded prior to the corporate reorganization as the Company's equity holders were responsible for income tax on the Company's profits. In connection with the closing of the Company's initial public offering, the Company merged into a corporation and became subject to federal and state income taxes. The Company's book and tax basis in assets and liabilities differed at the time of the corporate reorganization due primarily to different cost recovery periods utilized for book and tax purposes for the Company's oil and natural gas properties. See Note 11.
	Earnings (Loss) Per Share
	Basic earnings (loss) per common share is calculated by dividing net income available to common shareholders by the weighted average number of common shares outstanding during each period. Diluted earnings (loss) per common share is calculated by dividing net income available to common shareholders by the weighted average number of diluted common shares outstanding, which includes the effect of potentially dilutive securities. Potentially dilutive securities for the diluted earnings per share calculations consist of unvested restricted stock awards and outstanding stock options (if any) using the treasury method, as well as the Company's Series A Preferred Stock using the if-converted method. In the computation of diluted earnings per share, excess tax benefits that would be created upon the assumed vesting of unvested restricted shares or the assumed exercise of stock options (i.e. hypothetical excess tax benefits) are included in the assumed proceeds component of the treasury share method to the extent that such excess tax benefits are more likely than not to be realized. When a loss from continuing operations exists, all potentially dilutive securities are anti-dilutive and are therefore excluded from the computation of diluted earnings per share.
	Recent Accounting Pronouncements
	The Company reviewed recently issued accounting pronouncements that became effective during the twelve months ended December 31, 2013, and determined that none would have a material impact on the Company's consolidated financial statements with the exception of the adoption of ASU 2011-11, "Disclosures About Offsetting Assets and Liabilities", which the Company adopted on January 1, 2013 and that applies to the disclosures regarding commodity derivative contracts discussed in Note 4.
	Correction of the 2012 Net Deferred Tax Liability
	In the third quarter of 2013, the Company determined that its 2012 accounting for the tax impacts of the merger of certain entities that occurred in connection with the Company's initial public offering was in error. The Company identified that certain tax attributes acquired from the merged entities were not properly identified. Because the tax attributes were acquired as a result of a merger of entities under common control, the impacts of these tax attributes should have been recorded through equity at the time the Company became a taxable entity.
	To correct the 2012 tax error, the Company has restated the accompanying Consolidated Balance Sheet and the Consolidated Statement of Changes in Stockholders'/Members Equity as of December 31, 2012. There was no impact to the Consolidated Statements of Operations or the Consolidated Statement of Cash Flows for the year ended December 31, 2012. The impact of the correction is shown in the table below (in thousands):
		December 31, 2012
	Balance Sheet	As Previously		As Restated
		Reported
	Deferred income taxes	$	190,625	$	156,737
	Total long-term liabilities		905,002		871,114
	Additional paid-in-capital		830,003		863,891
	Total stockholders' equity		643,581		677,469

Fair_Value_Measurements_of_Fin

Fair Value Measurements of Financial Instruments	12 Months Ended
	Dec. 31, 2013
Fair Value Measurements of Financial Instruments	'
Fair Value Measurements of Financial Instruments	'
	3. Fair Value Measurements of Financial Instruments
	The Company uses a valuation framework based upon inputs that market participants use in pricing an asset or liability, which are classified into two categories: observable inputs and unobservable inputs. Observable inputs represent market data obtained from independent sources; whereas, unobservable inputs reflect a company's own market assumptions, which are used if observable inputs are not reasonably available without undue cost and effort. These two types of inputs are further divided into the following fair value input hierarchy:
	•
	Level 1—Inputs are unadjusted quoted prices in active markets for identical assets or liabilities at the measurement date.
	•
	Level 2—Inputs, other than quoted prices included in Level 1, are observable for the asset or liability, either directly or indirectly. Level 2 inputs include quoted prices for similar instruments in active markets, and inputs other than quoted prices that are observable for the asset or liability. Fair value assets and liabilities that are generally included in this category are commodity derivative contracts with fair values based on inputs from actively quoted markets. The Company uses a discounted cash flow approach to estimate the fair values of its commodity derivative contracts, utilizing commodity futures price strips for the underlying commodities provided by a reputable third-party.
	•
	Level 3—Inputs are unobservable for the asset or liability, and include situations where there is little, if any, market activity for the asset or liability.
	Assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. The Company's assessment of the significance of a particular input to the fair value measurement requires judgment, and may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels.
	Assets and Liabilities Measured at Fair Value on a Recurring Basis
	Derivative Instruments—Commodity derivative contracts reflected in the consolidated balance sheets are recorded at estimated fair value. At December 31, 2013 and 2012, all of the Company's commodity derivative contracts were with seven and five bank counterparties, respectively, and are classified as Level 2.
		Fair Value Measurements at December 31, 2013
		Quoted Prices		Significant		Significant		Total
		in Active		Other		Unobservable
		Markets		Observable		Inputs
		(Level 1)		Inputs		(Level 3)
				(Level 2)
		(in thousands)
	Assets:
	Commodity derivative NGL swaps	$	—	$	469	$	—	$	469
	Commodity derivative gas swaps		—		488		—		488
	Commodity derivative oil collars		—		64		—		64
	Commodity derivative gas collars		—		751		—		751
	Commodity derivative differential swaps		—		806		—		806
	Total assets	$	—	$	2,578	$	—	$	2,578
	Liabilities:
	Commodity derivative oil swaps	$	—	$	32,209	$	—	$	32,209
	Commodity derivative NGL swaps		—		74		—		74
	Commodity derivative gas swaps		—		809		—		809
	Commodity derivative oil collars		—		272		—		272
	Commodity derivative gas collars		—		26		—		26
	Total liabilities	$	—	$	33,390	$	—	$	33,390
		Fair Value Measurements at December 31, 2012
		Quoted Prices		Significant		Significant		Total
		in Active		Other		Unobservable
		Markets		Observable		Inputs
		(Level 1)		Inputs		(Level 3)
				(Level 2)
		(in thousands)
	Assets:
	Commodity derivative oil swaps	$	—	$	16,133	$	—	$	16,133
	Commodity derivative NGL swaps		—		2,353		—		2,353
	Commodity derivative oil collars		—		428		—		428
	Commodity derivative gas collars		—		2,026		—		2,026
	Commodity derivative differential swaps		—		2,661		—		2,661
	Total assets	$	—	$	23,601	$	—	$	23,601
	Liabilities:
	Commodity derivative oil swaps	$	—	$	15,091	$	—	$	15,091
	Commodity derivative NGL swaps		—		458		—		458
	Commodity derivative oil collars		—		287		—		287
	Commodity derivative gas collars		—		185		—		185
	Commodity derivative differential swaps		—		11,693		—		11,693
	Total liabilities	$	—	$	27,714	$	—	$	27,714
	Derivative instruments listed above are presented gross and include collars and swaps that are carried at fair value. The Company records the net change in the fair value of these positions in "Losses on commodity derivative contracts—net" in the Company's consolidated statements of operations. See Note 4 for additional information on the Company's derivative instruments and balance sheet presentation.

Risk_Management_and_Derivative

Risk Management and Derivative Instruments	12 Months Ended
	Dec. 31, 2013
Risk Management and Derivative Instruments	'
Risk Management and Derivative Instruments	'
	4. Risk Management and Derivative Instruments
	The Company is exposed to fluctuations in crude oil, NGLs and natural gas prices. The Company believes it is prudent to manage the variability in cash flows by entering into derivative financial instruments to economically hedge a portion of its crude oil, NGLs and natural gas production. The Company utilizes various types of derivative financial instruments, including swaps, collars and options, to manage fluctuations in cash flows resulting from changes in commodity prices. These derivative contracts are placed with major financial institutions that the Company believes are minimal credit risks. The oil, NGLs and gas reference prices, upon which the commodity derivative contracts are based, reflect various market indices that management believes have a high degree of historical correlation with actual prices received by the Company for its oil, NGLs and natural gas production.
	Inherent in the Company's portfolio of commodity derivative contracts are certain business risks, including market risk and credit risk. Market risk is the risk that the price of the commodity will change, either favorably or unfavorably, in response to changing market conditions. Credit risk is the risk of loss from nonperformance by the Company's counterparty to a contract. The Company does not require collateral from its counterparties but does attempt to minimize its credit risk associated with derivative instruments by entering into derivative instruments only with counterparties that are large financial institutions, which management believes present minimal credit risk. In addition, to mitigate its risk of loss due to default, the Company has entered into agreements with its counterparties on its derivative instruments that allow the Company to offset its asset position with its liability position in the event of default by the counterparty. Due to the netting arrangements, had the Company's counterparties failed to perform under existing commodity derivative contracts, the maximum loss at December 31, 2013 would have been approximately $0.7 million.
	Commodity Derivative Contracts
	As of December 31, 2013, the Company had the following open commodity positions:
		Hedged			Weighted-Average
		Volume			Fixed Price
	Oil (Bbls):
	WTI Swaps—2014		4,344,450		$88.76
	WTI Swaps—2015		1,820,000		$86.55
	WTI Collars—2014		164,400		$88.49 - $97.94
	WTI to LLS Basis Differential Swaps—2014(1)		501,000		$5.35
	NGL (Bbls):
	NGL Swaps—2014		151,500		$62.16
	Natural Gas (MMBtu):
	Swaps—2014(2)		17,885,000		$4.17
	Swaps—2015		18,250,000		$4.13
	Collars—2014(3)		1,685,004		$3.99 - $5.09
	-1
	The Company enters into swap arrangements intended to fix the positive differential between the Louisiana Light Sweet ("LLS") pricing and West Texas Intermediate ("NYMEX WTI") pricing.
	-2
	Includes 1,519,000 MMBtu that priced in the fourth quarter of 2013, but had not cash settled as of December 31, 2013.
	-3
	Includes 64,667 MMBtu that priced in the fourth quarter of 2013, but had not cash settled as of December 31, 2013.
	Balance Sheet Presentation
	The following table summarizes the gross fair value of derivative instruments by the appropriate balance sheet classification, even when the derivative instruments are subject to netting arrangements and qualify for net presentation in the Company's consolidated balance sheets at December, 2013 and 2012, respectively (in thousands):
	Type	Balance Sheet Location(1)		December 31,			December 31,
				2013			2012
	Oil Swaps	Derivative financial instruments—Current Assets		$	—		$	16,004
	Oil Swaps	Derivative financial instruments—Non-Current Assets			—			129
	Oil Swaps	Derivative financial instruments—Current Liabilities			(28,871	)		(11,485	)
	Oil Swaps	Derivative financial instruments—Non-Current Liabilities			(3,338	)		(3,606	)
	NGL Swaps	Derivative financial instruments—Current Assets			469			1,624
	NGL Swaps	Derivative financial instruments—Non-Current Assets			—			729
	NGL Swaps	Derivative financial instruments—Current Liabilities			(74	)		(336	)
	NGL Swaps	Derivative financial instruments—Non-Current Liabilities			—			(122	)
	Gas Swaps	Derivative financial instruments—Current Assets			469			—
	Gas Swaps	Derivative financial instruments—Non-Current Assets			19			—
	Gas Swaps	Derivative financial instruments—Current Liabilities			(496	)		—
	Gas Swaps	Derivative financial instruments—Non-Current Liabilities			(313	)		—
	Oil Collars	Derivative financial instruments—Current Assets			64			221
	Oil Collars	Derivative financial instruments—Non-Current Assets			—			207
	Oil Collars	Derivative financial instruments—Current Liabilities			(272	)		(238	)
	Oil Collars	Derivative financial instruments—Non-Current Liabilities			—			(49	)
	Gas Collars	Derivative financial instruments—Current Assets			751			1,129
	Gas Collars	Derivative financial instruments—Non-Current Assets			—			897
	Gas Collars	Derivative financial instruments—Current Liabilities			(26	)		(112	)
	Gas Collars	Derivative financial instruments—Non-Current Liabilities			—			(73	)
	Basis Differential Swaps	Derivative financial instruments—Current Assets			806			2,625
	Basis Differential Swaps	Derivative financial instruments—Non-Current Assets			—			36
	Basis Differential Swaps	Derivative financial instruments—Current Liabilities			—			(11,319	)
	Basis Differential Swaps	Derivative financial instruments—Non-Current Liabilities			—			(374	)
	Total derivative fair value at period end			$	(30,812	)	$	(4,113	)
	-1
	The fair values of commodity derivative instruments reported in the Company's consolidated balance sheets are subject to netting arrangements and qualify for net presentation. The following table summarizes the location and fair value amounts of all derivative instruments in the consolidated balance sheets, as well as the gross recognized derivative assets, liabilities and amounts offset in the consolidated balance sheets at December 31, 2013 and 2012, respectively (in thousands):
				December 31, 2013
	Not Designated as	Balance Sheet Classification		Gross			Gross			Net Recognized
	ASC 815 Hedges:			Recognized			Amounts			Fair Value Assets/
				Assets/			Offset			Liabilities
				Liabilities
	Derivative assets:
	Commodity contracts	Derivative financial instruments—current		$	2,559		$	1,859		$	700
	Commodity contracts	Derivative financial instruments—noncurrent			19			—			19
			$	2,578		$	1,859		$	719
Derivative liabilities:
Commodity contracts	Derivative financial instruments—current		$	29,739		$	1,859		$	27,880
Commodity contracts	Derivative financial instruments—noncurrent			3,651			—			3,651
			$	33,390		$	1,859		$	31,531
			December 31, 2012
Not Designated as	Balance Sheet Classification		Gross			Gross			Net Recognized
ASC 815 Hedges:			Recognized			Amounts			Fair Value Assets/
			Assets/			Offset			Liabilities
			Liabilities
Derivative assets:
Commodity contracts	Derivative financial instruments—current		$	21,603		$	15,908		$	5,695
Commodity contracts	Derivative financial instruments—noncurrent			1,998			281			1,717
			$	23,601		$	16,189		$	7,412
Derivative liabilities:
Commodity contracts	Derivative financial instruments—current		$	23,490		$	15,908		$	7,582
Commodity contracts	Derivative financial instruments—noncurrent			4,224			281			3,943
			$	27,714		$	16,189		$	11,525
Gains/Losses on Commodity Derivative Contracts
The Company does not designate its commodity derivative contracts as hedging instruments for financial reporting purposes. Accordingly, commodity derivative contracts are marked-to-market each quarter with the change in fair value during the periodic reporting period recognized currently as a gain or loss in "Losses on commodity derivative contracts—net" within revenues in the audited consolidated statements of operations. Realized gains and losses represent the actual settlements under commodity derivative contracts that require making a payment to or receiving a payment from the counterparty, as well as any deferred premiums payable to the counterparty upon contract settlement. During the year ended December 31, 2012, the Company paid deferred premiums of $3.3 million related to put options covering a total of 549,000 barrels of crude oil, respectively. No such payments for deferred premiums were made during 2013.
The following table presents realized net losses and unrealized net (losses) gains recorded by the Company in "Losses on commodity derivative contracts—net" related to the change in fair value of the commodity derivative instruments for the periods presented:
	For the Year Ended December 31,
	2013			2012			2011
	(in thousands)
Realized net losses	$	(17,585	)	$	(15,825	)	$	(16,733	)
Unrealized net (losses) gains		(26,699	)		4,667			11,889

Property_and_Equipment

Property and Equipment	12 Months Ended
	Dec. 31, 2013
Property and Equipment	'
Property and Equipment	'
	5. Property and Equipment
	The Company's property and equipment as of December 31, 2013 and 2012 was as follows (in thousands):
		December 31,			December 31,
		2013			2012
		(in thousands)
	Oil and gas properties, on the basis of full-cost accounting:
	Proved properties	$	2,817,062		$	1,522,723
	Unevaluated properties		243,599			313,941
	Other property and equipment		11,113			5,038
	Less accumulated depreciation, depletion, amortization and impairment		(976,880	)		(274,294	)
	Net property and equipment	$	2,094,894		$	1,567,408
	For the years ended December 31, 2013, 2012 and 2011, depletion expense related to oil and gas properties was $248.2 million, $125.1 million and $91.4 million, respectively and $28.42, $34.17 and $33.40 per barrel of oil equivalent ("Boe"), respectively. For the years ended December 31, 2013, 2012 and 2011, depreciation expense related to other property and equipment was $2.2 million, $0.5 million and $0.3 million, respectively.
	For the years ended December 31, 2013, 2012 and 2011, interest capitalized to unevaluated properties was $32.2 million, $11.2 million and $2.6 million, respectively. For the years ended December 31, 2013 and 2012, the Company capitalized $8.4 million and $1.5 million, respectively, of internal costs to oil and gas properties, including $1.4 million and $0.2 million, respectively, of qualifying share based compensation expense (see Note 10).

Acquisition_of_Oil_and_Gas_Pro

Acquisition of Oil and Gas Properties	12 Months Ended
	Dec. 31, 2013
Acquisition of Oil and Gas Properties	'
Acquisition of Oil and Gas Properties	'
	6. Acquisition of Oil and Gas Properties
	Anadarko Basin Acquisition—May 2013
	On May 31, 2013, the Company closed on the acquisition of producing properties and undeveloped acreage in the Anadarko Basin in Texas and Oklahoma from Panther Energy Company, LLC and its partners for approximately $618 million in cash (before customary post-closing adjustments). The Company funded the purchase price of the Anadarko Basin Acquisition with a portion of the net proceeds from the private placement of $700 million in aggregate principal amount of 9.25% senior unsecured notes due 2021, which also closed on May 31, 2013.
	The transaction was accounted for using the acquisition method of accounting which requires, among other things, that assets acquired and liabilities assumed be recognized at their fair values as of the acquisition date. The final determination of fair value for certain assets and liabilities remains preliminary and will be completed after post-closing purchase price adjustments are finalized no later than one year from the acquisition date.
	The following table summarizes (in thousands) the preliminary estimate of the assets acquired and liabilities assumed in the acquisition. The final determination of the certain assets and liabilities will be completed as soon as the post-closing purchase price adjustments are finalized. These amounts will be finalized as soon as practicable, but no later than one year from the acquisition date.
		Anadarko Basin
		Acquisition
	Oil and gas properties
	Proved	$	418,287
	Unevaluated		207,789
	Total assets acquired	$	626,076
	Asset retirement obligations		6,296
	Total liabilities assumed	$	6,296
	Net assets acquired	$	619,780
	The fair values of oil and natural gas properties and asset requirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of oil and natural gas properties include estimates of: (i) oil and gas reserves; (ii) future operating and development costs; (iii) future commodity prices; (iv) estimated future cash flows; and (v) market based weighted average cost of capital. Significant inputs to the valuation of asset retirement obligations include estimates of: (i) the timing of future plugging and abandonment activities; (ii) future plugging and abandonment costs; and (iii) market based weighted average cost of capital. These inputs require significant judgments and estimates by the Company's management at the time of the valuation and are the most sensitive and subject to change.
	Eagle Property Acquisition—October 2012
	On October 1, 2012, the Company closed on the Eagle Property Acquisition. The assets acquired include certain interests in producing oil and natural gas assets and unevaluated leasehold acreage in Oklahoma and Kansas and related hedging instruments. The aggregate purchase price, before adjustments for expenses incurred and revenue received by Eagle from June 1, 2012 through the closing date and other customary post-closing purchase price adjustments, consisted of (a) $325 million in cash and (b) 325,000 shares of Series A Preferred Stock with an initial liquidation preference of $1,000/share. The Company funded the cash portion of the Eagle Property Acquisition purchase price with a portion of the net proceeds from the private placement (which also closed on October 1, 2012) of $600 million in aggregate principal amount of 10.75% senior unsecured notes due October 1, 2020.
	The transaction was accounted for using the acquisition method of accounting . The fair value of, and the allocation to, the assets acquired and liabilities assumed in the Eagle Property Acquisition has been finalized and is shown in the following table (in thousands):
		Eagle Property
		Acquisition
	Oil and gas properties:
	Proved	$	419,549
	Unevaluated		244,236
	Commodity derivative contracts		8,453
	Total assets acquired	$	672,238
	Asset retirement obligations		2,662
	Deferred income tax liabilities		25,985
	Commodity derivative contracts		—
	Total liabilities assumed	$	28,647
	Net assets acquired	$	643,591
	The finalized balances in the table above include immaterial changes to the amounts originally allocated to oil and gas properties and deferred income tax liabilities. These changes were required to reflect the final consideration paid after adjustments for certain post-closing purchase price amounts.
	Other Property Acquisitions
	On April 1, 2013, the Company exercised preference rights and acquired additional acreage and producing wells in its Gulf Coast region for $3.4 million.
	Actual and Pro Forma Impact of Acquisitions—unaudited
	Revenues attributable to the Anadarko Basin Acquisition included in the Company's consolidated statements of operations for the year ended December 31, 2013 were $104.7 million. Revenues attributable to the Eagle Property Acquisition, included in the Company's consolidated statements of operations for the year ended December 31, 2012 were $28.4 million.
	The following table presents unaudited pro forma information for the Company as if the Eagle Property Acquisition occurred on January 1, 2011 and the Anadarko Basin Acquisition occurred on January 1, 2012:
		For the Year Ended December 31,
		2013(1)			2012(2)			2011(3)
	Revenues and other	$	539,562		$	490,241		$	287,119
	Net income (loss)		(340,400	)		(129,885	)		21,066
	Preferred stock dividends		(15,589	)		(26,000	)		(26,000	)
	Net loss attributable to common shareholders	$	(355,989	)	$	(155,885	)	$	(4,934	)
	Net loss per common share—basic and diluted	$	(5.41	)	$	(2.60	)		N/A
	-1
	Includes the effect of the Anadarko Basin Acquisition, as the Eagle Property Acquisition was included in the historical results for this period.
	-2
	Includes the effect of the Eagle Property Acquisition and the Anadarko Basin Acquisition.
	-3
	Includes the effect of the Eagle Property Acquisition.
	The historical financial information was adjusted to give effect to the pro forma events that were directly attributable to the Eagle Property Acquisition and the Anadarko Basin Acquisition and are factually supportable. The unaudited pro forma consolidated results are not necessarily indicative of what the Company's consolidated results of operations actually would have been had the Eagle Property Acquisition been completed on January 1, 2011 and if the Anadarko Basin Acquisition had been completed on January 1, 2012. In addition, the unaudited pro forma consolidated results do not purport to project the future results of operations for the combined Company.
	Acquisition and Transaction Expenses
	For the year ended December 31, 2013, acquisition and transaction costs are costs the Company has incurred as a result of the Anadarko Basin Acquisition and include advisory, legal, accounting, valuation and other professional and consulting fees; and general and administrative costs. For the year ended December 31, 2013, the Company recorded $11.8 million of such expenses.
	For the year ended December 31, 2012, acquisition and transaction costs are costs the Company has incurred as a result of the Eagle Property Acquisition and include finders' fees; advisory, legal, accounting, valuation and other professional and consulting fees; and acquisition related general and administrative costs. For the year ended December 31, 2012, the Company recorded $14.9 million of such expenses.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligations	'
Asset Retirement Obligations	'
	7. Asset Retirement Obligations
	For the Company, asset retirement obligations represent the future abandonment costs of tangible assets, such as wells, service assets and other facilities. The fair value of the asset retirement obligation at inception is capitalized as part of the carrying amount of the related long-lived assets. Asset retirement obligations approximated $26.3 million and $15.2 million as of December 31, 2013 and 2012, respectively. The liability has been accreted to its present value as of December 31, 2013 and 2012. The Company evaluated its wells and determined a range of abandonment dates through 2071. At December 31, 2013, all asset retirement obligations represent long-term liabilities and are classified as such.
	The following table details the change in the asset retirement obligations for the years ended December 31, 2013, 2012 and 2011, respectively (in thousands):
		Year ended December 31,
		2013			2012		2011
	Asset retirement obligations at beginning of year	$	15,245		$	7,627	$	2,859
	Liabilities incurred		2,535			3,044		1,294
	Liabilities assumed in Anadarko Basin Acquisition		6,296			—		—
	Liablities assumed in Eagle Property Acquisition		—			2,662		—
	Revisions		858			1,189		3,196
	Liabilities settled		(61	)		—		(56	)
	Current period accretion expense		1,435			723		334
	Asset retirement obligations at end of year	$	26,308		$	15,245	$	7,627
	Revisions during the year ended December 31, 2013 were due to an increase in estimated future abandonment costs based upon higher oilfield service pricing. Revisions during the year ended December 31, 2012 were due to an increase in estimated future abandonment costs for our Gulf Coast wells based upon higher oilfield service pricing and a change in the Company's approach to site remediation based upon expected environmental and regulatory requirements.

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2013
Long-Term Debt	'
Long-Term Debt	'
	8. Long-Term Debt
	The Company's long-term debt as of December 31, 2013 and 2012 is as follows:
		At December 31,
		2013		2012
		(in thousands)
	Revolving credit facility, due 2018	$	401,150	$	94,000
	Senior notes, due 2020		600,000		600,000
	Senior notes, due 2021		700,000		—
	Long-term debt	$	1,701,150	$	694,000
	Reserve-based Credit Facility
	As of December 31, 2013, the Company's credit facility consisted of a $750 million senior revolving credit facility (the "Credit Facility") with a borrowing base of $500 million, as recently redetermined on September 26, 2013, when the borrowing base was increased from $425 million. At December 31, 2013, outstanding letters of credit obligations total $0.2 million.
	The Credit Facility matures on May 31, 2018 and borrowings thereunder are secured by substantially all of the Company's oil and natural gas properties and currently bear interest at LIBOR plus an applicable margin, depending upon the Company's borrowing base utilization, between 1.75% and 2.75% per annum. At December 31, 2013 and December 31, 2012, the weighted average interest rate was 2.5% and 2.5%, respectively.
	In addition to interest expense, the Credit Facility requires the payment of a commitment fee each quarter. The commitment fee is computed at the rate of either 0.375% or 0.50% per annum based on the average daily amount by which the borrowing base exceeds the outstanding borrowings during each quarter.
	The borrowing base under the Credit Facility is subject to semiannual redeterminations in April and October and up to one additional time per six month period following each scheduled borrowing base redetermination, as may be requested by the Company or the administrative agent, acting on behalf of lenders holding at least two-thirds of the outstanding loans and other obligations. The next scheduled borrowing base redetermination date is October 1, 2014, assuming the financing discussed in Note 15 closes as planned.
	Under the terms of the Credit Facility, the Company is required to repay the amount by which the principal balance of its outstanding loans and its letter of credit obligations exceed its redetermined borrowing base. The Company is permitted to make such repayment in six equal successive monthly payments commencing 30 days following the administrative agent's notice regarding such borrowing base reduction.
	On September 26, 2013, the Company entered into the Assignment and Fourth Amendment to the Second Amended and Restated Credit Agreement among the Company, as parent, Midstates Sub, as borrower, SunTrust Bank as administrative agent, and the other lenders and parties party thereto (the "Fourth Amendment").
	The Fourth Amendment amended the Credit Facility to provide that the Company's ratio of total net indebtedness to EBITDA for the trailing four fiscal quarter period ending on the last day of such fiscal quarter cannot exceed (i) 4.75:1.0, for the fiscal quarters ending December 31, 2013 and March 31, 2014, (ii) 4.50:1.0, for the fiscal quarters ending June 30, 2014, (iii) 4.25:1.0, for the fiscal quarters ending September 30, 2014 and December 31, 2014, and (iv) 4.00:1.0, for the fiscal quarter ending March 31, 2015 and each fiscal quarter thereafter. The Company also agreed to pay a one-time fee of 0.50% to each lender on the portion of their commitment to the borrowing base under the Fourth Amendment in excess of their commitment prior to the Fourth Amendment, and a one-time fee of 0.10% to each lender on the lesser of such lenders commitment immediately prior to, or after giving effect to, the Fourth Amendment.
	The Credit Facility contains financial covenants, in addition to the maximum ratio of debt to EBITDA discussed above, which, among other things, set a minimum current ratio (as defined therein) of not less than 1.0 to 1.0 and various other standard affirmative and negative covenants including, but not limited to, restrictions on the Company's ability to make any dividends, distributions or redemptions.
	As of December 31, 2013, the Company was in compliance with the minimum current ratio and the ratio of debt to EBITDA covenants as set forth in the Credit Facility. The Company's current ratio at December 31, 2013 was 1.3 to 1.0. At December 31, 2013, the Company's ratio of debt to EBITDA was 4.4 to 1.0.
	Based upon the recent amendments to the Credit Facility, the Company believes its carrying amount at December 31, 2013 approximates its fair value (Level 2) due to the variable nature of the applicable interest rate and current financing terms available to the Company.
	2020 Senior Notes
	On October 1, 2012, the Company issued $600 million in aggregate principal amount of 10.75% senior notes due 2020 (the "2020 Outstanding Notes") in a private placement conducted pursuant to Rule 144A and Regulation S under the Securities Act of 1933, as amended (the "Securities Act"). On October 29, 2013, substantially all of the 2020 Outstanding Notes were exchanged for an equal principal amount of registered 10.75% senior subordinated notes due 2020 pursuant to an effective registration statement on Form S-4 filed on August 30, 2013 under the Securities Act (the "2020 Exchange Notes"). The 2020 Exchange Notes are identical to the 2020 Outstanding Notes except that the 2020 Exchange Notes are registered under the Securities Act and do not have restrictions on transfer, registration rights or provisions for additional interest. As used in this Form 10-K, the term "2020 Senior Notes" refers to both the 2020 Outstanding Notes and the 2020 Exchange Notes. The 2020 Senior Notes were co-issued on a joint and several basis by the Company and its wholly owned subsidiary, Midstates Sub. The Company does not have any operations or independent assets other than its 100% ownership interest in Midstates Sub and there are no other subsidiaries of the Company. The 2020 Senior Notes Indenture does not create any restricted assets within Midstates Sub, nor does it impose any significant restrictions on the ability of Midstates Sub to pay dividends or make loans to the Company or limit the ability of the Company to advance loans to Midstates Sub.
	At any time prior to October 1, 2015, the Company may, under certain circumstances, redeem up to 35% of the aggregate principal amount of the 2020 Senior Notes with the net proceeds of a public or private equity offering at a redemption price of 110.75% of the principal amount of the 2020 Senior Notes, plus any accrued and unpaid interest up to the redemption date. In addition, at any time before October 1, 2016, the Company may redeem all or a part of the 2020 Senior Notes at a redemption price equal to 100% of the principal amount of 2020 Senior Notes redeemed plus the Applicable Premium (as defined in the Indenture) at the redemption date, plus any accrued and unpaid interest and Additional Interest (as defined in the Indenture), if any, up to, the redemption date. On or after October 1, 2016, the Company may redeem all or a part of the 2020 Senior Notes at varying redemption prices (expressed as percentages of principal amount) set forth in the Indenture plus accrued and unpaid interest and Additional Interest (as defined in the Indenture), if any, on the 2020 Senior Notes redeemed, up to, the redemption date.
	The Indenture contains covenants that, among other things, restrict the Company's ability to: (i) incur additional indebtedness, guarantee indebtedness or issue certain preferred shares; (ii) make loans, investments and other restricted payments; (iii) pay dividends on or make other distributions in respect of, or repurchase or redeem, capital stock; (iv) create or incur certain liens; (v) sell, transfer or otherwise dispose of certain assets; (vi) enter into certain types of transactions with the Company's affiliates; (vii) consolidate, merge or sell substantially all of the Company's assets; (viii) prepay, redeem or repurchase certain debt; (ix) alter the business the Company conducts and (x) enter into agreements restricting the ability of the Company's current and any future subsidiaries to pay dividends.
	Upon the occurrence of certain change of control events, as defined in the Indenture, each holder of the 2020 Senior Notes will have the right to require that the Company repurchase all or a portion of such holder's 2020 Senior Notes in cash at a purchase price equal to 101% of the aggregate principal amount thereof plus any accrued and unpaid interest to the date of repurchase.
	The estimated fair value of the 2020 Senior Notes was $648.0 million as of December 31, 2013 (Level 2 in the fair value measurement hierarchy based on the limited trading volume on the secondary market), based on quoted market prices for these same debt securities. The effective annual interest rate for the 2020 Senior Notes was approximately 11.1% for the years ended December 31, 2013 and 2012.
	2021 Senior Notes
	On May 31, 2013, the Company issued $700 million in aggregate principal amount of 9.25% senior notes due 2021 (the "2021 Outstanding Notes") in a private placement conducted pursuant to Rule 144A and Regulation S under the Securities Act. On October 29, 2013, all of the 2021 Outstanding Notes were exchanged for an equal principal amount of registered 9.25% senior subordinated notes due 2021 pursuant to an effective registration statement on Form S-4 filed on August 30, 2013 under the Securities Act (the "2021 Exchange Notes"). The 2021 Exchange Notes are identical to the 2021 Outstanding Notes except that the 2021 Exchange Notes are registered under the Securities Act and do not have restrictions on transfer, registration rights or provisions for additional interest. As used in this Form 10-K, the term "2021 Senior Notes" refers to both the 2021 Outstanding Notes and the 2021 Exchange Notes. The proceeds from the offering of $700 million (net of the initial purchasers' discount and related offering expenses) were used to fund the Anadarko Basin Acquisition and the related expenses, to pay the expenses related to an amendment to the Company's revolving credit facility, to repay $34.3 million in outstanding borrowings under the Company's Credit Facility, and for general corporate purposes.
	The 2021 Senior Notes rank pari passu in right of payment with the 2020 Senior Notes.
	The 2021 Senior Notes were co-issued on a joint and several basis by the Company and its wholly owned subsidiary, Midstates Sub. The Company does not have any operations or independent assets other than its 100% ownership interest in Midstates Sub and there are no other subsidiaries of the Company. The 2021 Senior Notes indenture does not create any restricted assets within Midstates Sub, nor does it impose any significant restrictions on the ability of Midstates Sub to pay dividends or make loans to the Company or limit the ability of the Company to advance loans to Midstates Sub.
	On or prior to May 31, 2014, the Company may redeem up to $100.0 million of aggregate principal amount of the 2021 Senior Notes with the net cash proceeds from any Equity Offerings (as such term is defined in the 2021 Senior Notes Indenture) at a redemption price equal to 103% of the principal amount plus accrued and unpaid interest.
	Prior to June 1, 2016, the Company may, under certain circumstances, redeem up to 35% of the aggregate principal amount of the 2021 Senior Notes (less the amount of 2021 Senior Notes redeemed pursuant to the preceding paragraph) with the net proceeds of any Equity Offerings at a redemption price of 109.25% of the principal amount of the 2021 Senior Notes redeemed, plus any accrued and unpaid interest, if any, up to the redemption date. In addition, at any time before June 1, 2016, the Company may redeem all or a part of the 2021 Senior Notes at a redemption price equal to 100% of the principal amount of the 2021 Senior Notes redeemed plus the Applicable Premium (as defined in the Indenture) at the redemption date, plus any accrued and unpaid interest and Additional Interest (as defined in the 2021 Senior Notes Indenture), if any, up to, the redemption date. On or after October 1, 2016, the Company may redeem all or a part of the 2021 Senior Notes at varying redemption prices (expressed as percentages of principal amount) set forth in the 2021 Senior Notes Indenture plus accrued and unpaid interest and Additional Interest (as defined in the 2021 Senior Notes Indenture), if any, on the 2021 Senior Notes redeemed, up to, the redemption date.
	The terms of the covenants and change in control provisions in the 2021 Senior Notes Indenture are substantially identical to those of the 2020 Senior Notes discussed above.
	The estimated fair value of the 2021 Senior Notes was $724.5 million as of December 31, 2013 (Level 2 in the fair value measurement hierarchy based on the limited trading volume on the secondary market), based on quoted market prices for these same debt securities. The effective annual interest rate for the 2021 Senior Notes was approximately 9.5% for the year ended December 31, 2013.

Mandatorily_Redeemable_Convert

Mandatorily Redeemable Convertible Preferred Units	12 Months Ended
	Dec. 31, 2013
Mandatorily Redeemable Convertible Preferred Units	'
Mandatorily Redeemable Convertible Preferred Units	'
	9. Mandatorily Redeemable Convertible Preferred Units
	In December 2011, Holdings LLC, FR Midstates Holdings LLC ("FR Midstates") and Midstates Petroleum Holdings, Inc. ("Petroleum Inc.") entered into an amended and restated limited liability company agreement, which was later amended in March 2012, to provide for the issuance of up to 65,000, or $65 million in aggregate value, of certain mandatorily redeemable convertible preferred units (the "Preferred Units") between December 15, 2011 and June 10, 2015. The Preferred Units had a liquidation value of $1,000 per unit and bore interest, compounded quarterly, at a rate of 8% plus the greater of LIBOR or 1.5%. The Preferred Units were convertible into units of Holdings LLC on or after the one year anniversary of the date of issuance into a number of common units with a fair market value (as determined by the Board of Directors) equal to the liquidation value plus any accrued interest and were redeemable for cash at any time at the option of Holdings LLC, but were mandatorily redeemable for cash on June 10, 2015, unless otherwise converted. In addition, a fixed interest charge of 1.5% of the aggregate capital invested in the Preferred Units was payable upon redemption or conversion.
	On January 4, 2012, and again on February 9, 2012, Holdings LLC issued 20,000 Preferred Units (for a total of 40,000 Preferred Units) to FR Midstates for aggregate cash proceeds of $40.0 million. On April 3, 2012, Holdings LLC issued an additional 25,000 preferred units to FR Midstates for aggregate cash proceeds of $25.0 million.
	On April 26, 2012, the Company used $67.1 million of the proceeds from its initial public offering to redeem the Preferred Units in full, including interest and other charges. As such, at December 31, 2012, the Preferred Units are no longer outstanding. The Company recorded $2.1 million related to interest expense associated with these Preferred Units for the year ended December 31, 2012. There was no related interest expense for the year ended December 31, 2013.

Equity_and_ShareBased_Compensa

Equity and Share-Based Compensation	12 Months Ended
	Dec. 31, 2013
Equity and Share-Based Compensation	'
Equity and Share-Based Compensation	'
	10. Equity and Share-Based Compensation
	Common and Preferred Shares
	At December 31, 2011, Holdings LLC had 256,742 common units issued and outstanding. On April 24, 2012, in connection with the Company's initial public offering, a corporate reorganization occurred and each common unit of Holdings LLC was converted into approximately 185.5 common shares of the Company and as a result, the Company issued 47,634,353 shares of its common stock.
	On April 25, 2012, the Company completed its initial public offering of common stock pursuant to a registration statement on Form S-1 (File 333-177966), as amended and declared effective by the SEC on April 19, 2012. Pursuant to the registration statement, the Company registered the offer and sale of 27,600,000 shares of $0.01 par value common stock, which included 6,000,000 shares of stock sold by the selling shareholders and 3,600,000 shares of common stock sold by the selling stockholders pursuant to an option granted to the underwriters to cover over-allotments.
	After the corporate reorganization and the completion of its initial public offering discussed above, the Company is authorized to issue up to a total of 300,000,000 shares of its common stock with a par value of $0.01 per share, and 50,000,000 shares of its preferred stock with a par value of $0.01 per share. Holders of the Company's common shares are entitled to one vote for each share held of record on all matters submitted to a vote of stockholders and to receive ratably in proportion to the shares of common stock held by them any dividends declared from time to time by the board of directors. The common shares have no preferences or rights of conversion, exchange, pre-exemption or other subscription rights.
	With respect to preferred shares, the Company is authorized, without further stockholder approval, to establish and issue from time to time one or more classes or series of preferred stock with such powers, preferences, rights, qualifications, limitations and restrictions as determined by its board of directors.
	Series A Preferred Stock
	In connection with the Eagle Property Acquisition, on September 28, 2012, the Company designated 325,000 shares of Series A Mandatorily Convertible Preferred Stock (the "Series A Preferred Stock") with an initial liquidation preference of $1,000 per share and an 8% per annum dividend, payable semiannually at the Company's option in cash or through an increase in the liquidation preference. The Series A Preferred Shares are convertible after October 1, 2013, in whole but not in part and at the option of the holders of a majority of the outstanding shares of Series A Preferred Stock, into a number shares of the Company's common stock calculated by dividing the then-current liquidation preference by the conversion price of $13.50 per share and, if not previously converted, are mandatorily convertible at September 30, 2015 into shares of the Company's common stock at a conversion price no greater than $13.50 per share and no less than $11.00 per share, with the ultimate conversion price dependent upon the volume weighted average price of the Company's common stock during the 15 trading days immediately prior to September 30, 2015. The Series A Preferred Stock was issued on October 1, 2012.
	On March 30, 2013, the Company elected to pay the $13 million semi-annual dividend due on that date through an increase in the Series A Preferred Stock liquidation preference to $1,040. As a result, the Company will be obligated to issue between 962,963 and 1,181,818 additional shares of common stock upon conversion of the Series A Preferred Stock, with the ultimate number of shares dependent upon the conversion price then in effect as described above.
	On September 30, 2013, the Company elected to pay the $13.5 million semi-annual dividend due on that date through an increase in the Series A Preferred Stock liquidation preference to $1,082. As a result, the Company will be obligated to issue between 1,001,481 and 1,229,091 additional shares of common stock upon conversion of the Series A Preferred Stock, with the ultimate number of shares dependent upon the conversion price then in effect as discussed above.
	For the three months ended December 31, 2013, the $6.3 million Series A Preferred Stock dividend was based upon the estimated fair value of 639,127 common shares that would have been issued had the notional dividend amount of $7.0 million been converted into common shares at a conversion price of $11.00 per share.
	For the twelve months ended December 31, 2013, the $15.6 million Series A Preferred Stock dividend was based upon the estimated fair value of 2,459,127 common shares that would have been issued had the notional dividend amounts for the year of $27.1 million been converted into common shares at a conversion price of $11.00 per share.
	The following table demonstrates the number of shares to be issued upon conversion through December 31, 2013 at the respective conversion rates based upon the current liquidation preference:
		Conversion at			Conversion at
		$13.50/share			$11.00/share
	Number of Common Shares Issuable Upon Conversion		26,077,807			32,004,582
	Share Activity
	The following table summarizes changes in the number of outstanding shares since January 1, 2011:
		Number of Shares
		Series A			Common			Treasury
		Preferred			Stock			Stock
		Stock
	Share count as of January 1, 2011		—			—			—
	Share count as of December 31, 2011		—			—			—
	Issuance of common stock in pre IPO reorganization		—			47,634,353			—
	Proceeds from the sale of common stock to public		—			18,000,000			—
	Issuance of preferred stock as consideration in Eagle Property Acquisition		—			—			—
	Share based compensation grants of restricted stock		—			1,029,509			—
	Forfeitures of restricted stock					(44,151	)		—
	Share count as of December 31, 2012		325,000			66,619,711			—
	Grants of restricted stock		—			2,840,241			—
	Forfeitures of restricted stock		—			(534,207	)		—
	Acquisition of treasury stock		—			—			(118,702	)
	Share count as of December 31, 2013		325,000			68,925,745			(118,702	)
	At December 31, 2013, the Company had 68,925,745 and 68,807,043 shares of its common stock issued and outstanding, respectively, and 325,000 shares of Series A Preferred Stock issued and outstanding.
	Share-Based Compensation, pre Initial Public Offering
	During the year ended December 31, 2011, certain restricted and unrestricted shares in Petroleum Inc., through which Holdings LLC's founders, members of management and certain employees previously held their equity interests, certain unrestricted units in Holdings LLC, and certain units in Midstates Incentive Holdings, LLC ("Midstates Incentive") had been issued to employees of Holdings LLC.
	Additionally, in March 2011, Holdings LLC's Chief Executive Officer, in connection with the commencement of his employment, purchased 17.3 shares of common stock of Petroleum Inc. and contemporaneously received a grant of 24.6 shares of common stock in Petroleum Inc. that vested as described further below. No other shares or units were issued during the 2011 period. The Company determined the grant date fair value of the share based award to be $80,013 per Petroleum Inc. share ($3.4 million in aggregate), or after taking into account the corporate reorganization attributable to the initial public offering completed on April 25, 2012, $4.26 per share of the Company's common stock. The Company recognized stock compensation based upon the grant date fair value and immediately expensed the difference between the grant date fair value and the price paid for the purchased shares of Petroleum Inc., as well as additional compensation expense related to the liability accounting for the Company's share-based awards discussed below.
	Prior to December 5, 2011, due to certain rights to call shares and units in Holdings LLC for cash, Holdings LLC's share-based payments awarded to employees were accounted for as liability awards. As such, Holdings LLC calculated the fair value of the share-based awards on a quarterly basis using estimated market value and the total fair value of the awards was recorded within "Other long-term liabilities" in Holding LLC's consolidated balance sheets. Any change in the fair value of the liability awards was recorded as share-based compensation expense within "General and administrative expense" in Holdings LLC's consolidated statements of operations, which was the same line item as cash compensation paid to the same employees.
	Historically, Holdings LLC's determination of the fair value of each of the units was affected by: (i) Holdings LLC's risk adjusted proved, possible, and probable reserves; (ii) internal assessment of long-term commodity prices; (iii) current values of Holdings LLC's non-oil and gas assets and liabilities; and (iv) a number of complex and subjective variables. Although the fair value of the share-based payments is determined in accordance with GAAP, that value may not be indicative of the fair value observed in a market transaction between a willing buyer and a willing seller.
	Effective as of November 22, 2011, the Board of Directors of Petroleum Inc. accelerated the vesting of all restricted stock in Petroleum Inc. The vesting resulted in the recognition of previously unrecognized share-based compensation expense at the estimated fair market value of the restricted stock held by employees at November 22, 2011. Petroleum Inc. determined the fair market value of Petroleum Inc.'s common stock based on management's estimates.
	On December 5, 2011, Employment Agreements with employees of Midstates Petroleum Company LLC, a Stockholders' Agreement by and among stockholders in Petroleum Inc. and a Unitholders' Agreement by and among the members of Holdings LLC were either terminated or amended such that the rights within those agreements to call shares in Petroleum Inc. and units in Holdings LLC for cash no longer required Holdings LLC's share-based payments awarded to employees to be accounted for as liability awards. As a result the Company transitioned as of December 5, 2011 from liability accounting to equity accounting for the Company's share-based compensation plans and accordingly, the Company no longer recognized changes in the estimated fair value of outstanding share-based awards in the statements of operations.
	Restricted Shares.
	Restricted shares in Petroleum Inc. were awarded at no cost to the recipient with a vesting period that commenced on the grant date and terminated on the fifth anniversary or upon certain changes in control of Holdings LLC, including but not limited to mergers, acquisitions, or a public offering.
	As a result of the vesting on November 22, 2011, as discussed above, there is no unrecognized compensation cost and as a result of the corporate reorganization in April 2012, each share of Petroleum Inc. was converted into 18,762 shares of the Company's common stock. As a result, there are no outstanding restricted shares in Petroleum Inc. as of December 31, 2013.
	Unrestricted Shares and Units.
	Unrestricted shares in Petroleum Inc. and units of Holdings LLC were either purchased by the recipient on the grant date and were fully vested upon purchase, or represented restricted shares which vested. For shares of Petroleum Inc. and units of Holdings LLC purchased, any difference between the recipient's purchase price and the grant date fair value was recognized as compensation expense on the grant date. As a result of the corporate reorganization in April 2012, each share of Petroleum, Inc. and each unit of Holdings LLC were converted into 18,762 and 185.5 shares respectively, of the Company's common stock. As a result, at December 31, 2013, there are no Petroleum, Inc. shares or Holdings LLC units outstanding.
	Incentive Units.
	At December 31, 2013, 1,513 incentive units were issued and outstanding. In connection with the corporate reorganization that occurred immediately prior to our initial public offering, these incentive units held in the Company were contributed to FR Midstates Interholding, LP ("FRMI") in exchange for incentive units in FRMI. Holders of FRMI incentive units will receive, out of proceeds otherwise distributable to FRMI, a percentage interest in the amounts distributed to FRMI in excess of certain multiples of FRMI's aggregate capital contributions and investment expenses ("FRMI Profits"). Although any future payments to the incentive unit holders will be made out of the proceeds otherwise distributable to FRMI and not by the Company, the Company will be required to record a non-cash compensation charge in the period any payment is made related to the FRMI incentive units. To date, no compensation expense related to the incentive units has been recognized by the Company, as any payout under the incentive units is not considered probable, and thus, the amount of FRMI Profits, if any, cannot be determined.
	Share-based Compensation, Post-Initial Public Offering
	2012 Long Term Incentive Plan.
	The Company established the 2012 Long Term Incentive Plan (the "2012 LTIP") and filed a Form S-8 with the SEC, registering 6,563,435 shares for future issuance under the terms of the 2012 LTIP. The 2012 LTIP provides a means for the Company to attract and retain employees, directors and consultants, and a method whereby employees, directors and consultants of the Company who contribute to its success can acquire and maintain stock ownership or awards, the value of which is tied to the performance of the Company, thereby strengthening their concern for the welfare of the Company and their desire to remain employed.
	The 2012 LTIP provides for the granting of Options (Incentive and other), Restricted Stock Awards, Restricted Stock Units, Stock Appreciation Rights, Dividend Equivalents, Bonus Stock, Other Stock-Based Awards, Annual Incentive Awards, Performance Awards, or any combination of the foregoing (the "Awards"). Subject to certain limitations as defined in the 2012 LTIP, the terms of each Award are as determined by the Compensation Committee of the Board of Directors. A total of 6,563,435 common share Awards are authorized for issuance under the 2012 LTIP and shares of stock subject to an Award that expire, or are canceled, forfeited, exchanged, settled in cash or otherwise terminated, will again be available for future Awards under the 2012 LTIP.
	Non-vested Stock Awards.
	Subsequent to the completion of the Company's initial public offering and pursuant to the 2012 LTIP, through December 31, 2013 the Company had 2,963,672 shares of restricted common stock to directors, management and employees outstanding. Shares granted under the LTIP generally vest ratably over a period of three years (one-third on each anniversary of the grant), however, beginning in 2013, shares granted under the 2012 LTIP to directors are subject to one-year cliff vesting.
	The fair value of restricted stock grants is based on the value of the Company's common stock on the date of grant. Compensation expense is recognized ratably over the requisite three year service period.
	The following table summarizes the Company's non-vested share award activity for the years ended December 31, 2013 and 2012:
		Shares			Weighted
					Average
					Grant Date
					Fair Value
	Non-vested shares outstanding at December 31, 2011		—		$	—
	Granted		1,029,509		$	12.63
Vested		—		$	—
Forfeited		(44,151	)	$	12.99
Non-vested shares outstanding at December 31, 2012		985,358		$	12.61
Granted		2,840,241		$	6.82
Vested		(327,720	)	$	12.62
Forfeited		(534,207	)	$	8.65
Non-vested shares outstanding at December 31, 2013		2,963,672		$	7.78
Unrecognized expense as of December 31, 2013 for all outstanding restricted stock awards, adjusted for estimated forfeitures, was $16.3 million and will be recognized over a weighted average period of 2.08 years.
At December 31, 2013, 3,272,043 shares remain available for issuance under the terms of the 2012 LTIP.
The following table summarizes share-based compensation costs (net of amounts capitalized to oil and gas properties) recognized as general and administrative expense by the Company for the periods presented (in thousands):
	For the Years
	Ended December 31,
	2013			2012			2011
Restricted and unrestricted Petroleum Inc. shares and Holdings LLC units	$	—		$	—		$	53,744
Incentive units		—			—			—
2012 LTIP restricted shares		5,713			2,459			—
Total share-based compensation expense	$	5,713		$	2,459		$	53,744
For the years ended December 31, 2013 and 2012, the Company capitalized $1.4 million and $0.2 million, respectively, of qualifying share-based compensation costs to oil and gas properties.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Taxes	'
Income Taxes	'
	11. Income Taxes
	Prior to its corporate reorganization (See Note 1), the Company was a limited liability company and not subject to federal income tax or state income tax (in most states). Accordingly, no provision for federal or state income taxes was recorded prior to the corporate reorganization as the Company's equity holders were responsible for income tax on the Company's profits. In connection with the closing of the Company's initial public offering, the Company merged into a corporation and became subject to federal and state income taxes. The Company's book and tax basis in assets and liabilities differed at the time of the corporate reorganization due primarily to different cost recovery methodology utilized for book and tax purposes for the Company's oil and natural gas properties. In the quarter ended June 30, 2012, the Company recorded a one-time charge to income tax expense of $149.5 million to recognize this deferred tax liability related to the Company's change in tax status caused by the initial public offering.
	The Company incurred a tax net operating loss ("NOL") in the current year due principally to the ability to expense certain intangible drilling and development costs under current law. There is no tax refund available to the Company, nor is there any current income tax payable. In light of the impairment of oil and gas properties, Management has recorded a $45.7 million valuation allowance against the Company's federal and State of Louisiana NOLs, as management does not believe that it is more-likely-than-not that this portion of the Company's NOLs are realizable. Management believes that the balance of the Company's NOLs are realizable only to the extent of future taxable income primarily related to the excess of book carrying value of properties over their respective tax bases. No other sources of future taxable income are considered in this judgment.
	The Company's NOLs were incurred in the tax years 2012 and 2013, and U.S. federal and State of Oklahoma NOLs will generally be available for use through the tax years 2032 and 2033, respectively, and its State of Louisiana NOLs are generally available through 2027 and 2028, respectively. The State of Texas currently has no NOL carryover provision. The Company believes that Section 382 of the Internal Revenue Code of 1986, as amended, which relates to tax attribute limitations upon the 50% or greater change of ownership of an entity during any three-year look back period, will not have an adverse effect on future NOL usage.
	On September 13, 2013, the US Treasury and IRS issued final Tangible Property Regulations ("TPR") under IRC Section 162 and IRC Section 263(a). The regulations are not effective until tax years beginning on or after January 1, 2014; however, certain portions may require an accounting method change on a retroactive basis, thus requiring a IRC Section 481(a) adjustment related to fixed and real asset deferred taxes. The accounting rules under ASC 740 treat the release of the regulations as a change in tax law as of the date of issuance and require the Company to determine whether there will be an impact on its financial statements for the period ended December 31, 2013. Any such impact of the final tangible property regulations would affect temporary deferred taxes only and result in a balance sheet reclassification within non-current deferred taxes. The Company has analyzed the expected impact of the TPR on the Company and concluded that the expected impact is minimal. The Company will continue to monitor the impact of any future changes to the TPR on the Company prospectively.
	As of December 31, 2013, the Company has not recorded a reserve for any uncertain tax positions. No income tax payments are expected in the upcoming four quarterly reporting periods.
		Year Ended December 31,
		2013			2012(1)
	Current
	United States	$	—		$	—
	State		—			—
	Total current		—			—
	Deferred
	United States		(130,906	)		137,496
	State		(15,623	)		20,390
	Total deferred		(146,529	)		157,886
	Total income tax provision (benefit)	$	(146,529	)	$	157,886
	-1
	For the 2011 comparable period, the calculation is not applicable as the Company was not a taxable entity until April 25, 2012.
	The Company's estimated income tax expense differs from the amount derived by applying the statutory federal rate to pretax income principally due the effect of the following items (in thousands):
		Year Ended December 31,
		2013			2012(1)
	Income before taxes	$	(490,514	)	$	7,789
	Statutory rate		35	%		35	%
	Income tax expense computed at statutory rate	$	(171,680	)	$	2,726
	Reconciling items:
	Non-deductible pre-IPO loss		—			4,561
	State income taxes, net of federal tax benefit		(10,886	)		1,053
	Change in valuation allowance		45,688
	Change in state rate		(10,500	)
	Other, net		849			57
	Change in tax status(2)		—			149,489
	Tax provision (benefit)	$	(146,529	)	$	157,886
	-1
	For the 2011 comparable period, the calculation is not applicable as the Company was not a taxable entity until April 25, 2012.
	-2
	The change in tax status for the year ended December 31, 2012 is split between federal of $130.2 million and state of $19.3 million.
	Deferred income taxes primarily represent the net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for income tax purposes. The components of our deferred taxes are detailed in the table below (in thousands):
		December 31,			December 31,
		2013			2012(1)(2)
	Deferred tax assets—current
	Derivative instruments and other	$	15,581		$	6,027
	Less valuation allowance		(3,744	)		—
	Total deferred tax assets, current	$	11,837		$	6,027
	Deferred tax assets—noncurrent
	US tax loss carryforwards		151,872			90,735
	State tax loss carryforwards		14,154			12,258
	Employee benefit plans		1,539			985
	Less valuation allowance		(41,944	)		—
	Total deferred tax assets, noncurrent	$	125,621		$	103,978
	Deferred tax liabilities—noncurrent
	Oil and gas properties and equipment(1)		140,912			260,715
	Total deferred tax liabilities, noncurrent	$	140,912		$	260,715
	Reflected in the accompanying balance sheet as:
	Net deferred tax asset, current	$	11,837		$	6,027
	Net deferred tax liability noncurrent	$	15,291		$	156,737
	-1
	For December 31, 2012, oil and gas properties and equipment includes a deferred tax liability of $26.7 million which was recognized as a result of the Eagle Property Acquisition. The difference originated in the tax bases and the recognized value for GAAP purposes of the assets acquired and liabilities assumed in the Eagle Property Acquisition.
	-2
	In the third quarter of 2013, the Company determined that its 2012 accounting for the tax impacts of the merger of certain entities that occurred in connection with the Company's initial public offering was in error. The Company identified that certain tax attributes acquired from the merged entities were not properly identified. Because the tax attributes were acquired as a result of a merger of entities under common control, the impacts of these tax attributes should have been recorded through equity at the time the Company became a taxable entity.

Earnings_Loss_Per_Share

Earnings (Loss) Per Share	12 Months Ended
	Dec. 31, 2013
Earnings (Loss) Per Share	'
Earnings (Loss) Per Share	'
	12. Earnings (Loss) Per Share
	The Company's Series A Preferred Stock issued in connection with the Eagle Property Acquisition has the nonforfeitable right to participate on an as converted basis at the conversion rate then in effect in any common stock dividends declared and as such, is considered a participating security. The Company's nonvested stock awards, which are granted as part of the 2012 LTIP, contain nonforfeitable rights to dividends and as such, are considered to be participating securities and, together with the Series A Preferred Stock, are included in the computation of basic and diluted earnings (loss) per share, pursuant to the two-class method. In the calculation of basic earnings (loss) per share attributable to common shareholders, participating securities are allocated earnings based on actual dividend distributions received plus a proportionate share of undistributed net income attributable to common shareholders, if any, after recognizing distributed earnings. The Company's participating securities do not participate in undistributed net losses because they are not contractually obligated to do so.
	The computation of diluted earnings per share attributable to common shareholders reflects the potential dilution that could occur if securities or other contracts to issue common shares that are dilutive were exercised or converted into common shares (or resulted in the issuance of common shares) and would then share in the earnings of the Company. During the periods in which the Company records a loss from continuing operations attributable to common shareholders, securities would not be dilutive to net loss per share and conversion into common shares is assumed to not occur. Diluted net income per share attributable to common shareholders is calculated under both the two-class method and the treasury stock method; the more dilutive of the two calculations is presented below.
	The following table (in thousands, except per share amounts) provides a reconciliation of net losses to preferred shareholders, common shareholders, and participating securities for purposes of computing net loss per share for the year ended December 31, 2013:
		Total			Series A		Common			Non-vested
					Preferred		Stock			Restricted
					Stock					Stock(2)
	Net loss	$	(343,985	)	$	—	$	(343,985	)	$	—
	Preferred Dividend(1)	$	(15,589	)		—		(15,589	)		—
	Calculated allocation of net loss attributable to shareholders	$	(359,574	)	$	—	$	(359,574	)	$	—
	Weighted average shares outstanding							65,766
	Net loss per share						$	(5.47	)
	-1
	Calculation of the preferred stock dividend is discussed in Note 10.
	-2
	As these shares are participating securities that participate in earnings, but are not required to participate in losses, this calculation demonstrates that there is not an allocation of the loss to the non-vested restricted stockholders.
	The following table (in thousands, except per share amounts) provides a reconciliation of net losses to preferred shareholders, common shareholders, and non-vested restricted shareholders for purposes of computing net loss per share for the year ended December 31, 2012:
		Total			Series A		Common			Non-vested
					Preferred		Stock			Restricted
					Stock					Stock(2)
	Net loss	$	(150,097	)	$	—	$	(150,097	)	$	—
	Preferred Dividend(1)	$	(6,500	)		—		(6,500	)		—
	Calculated allocation of net loss attributable to shareholders	$	(156,597	)	$	—	$	(156,597	)	$	—
	Weighted average shares outstanding							59,979
	Net loss per share						$	(2.61	)
	-1
	Calculation of the preferred stock dividend is discussed in Note 10.
	-2
	As these shares are participating securities that participate in earnings, but are not required to participate in losses, this calculation demonstrates that there is not an allocation of the loss to the non-vested restricted stockholders.

Concentrations_of_Credit_Risk

Concentrations of Credit Risk	12 Months Ended
	Dec. 31, 2013
Concentrations of Credit Risk	'
Concentrations of Credit Risk	'
	13. Concentrations of Credit Risk
	Financial instruments which potentially subject the Company to credit risk consist primarily of cash balances, accounts receivable and derivative financial instruments.
	The Company maintains cash and cash equivalents in bank deposit accounts which, at times, may exceed the federally insured limits. The Company has not experienced any significant losses from such investments. The Company attempts to limit the amount of credit exposure to any one financial institution or company.
	The Company normally sells production to a relatively small number of purchasers, as is customary in the exploration, development and production business. The Company typically sells a substantial portion of production under short-term (usually one month) contracts tied to a local index. The Company does not have any long-term, fixed-price sales contracts. For the year ended December 31, 2013, five purchasers accounted for 28%, 16%, 13%, 12% and 11% respectively, of the Company's revenue. For the year ended December 31, 2012, three purchasers accounted for 41%, 32% and 10%, respectively, of the Company's revenue. For the year ended December 31, 2011, two purchasers accounted for 39% and 38%, respectively, of the Company's revenue.
	Substantially all of the Company's accounts receivable result from the sale of oil, natural gas and natural gas liquids. At December 31, 2013, three purchasers accounted for approximately 31%, 16%, and 13%, respectively, of the accounts receivable balance. At December 31, 2012, four purchasers accounted for approximately 38%, 18%, 14% and 10%, respectively, of the accounts receivable balance.
	Derivative financial instruments are generally executed with major financial institutions that expose the Company to market and credit risks and which may, at times, be concentrated with certain counterparties. The credit worthiness of the counterparties is subject to continual review. The Company also has netting arrangements in place with counterparties to reduce credit exposure. The Company has not experienced any losses from such instruments.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies	'
Commitments and Contingencies	'
	14. Commitments and Contingencies
	Contractual Obligations
	At December 31, 2013, contractual obligations for drilling contracts, long-term operating leases, seismic contracts and other contracts are as follows (in thousands):
		Total		2014		2015		2016		2017		2018 and
												beyond
	Drilling contracts	$	8,192	$	8,192	$	—	$	—	$	—	$	—
	Non-cancellable office lease commitments	$	11,052		1,732		1,857		1,877		1,941		3,645
	Seismic contracts	$	4,410		4,410		—		—		—		—
	Net minimum commitments	$	23,654	$	14,334	$	1,857	$	1,877	$	1,941	$	3,645
	For the years ended December 31, 2013, 2012 and 2011, the Company expensed $1.7 million, $1.1 million and $0.6 million, respectively, for office rent.
	In addition to the commitments noted in the above table, the Company is party to a gas transportation, gathering and processing contract (as amended and effective June 1, 2013) in the Mississippian Lime region which includes certain minimum natural gas and NGL volume commitments. To the extent the Company does not deliver natural gas volumes in sufficient quantities to generate, when processed, the minimum levels of recovered NGLs, the Company would be required to reimburse the counterparty an amount equal to the sum of the monthly shortfall, if any, multiplied by a fee of roughly $0.06 to $0.125 per gallon (subject to annual escalation). The NGL volume commitments range from 2,800 bbls to 5,460 bbls per day over the remaining term of the contract. Additionally, the Company is obligated to deliver a total of 38,100,000 MMBTUs and 76,200,000 MMBTUs during the first 30 months and 60 months of the contract, respectively. During the first 30 months, any shortfall in delivered volumes would result in a payment to the counterparty equal to the shortfall amount multiplied by a fee of approximately $0.36 per MMBTU. During the first 60 months, any shortfall in delivered volumes would result in a payment to the counterparty equal to the shortfall amount multiplied by a fee of approximately $0.36 per MMBTU, provided that the Company would receive volumetric credit for any deficiency payment made after the initial 30 months. The Company is currently delivering at least the minimum volumes required under these contractual provisions and does not expect to incur any future volumetric shortfall payments during the term of this contract.
	Commitments related to ARO's are not included in the table above; see Note 7 for discussion of those commitments.
	Litigation
	We are involved in disputes or legal actions arising in the ordinary course of our business. We may not be able to predict the timing or outcome of these or future claims and proceedings with certainty, and an unfavorable resolution of one or more of such matters could have a material adverse effect on our financial condition, results of operations or cash flows. Currently, we are not party to any legal proceedings that, individually or in the aggregate, are reasonably expected to have a material adverse effect on our financial position, results of operations, or cash flows.

Subsequent_Events

Subsequent Events	12 Months Ended
	Dec. 31, 2013
Subsequent Events	'
Subsequent Events	'
	15. Subsequent Events
	On March 5, 2014, the Company executed a Purchase and Sale Agreement ("PSA") to sell all of its ownership interest in developed and undeveloped acreage in the Pine Prairie field area of Evangeline Parish, Louisiana to a private buyer for a purchase price of $170 million in cash, subject to standard post-closing adjustments. Acreage subject to the transaction does not include the Company's acreage and production in the western part of Louisiana in Beauregard Parish or other undeveloped acreage held outside the Pine Prairie field. The proceeds from the sale will be used to pay down the Company's revolving credit facility. The PSA has an effective date of November 1, 2013 and is expected to close on May 1, 2014.
	Additionally, in order to provide additional capital resources during 2014, the Company entered into commitment letters with SunTrust Bank, SunTrust Robinson Humphrey, Inc., Morgan Stanley Senior Funding, Inc., Bank of America N.A., Goldman Sachs Bank USA, Merrill Lynch, Piece, Fenner & Smith Incorporated, Natixis New York Branch and Royal Bank of Canada on March 9, 2014 to, among other things, provide for a Senior Secured Bridge Facility ("Bridge Facility") in the amount of $125 million and to provide for a commitment ("RBL Backstop") to provide a backstop revolver credit facility in the event that an amendment to our existing revolving credit facility to permit the consummation of the Bridge Facility and a revised borrowing base of $475 million cannot be obtained.
	The Bridge Facility would be secured by a first priority lien on the Company's Gulf Coast assets and a second lien on its Mississippian and Anadarko assets. Any obligations under the Bridge Facility would be guaranteed by the same entities that guaranty the existing credit facility. Advances under the Bridge Facility would be available through September 30, 2014, would be funded in tranches of $50 million (subject to availability), initially bear interest at LIBOR plus 4.5% (subject to a 0.50% increase in interest rate at September 30, 2014, December 31, 2014 and March 31, 2015) and mature on the first anniversary of the closing date. Interest on any advances is payable quarterly in cash. Upon maturity, any amounts outstanding on the Bridge Facility would be converted into a senior secured term loan or, at any time thereafter at the option of the lenders, into senior secured exchange notes maturing in September 2019. Additionally, lenders under the Bridge Facility will have a securities demand if total liquidity (as defined therein) falls below $50 million, provided that this provision will not apply until June 1, 2014, so long as the executed PSA discussed above remains in place. The Bridge Facility would be pre-payable in whole or in part without penalty or premium and would be subject to mandatory prepayment in the event of Louisiana asset sales (including the Pine Prairie transaction discussed above), issuance of debt or equity, occurrence of a change in control or certain other events. The Company has agreed to pay a 1.75% commitment fee, a 1.25% funding fee and a 2.25% fee upon the rollover. The definitive loan documentation for the Bridge Facility will include certain representations and warranties, affirmative, negative and financial covenants and events of default customary for bridge loan financings, including limitations on incurrence of indebtedness that, prior to any rollover, will be more restrictive than those contained in the existing credit facility.
	In the event that an amendment accommodating the Bridge Facility, the transactions contemplated thereby and a borrowing base of $475 million cannot be obtained under the existing credit facility, the RBL Backstop provides a commitment to provide a new credit facility on substantially the same terms as the existing credit facility, including the notional amount of $750 million and a maturity date of May 2018, but with appropriate modifications to (i) release the Louisiana assets from the borrowing base facility to allow for the Bridge Facility and the potential sale pursuant to the PSA, (ii) reduce the borrowing base under the existing credit facility from $500 million to $475 million, (iii) increase the leverage ratio by 0.50 for the quarter of and the two quarters following the sale of Pine Prairie for net proceeds greater than $100 million, (iv) allow for the Bridge Facility to be secured by a second lien on the Mississippian and Anadarko assets, and (v) increase the applicable interest rate under the existing credit facility by 0.25%. Lenders participating in the RBL Backstop are to receive an underwriting fee of 0.25% whether the RBL Backstop is utilized or not. In the event the existing credit agreement is not amended for the above terms and the RBL Backstop is utilized, participating lenders will receive an additional underwriting fee of 1.00%. Other terms of the backstop credit facility would remain materially unchanged from those contained in the existing credit facility.
	The Company expects to execute the definitive documentation of the new reserve based credit facility and the Bridge Facility during first quarter of 2014.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies	'
Basis of Presentation	'
	Basis of Presentation
	The accompanying consolidated financial statements of the Company have been prepared pursuant to the rules and regulations of the Securities and Exchange Commission ("SEC") and have been prepared in accordance with generally accepted accounting principles in the United States of America ("GAAP").
	All intercompany transactions have been eliminated in consolidation. The consolidated financial statements as of and for the year ended December 31, 2013 include the results from the Anadarko Basin Acquisition beginning May 31, 2013. The consolidated financial statements as of and for the year ended December 31, 2012 include the results from the Eagle Property Acquisition beginning October 1, 2012.
Use of Estimates	'
	Use of Estimates
	The preparation of 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 financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
	Significant estimates include, but are not limited to, the amount of recoverable oil and natural gas reserves; future cash flows from oil and natural gas properties; the fair value of commodity derivative contracts; the fair value of share-based compensation; and the valuation of future asset retirement obligations.
Cash and Cash Equivalents	'
	Cash and Cash Equivalents
	The Company considers all short-term investments with an original maturity of three months or less to be cash equivalents.
Accounts Receivable and Allowance for Doubtful Accounts	'
	Accounts Receivable and Allowance for Doubtful Accounts
	Accounts receivable are stated at the historical carrying amount net of allowance for uncollectible accounts. The carrying amount of the Company's accounts receivable approximate fair value because of the short-term nature of the instruments. The Company accrues a reserve on a receivable when, based on the judgment of management, it is probable that a receivable will not be collected and the amount of any reserve may be reasonably estimated. As of December 31, 2013 and 2012, the Company had no allowance for doubtful accounts.
Financial Instruments	'
	Financial Instruments
	The Company's financial instruments consist of cash and cash equivalents, receivables, payables, debt, and commodity derivative contracts. Commodity derivative contracts are recorded at fair value (see Note 3). Based upon recent amendments to the Company's Credit Facility, the Company believes the carrying amount of the related floating-rate debt approximates fair value due to the variable nature of the interest rate and the current financing terms available to the Company. The carrying amount of the Company's other financial instruments approximate fair value because of the short-term nature of the items or variable pricing. See fair value discussion of Senior Notes and Series A Preferred Shares issued in October 2012 in Notes 8 and 10, respectively.
	Derivative financial instruments are recorded in the consolidated balance sheets as either an asset or liability measured at estimated fair value. Changes in the derivative's fair value are recognized currently in earnings as gains and losses in the period of change. The gains or losses are recorded in "Losses on commodity derivative contracts—net." The related cash flow impact is reflected within cash flows from operating activities.
Other Noncurrent Assets	'
	Other Noncurrent Assets
	At December 31, 2013, other noncurrent assets consisted of $44.7 million in deferred financing costs, $9.7 million in field inventory, and $0.2 million in other noncurrent assets. At December 31, 2012, other noncurrent assets consisted of $25.2 million in deferred financing costs and $0.2 million in other noncurrent assets. The increase in deferred financing costs is the result of approximately $19.3 million in deferred financing costs incurred during 2013 with the issuance of the 2021 Senior Notes.
Property and Equipment	'
	Property and Equipment
	Oil and Gas Properties
	The Company uses the full-cost method of accounting for its exploration and development activities. Under this method of accounting, the cost of both successful and unsuccessful exploration and development activities are capitalized as property and equipment. This includes any internal costs that are directly related to exploration and development activities, but does not include any costs related to production, general corporate overhead or similar activities. Proceeds from the sale or disposition of oil and gas properties are accounted for as a reduction to capitalized costs unless a significant portion of the Company's reserve quantities are sold that results in a significant alteration of the relationship between capitalized costs and remaining proved reserves, in which case a gain or loss is generally recognized in income.
	Unevaluated Property
	Oil and gas unevaluated properties and properties under development include costs that are not being depleted or amortized. These costs represent investments in unproved properties. The Company excludes these costs until proved reserves are found, until it is determined that the costs are impaired or until major development projects are placed in service, at which time the costs are moved into oil and natural gas properties subject to amortization. All unproved property costs are reviewed at least annually to determine if impairment has occurred.
	Oil and Gas Reserves
	Proved oil, NGLs and natural gas reserves utilized in the preparation of the consolidated financial statements are estimated in accordance with the rules established by the SEC and the Financial Accounting Standards Board (FASB), which require that reserve estimates be prepared under existing economic and operating conditions using a 12-month average price with no provision for price and cost escalations in future years except by contractual arrangements.
	Reserve estimates are inherently imprecise. Accordingly, the estimates are expected to change as more current information becomes available. The Company depletes its oil and gas properties using the units-of-production method. Capitalized costs of oil and natural gas properties subject to amortization are depleted over proved reserves. It is possible that, because of changes in market conditions or the inherent imprecision of reserve estimates, the estimates of future cash inflows, future gross revenues, the amount of oil and natural gas reserves, the remaining estimated lives of oil and natural gas properties, or any combination of the above may be increased or reduced. Increases in recoverable economic volumes generally reduce per unit depletion rates while decreases in recoverable economic volumes generally increase per unit depletion rates.
	Impairment of Oil and Gas Properties/Ceiling Test
	The Company performs a full-cost ceiling test on a quarterly basis. The test establishes a limit (ceiling) on the book value of oil and gas properties. The capitalized costs of proved oil and gas properties, net of accumulated depreciation, depletion and amortization (DD&A) and the related deferred income taxes, may not exceed this "ceiling." The ceiling limitation is equal to the sum of: (i) the present value of estimated future net revenues from the projected production of proved oil and gas reserves, excluding future cash outflows associated with settling asset retirement obligations accrued on the balance sheet, calculated using the average oil and natural gas sales price received by the Company as of the first trading day of each month over the preceding twelve months (such prices are held constant throughout the life of the properties) and a discount factor of 10%; (ii) the cost of unproved and unevaluated properties excluded from the costs being amortized; (iii) the lower of cost or estimated fair value of unproved properties included in the costs being amortized; and (iv) related income tax effects. If capitalized costs exceed this ceiling, the excess is charged to expense in the accompanying consolidated statements of operations. For the year ended December 31, 2013, capitalized costs exceeded the ceiling and an impairment of oil and gas properties of $319.6 million, after tax, was recorded.
	The most significant factors affecting the impairment related to the transfer of unevaluated property costs to the full cost pool during 2013 and negative reserve revisions in our Gulf Coast area. During 2013, we transferred $61.2 million of Gulf Coast unevaluated property costs to the full cost pool based upon our lack of future plans for further evaluation or development of those leases, and $168.4 million of Mississippian unevaluated property costs attributable to leases that expired during 2013 or that we currently intend to allow to expire in 2014. The negative reserve revisions in our Gulf Coast area were mainly attributable to variability in well performance, our decision during the second quarter to halt further development in our West Gordon field and unfavorable cost revisions. See Note 5.
	Depreciation, Depletion, and Amortization (DD&A)
	DD&A of oil and gas properties is calculated using the Units of Production Method (UOP). The UOP calculation, in its simplest terms, multiplies the percentage of estimated proved reserves produced by the cost of those reserves. The result is to recognize expense at the same pace that the reserves are estimated to be depleting. The amortization base in the UOP calculation includes the sum of proved property costs net of accumulated DD&A, estimated future development costs (future costs to access and develop proved reserves) and asset retirement costs that are not already included in oil and gas property, less related salvage value.
	Capitalized Interest
	Interest from external borrowings is capitalized on unevaluated properties using the weighted-average cost of outstanding borrowings until the project is substantially complete and ready for its intended use, which for oil and gas assets is at the first production from the field. Capitalized interest is depleted over the useful lives of the assets in the same manner as the depletion of the underlying assets. The Company paid cash interest of $104.3 million, $7.2 million, and $4.2 million for the years ended December 31, 2013, 2012 and 2011, respectively.
	Other Property and Equipment
	Other property and equipment consists of vehicles, furniture and fixtures, and computer hardware and software and are carried at cost. Depreciation is provided principally using the straight-line method over the estimated useful lives of the assets, which primarily range from three to seven years. Maintenance and repairs are charged to expense as incurred, while renewals and betterments are capitalized.
Accrued Liabilities	'
	Accrued Liabilities
	Accrued liabilities at December 31, 2013 consisted of $87.2 million in oil and gas capital expenditures, $64.4 million in accrued revenue and royalty distributions, $21.3 million in accrued interest, $8.3 million in accrued lease operating and workover expenses, $4.4 million in accrued taxes, and $18.8 million in other accrued liabilities. At December 31, 2012, the balance consisted of $69.0 million in oil and gas capital expenditures, $16.2 million in accrued interest, and $13.4 million in other accrued liabilities.
Asset Retirement Obligations	'
	Asset Retirement Obligations
	The legal obligations associated with the retirement of long-lived assets are recognized at estimated fair value at the time that the obligation is incurred.
	Oil and gas producing companies incur such a liability upon acquiring or drilling a well. The Company estimates the fair value of an asset retirement obligation in the period in which the obligation is incurred and can be reliably measured. The corresponding asset retirement cost is capitalized by increasing the carrying amount of the related long-lived asset. The liability is accreted to its then present value each period, and the capitalized cost is depreciated over the useful life of the related asset. If the liability is settled for an amount other than the recorded amount, any adjustment is recorded in the full cost pool. See Note 7.
Share-Based Compensation	'
	Share-Based Compensation
	We measure share-based compensation cost at fair value and generally recognize the corresponding compensation expense on a straight-line basis over the service period during which awards are expected to vest. We include share-based compensation expense, net of amounts capitalized to oil and gas properties, in "General and administrative expense" in our consolidated statements of operations. See Note 10.
Revenue Recognition	'
	Revenue Recognition
	Oil, NGLs and natural gas revenues are recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred and collection of the revenues is reasonably assured. Cash received relating to future revenues is deferred and recognized when all revenue recognition criteria are met.
	The Company follows the sales method of accounting for oil and gas revenues, whereby revenue is recognized for all oil and gas sold to purchasers regardless of whether the sales are proportionate to the Company's ownership interest in the property. Production imbalances are recognized as a liability to the extent an imbalance on a specific property exceeds the Company's share of remaining proved oil and gas reserves. The Company had no significant imbalances at December 31, 2013 or 2012.
Acquisition and Transaction Costs	'
	Acquisition and Transaction Costs
	Acquisition related costs are expensed as incurred and as services are received. Such costs include finders' fees; advisory, legal, accounting, valuation and other professional and consulting fees; and acquisition related general and administrative costs. Costs incurred in 2013 relate to the Anadarko Basin Acquisition and costs incurred in 2012 relate to the Eagle Property Acquisition. See Note 6.
Income Taxes	'
	Income Taxes
	Income taxes are provided for the tax effects of transactions reported in the financial statements and consist of taxes currently payable plus deferred income taxes related to certain income and expenses recognized in different periods for financial and income tax reporting purposes. Deferred income tax assets and liabilities represent the future tax return consequences of those differences, which will either be taxable or deductible when assets are recovered or liabilities are settled. Deferred income taxes also include tax credits and net operating losses that are available to offset future income taxes. Deferred income taxes are measured by applying currently enacted tax rates.
	The Company accounts for uncertainty in income taxes for tax positions taken or expected to be taken in a tax return. Only tax positions that meet the more-than-likely-than-not recognition threshold are recognized.
	Prior to its corporate reorganization (See Note 1), the Company was a limited liability company and not subject to federal income tax or state income tax (in most states). Accordingly, no provision for federal or state income taxes was recorded prior to the corporate reorganization as the Company's equity holders were responsible for income tax on the Company's profits. In connection with the closing of the Company's initial public offering, the Company merged into a corporation and became subject to federal and state income taxes. The Company's book and tax basis in assets and liabilities differed at the time of the corporate reorganization due primarily to different cost recovery periods utilized for book and tax purposes for the Company's oil and natural gas properties. See Note 11.
Earnings (Loss) Per Share	'
	Earnings (Loss) Per Share
	Basic earnings (loss) per common share is calculated by dividing net income available to common shareholders by the weighted average number of common shares outstanding during each period. Diluted earnings (loss) per common share is calculated by dividing net income available to common shareholders by the weighted average number of diluted common shares outstanding, which includes the effect of potentially dilutive securities. Potentially dilutive securities for the diluted earnings per share calculations consist of unvested restricted stock awards and outstanding stock options (if any) using the treasury method, as well as the Company's Series A Preferred Stock using the if-converted method. In the computation of diluted earnings per share, excess tax benefits that would be created upon the assumed vesting of unvested restricted shares or the assumed exercise of stock options (i.e. hypothetical excess tax benefits) are included in the assumed proceeds component of the treasury share method to the extent that such excess tax benefits are more likely than not to be realized. When a loss from continuing operations exists, all potentially dilutive securities are anti-dilutive and are therefore excluded from the computation of diluted earnings per share.
Recent Accounting Pronouncements	'
	Recent Accounting Pronouncements
	The Company reviewed recently issued accounting pronouncements that became effective during the twelve months ended December 31, 2013, and determined that none would have a material impact on the Company's consolidated financial statements with the exception of the adoption of ASU 2011-11, "Disclosures About Offsetting Assets and Liabilities", which the Company adopted on January 1, 2013 and that applies to the disclosures regarding commodity derivative contracts discussed in Note 4.
Correction of the 2012 Net Deferred Tax Liability	'
	Correction of the 2012 Net Deferred Tax Liability
	In the third quarter of 2013, the Company determined that its 2012 accounting for the tax impacts of the merger of certain entities that occurred in connection with the Company's initial public offering was in error. The Company identified that certain tax attributes acquired from the merged entities were not properly identified. Because the tax attributes were acquired as a result of a merger of entities under common control, the impacts of these tax attributes should have been recorded through equity at the time the Company became a taxable entity.
	To correct the 2012 tax error, the Company has restated the accompanying Consolidated Balance Sheet and the Consolidated Statement of Changes in Stockholders'/Members Equity as of December 31, 2012. There was no impact to the Consolidated Statements of Operations or the Consolidated Statement of Cash Flows for the year ended December 31, 2012. The impact of the correction is shown in the table below (in thousands):
		December 31, 2012
	Balance Sheet	As Previously		As Restated
		Reported
	Deferred income taxes	$	190,625	$	156,737
	Total long-term liabilities		905,002		871,114
	Additional paid-in-capital		830,003		863,891
	Total stockholders' equity		643,581		677,469

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2013
Summary of Significant Accounting Policies	'
Schedule of the impact of correction	'
	The impact of the correction is shown in the table below (in thousands):
		December 31, 2012
	Balance Sheet	As Previously		As Restated
		Reported
	Deferred income taxes	$	190,625	$	156,737
	Total long-term liabilities		905,002		871,114
	Additional paid-in-capital		830,003		863,891
	Total stockholders' equity		643,581		677,469

Fair_Value_Measurements_of_Fin1

Fair Value Measurements of Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Measurements of Financial Instruments	'
Schedule of commodity derivative contracts recorded at estimated fair value	'
		Fair Value Measurements at December 31, 2013
		Quoted Prices		Significant		Significant		Total
		in Active		Other		Unobservable
		Markets		Observable		Inputs
		(Level 1)		Inputs		(Level 3)
				(Level 2)
		(in thousands)
	Assets:
	Commodity derivative NGL swaps	$	—	$	469	$	—	$	469
	Commodity derivative gas swaps		—		488		—		488
	Commodity derivative oil collars		—		64		—		64
	Commodity derivative gas collars		—		751		—		751
	Commodity derivative differential swaps		—		806		—		806
	Total assets	$	—	$	2,578	$	—	$	2,578
	Liabilities:
	Commodity derivative oil swaps	$	—	$	32,209	$	—	$	32,209
	Commodity derivative NGL swaps		—		74		—		74
	Commodity derivative gas swaps		—		809		—		809
	Commodity derivative oil collars		—		272		—		272
	Commodity derivative gas collars		—		26		—		26
	Total liabilities	$	—	$	33,390	$	—	$	33,390
		Fair Value Measurements at December 31, 2012
		Quoted Prices		Significant		Significant		Total
		in Active		Other		Unobservable
		Markets		Observable		Inputs
		(Level 1)		Inputs		(Level 3)
				(Level 2)
		(in thousands)
	Assets:
	Commodity derivative oil swaps	$	—	$	16,133	$	—	$	16,133
	Commodity derivative NGL swaps		—		2,353		—		2,353
	Commodity derivative oil collars		—		428		—		428
	Commodity derivative gas collars		—		2,026		—		2,026
	Commodity derivative differential swaps		—		2,661		—		2,661
	Total assets	$	—	$	23,601	$	—	$	23,601
	Liabilities:
	Commodity derivative oil swaps	$	—	$	15,091	$	—	$	15,091
	Commodity derivative NGL swaps		—		458		—		458
	Commodity derivative oil collars		—		287		—		287
	Commodity derivative gas collars		—		185		—		185
	Commodity derivative differential swaps		—		11,693		—		11,693
	Total liabilities	$	—	$	27,714	$	—	$	27,714

Risk_Management_and_Derivative1

Risk Management and Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2013
Risk Management and Derivative Instruments	'
Schedule of entity's open commodity positions	'
	As of December 31, 2013, the Company had the following open commodity positions:
		Hedged			Weighted-Average
		Volume			Fixed Price
	Oil (Bbls):
	WTI Swaps—2014		4,344,450		$88.76
	WTI Swaps—2015		1,820,000		$86.55
	WTI Collars—2014		164,400		$88.49 - $97.94
	WTI to LLS Basis Differential Swaps—2014(1)		501,000		$5.35
	NGL (Bbls):
	NGL Swaps—2014		151,500		$62.16
	Natural Gas (MMBtu):
	Swaps—2014(2)		17,885,000		$4.17
	Swaps—2015		18,250,000		$4.13
	Collars—2014(3)		1,685,004		$3.99 - $5.09
	-1
	The Company enters into swap arrangements intended to fix the positive differential between the Louisiana Light Sweet ("LLS") pricing and West Texas Intermediate ("NYMEX WTI") pricing.
	-2
	Includes 1,519,000 MMBtu that priced in the fourth quarter of 2013, but had not cash settled as of December 31, 2013.
	-3
	Includes 64,667 MMBtu that priced in the fourth quarter of 2013, but had not cash settled as of December 31, 2013.
Schedule of location and fair values amounts of all derivative instruments as well as the gross recognized derivative assets, liabilities and amounts offset in the consolidated balance sheets	'
	The following table summarizes the gross fair value of derivative instruments by the appropriate balance sheet classification, even when the derivative instruments are subject to netting arrangements and qualify for net presentation in the Company's consolidated balance sheets at December, 2013 and 2012, respectively (in thousands):
	Type	Balance Sheet Location(1)		December 31,			December 31,
				2013			2012
	Oil Swaps	Derivative financial instruments—Current Assets		$	—		$	16,004
	Oil Swaps	Derivative financial instruments—Non-Current Assets			—			129
	Oil Swaps	Derivative financial instruments—Current Liabilities			(28,871	)		(11,485	)
	Oil Swaps	Derivative financial instruments—Non-Current Liabilities			(3,338	)		(3,606	)
	NGL Swaps	Derivative financial instruments—Current Assets			469			1,624
	NGL Swaps	Derivative financial instruments—Non-Current Assets			—			729
	NGL Swaps	Derivative financial instruments—Current Liabilities			(74	)		(336	)
	NGL Swaps	Derivative financial instruments—Non-Current Liabilities			—			(122	)
	Gas Swaps	Derivative financial instruments—Current Assets			469			—
	Gas Swaps	Derivative financial instruments—Non-Current Assets			19			—
	Gas Swaps	Derivative financial instruments—Current Liabilities			(496	)		—
	Gas Swaps	Derivative financial instruments—Non-Current Liabilities			(313	)		—
	Oil Collars	Derivative financial instruments—Current Assets			64			221
	Oil Collars	Derivative financial instruments—Non-Current Assets			—			207
	Oil Collars	Derivative financial instruments—Current Liabilities			(272	)		(238	)
	Oil Collars	Derivative financial instruments—Non-Current Liabilities			—			(49	)
	Gas Collars	Derivative financial instruments—Current Assets			751			1,129
	Gas Collars	Derivative financial instruments—Non-Current Assets			—			897
	Gas Collars	Derivative financial instruments—Current Liabilities			(26	)		(112	)
	Gas Collars	Derivative financial instruments—Non-Current Liabilities			—			(73	)
	Basis Differential Swaps	Derivative financial instruments—Current Assets			806			2,625
	Basis Differential Swaps	Derivative financial instruments—Non-Current Assets			—			36
	Basis Differential Swaps	Derivative financial instruments—Current Liabilities			—			(11,319	)
	Basis Differential Swaps	Derivative financial instruments—Non-Current Liabilities			—			(374	)
	Total derivative fair value at period end			$	(30,812	)	$	(4,113	)
	-1
	The fair values of commodity derivative instruments reported in the Company's consolidated balance sheets are subject to netting arrangements and qualify for net presentation. The following table summarizes the location and fair value amounts of all derivative instruments in the consolidated balance sheets, as well as the gross recognized derivative assets, liabilities and amounts offset in the consolidated balance sheets at December 31, 2013 and 2012, respectively (in thousands):
				December 31, 2013
	Not Designated as	Balance Sheet Classification		Gross			Gross			Net Recognized
	ASC 815 Hedges:			Recognized			Amounts			Fair Value Assets/
				Assets/			Offset			Liabilities
				Liabilities
	Derivative assets:
	Commodity contracts	Derivative financial instruments—current		$	2,559		$	1,859		$	700
	Commodity contracts	Derivative financial instruments—noncurrent			19			—			19
				$	2,578		$	1,859		$	719
	Derivative liabilities:
	Commodity contracts	Derivative financial instruments—current		$	29,739		$	1,859		$	27,880
	Commodity contracts	Derivative financial instruments—noncurrent			3,651			—			3,651
				$	33,390		$	1,859		$	31,531
				December 31, 2012
	Not Designated as	Balance Sheet Classification		Gross			Gross			Net Recognized
	ASC 815 Hedges:			Recognized			Amounts			Fair Value Assets/
				Assets/			Offset			Liabilities
				Liabilities
	Derivative assets:
	Commodity contracts	Derivative financial instruments—current		$	21,603		$	15,908		$	5,695
	Commodity contracts	Derivative financial instruments—noncurrent			1,998			281			1,717
				$	23,601		$	16,189		$	7,412
	Derivative liabilities:
	Commodity contracts	Derivative financial instruments—current		$	23,490		$	15,908		$	7,582
	Commodity contracts	Derivative financial instruments—noncurrent			4,224			281			3,943
				$	27,714		$	16,189		$	11,525
Schedule of net losses and unrealized net (losses) gains recorded by the Company in "Losses on commodity derivative contracts - net" related to the change in fair value of the commodity derivative instruments for the periods	'
		For the Year Ended December 31,
		2013			2012			2011
		(in thousands)
	Realized net losses	$	(17,585	)	$	(15,825	)	$	(16,733	)
	Unrealized net (losses) gains		(26,699	)		4,667			11,889

Property_and_Equipment_Tables

Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2013
Property and Equipment	'
Schedule of property and equipment	'
	The Company's property and equipment as of December 31, 2013 and 2012 was as follows (in thousands):
		December 31,			December 31,
		2013			2012
		(in thousands)
	Oil and gas properties, on the basis of full-cost accounting:
	Proved properties	$	2,817,062		$	1,522,723
	Unevaluated properties		243,599			313,941
	Other property and equipment		11,113			5,038
	Less accumulated depreciation, depletion, amortization and impairment		(976,880	)		(274,294	)
	Net property and equipment	$	2,094,894		$	1,567,408

Acquisition_of_Oil_and_Gas_Pro1

Acquisition of Oil and Gas Properties (Tables)	12 Months Ended
	Dec. 31, 2013
Acquisition of Oil and Gas Properties	'
Schedule of unaudited pro forma information as of the acquisition	'
		For the Year Ended December 31,
		2013(1)			2012(2)			2011(3)
	Revenues and other	$	539,562		$	490,241		$	287,119
	Net income (loss)		(340,400	)		(129,885	)		21,066
	Preferred stock dividends		(15,589	)		(26,000	)		(26,000	)
	Net loss attributable to common shareholders	$	(355,989	)	$	(155,885	)	$	(4,934	)
	Net loss per common share—basic and diluted	$	(5.41	)	$	(2.60	)		N/A
	-1
	Includes the effect of the Anadarko Basin Acquisition, as the Eagle Property Acquisition was included in the historical results for this period.
	-2
	Includes the effect of the Eagle Property Acquisition and the Anadarko Basin Acquisition.
	-3
	Includes the effect of the Eagle Property Acquisition.
Anadarko Basin Acquisition	'
Acquisition of Oil and Gas Properties	'
Schedule of fair value of the assets acquired and liabilities assumed in acquisition	'
	The following table summarizes (in thousands) the preliminary estimate of the assets acquired and liabilities assumed in the acquisition.
		Anadarko Basin
		Acquisition
	Oil and gas properties
	Proved	$	418,287
	Unevaluated		207,789
	Total assets acquired	$	626,076
	Asset retirement obligations		6,296
	Total liabilities assumed	$	6,296
	Net assets acquired	$	619,780
Eagle Property Acquisition	'
Acquisition of Oil and Gas Properties	'
Schedule of fair value of the assets acquired and liabilities assumed in acquisition	'
	The fair value of, and the allocation to, the assets acquired and liabilities assumed in the Eagle Property Acquisition has been finalized and is shown in the following table (in thousands):
		Eagle Property
		Acquisition
	Oil and gas properties:
	Proved	$	419,549
	Unevaluated		244,236
	Commodity derivative contracts		8,453
	Total assets acquired	$	672,238
	Asset retirement obligations		2,662
	Deferred income tax liabilities		25,985
	Commodity derivative contracts		—
	Total liabilities assumed	$	28,647
	Net assets acquired	$	643,591

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligations	'
Schedule of changes in the Company's ARO's	'
	The following table details the change in the asset retirement obligations for the years ended December 31, 2013, 2012 and 2011, respectively (in thousands):
		Year ended December 31,
		2013			2012		2011
	Asset retirement obligations at beginning of year	$	15,245		$	7,627	$	2,859
	Liabilities incurred		2,535			3,044		1,294
	Liabilities assumed in Anadarko Basin Acquisition		6,296			—		—
	Liablities assumed in Eagle Property Acquisition		—			2,662		—
	Revisions		858			1,189		3,196
	Liabilities settled		(61	)		—		(56	)
	Current period accretion expense		1,435			723		334
	Asset retirement obligations at end of year	$	26,308		$	15,245	$	7,627

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2013
Long-Term Debt	'
Schedule of the company's long term debt	'
		At December 31,
		2013		2012
		(in thousands)
	Revolving credit facility, due 2018	$	401,150	$	94,000
	Senior notes, due 2020		600,000		600,000
	Senior notes, due 2021		700,000		—
	Long-term debt	$	1,701,150	$	694,000

Equity_and_ShareBased_Compensa1

Equity and Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2013
Equity and Share-Based Compensation	'
Schedule of number of shares to be issued upon conversion at respective conversion rates based upon the current liquidation preference	'
	The following table demonstrates the number of shares to be issued upon conversion through December 31, 2013 at the respective conversion rates based upon the current liquidation preference:
		Conversion at			Conversion at
		$13.50/share			$11.00/share
	Number of Common Shares Issuable Upon Conversion		26,077,807			32,004,582
Summary of changes in the number of outstanding shares	'
		Number of Shares
		Series A			Common			Treasury
		Preferred			Stock			Stock
		Stock
	Share count as of January 1, 2011		—			—			—
	Share count as of December 31, 2011		—			—			—
	Issuance of common stock in pre IPO reorganization		—			47,634,353			—
	Proceeds from the sale of common stock to public		—			18,000,000			—
	Issuance of preferred stock as consideration in Eagle Property Acquisition		—			—			—
	Share based compensation grants of restricted stock		—			1,029,509			—
	Forfeitures of restricted stock					(44,151	)		—
	Share count as of December 31, 2012		325,000			66,619,711			—
	Grants of restricted stock		—			2,840,241			—
	Forfeitures of restricted stock		—			(534,207	)		—
	Acquisition of treasury stock		—			—			(118,702	)
	Share count as of December 31, 2013		325,000			68,925,745			(118,702	)
Company's non-vested share award activity	'
		Shares			Weighted
					Average
					Grant Date
					Fair Value
	Non-vested shares outstanding at December 31, 2011		—		$	—
	Granted		1,029,509		$	12.63
	Vested		—		$	—
	Forfeited		(44,151	)	$	12.99
	Non-vested shares outstanding at December 31, 2012		985,358		$	12.61
	Granted		2,840,241		$	6.82
	Vested		(327,720	)	$	12.62
	Forfeited		(534,207	)	$	8.65
	Non-vested shares outstanding at December 31, 2013		2,963,672		$	7.78
Summary of share-based compensation costs (net of amounts capitalized to oil and gas properties) recognized as general and administrative expense by the company	'
	The following table summarizes share-based compensation costs (net of amounts capitalized to oil and gas properties) recognized as general and administrative expense by the Company for the periods presented (in thousands):
		For the Years
		Ended December 31,
		2013			2012			2011
	Restricted and unrestricted Petroleum Inc. shares and Holdings LLC units	$	—		$	—		$	53,744
	Incentive units		—			—			—
	2012 LTIP restricted shares		5,713			2,459			—
	Total share-based compensation expense	$	5,713		$	2,459		$	53,744

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Taxes	'
Schedule of income tax provision	'
		Year Ended December 31,
		2013			2012(1)
	Current
	United States	$	—		$	—
	State		—			—
	Total current		—			—
	Deferred
	United States		(130,906	)		137,496
	State		(15,623	)		20,390
	Total deferred		(146,529	)		157,886
	Total income tax provision (benefit)	$	(146,529	)	$	157,886
	-1
	For the 2011 comparable period, the calculation is not applicable as the Company was not a taxable entity until April 25, 2012.
Schedule of difference between the Company's estimated income tax from amount derived by applying statutory federal rate to pretax income	'
	The Company's estimated income tax expense differs from the amount derived by applying the statutory federal rate to pretax income principally due the effect of the following items (in thousands):
		Year Ended December 31,
		2013			2012(1)
	Income before taxes	$	(490,514	)	$	7,789
	Statutory rate		35	%		35	%
	Income tax expense computed at statutory rate	$	(171,680	)	$	2,726
	Reconciling items:
	Non-deductible pre-IPO loss		—			4,561
	State income taxes, net of federal tax benefit		(10,886	)		1,053
	Change in valuation allowance		45,688
	Change in state rate		(10,500	)
	Other, net		849			57
	Change in tax status(2)		—			149,489
	Tax provision (benefit)	$	(146,529	)	$	157,886
	-1
	For the 2011 comparable period, the calculation is not applicable as the Company was not a taxable entity until April 25, 2012.
	-2
	The change in tax status for the year ended December 31, 2012 is split between federal of $130.2 million and state of $19.3 million.
Schedule of components of the entity's deferred taxes	'
	The components of our deferred taxes are detailed in the table below (in thousands):
		December 31,			December 31,
		2013			2012(1)(2)
	Deferred tax assets—current
	Derivative instruments and other	$	15,581		$	6,027
	Less valuation allowance		(3,744	)		—
	Total deferred tax assets, current	$	11,837		$	6,027
	Deferred tax assets—noncurrent
	US tax loss carryforwards		151,872			90,735
	State tax loss carryforwards		14,154			12,258
	Employee benefit plans		1,539			985
	Less valuation allowance		(41,944	)		—
	Total deferred tax assets, noncurrent	$	125,621		$	103,978
	Deferred tax liabilities—noncurrent
	Oil and gas properties and equipment(1)		140,912			260,715
	Total deferred tax liabilities, noncurrent	$	140,912		$	260,715
	Reflected in the accompanying balance sheet as:
	Net deferred tax asset, current	$	11,837		$	6,027
	Net deferred tax liability noncurrent	$	15,291		$	156,737
	-1
	For December 31, 2012, oil and gas properties and equipment includes a deferred tax liability of $26.7 million which was recognized as a result of the Eagle Property Acquisition. The difference originated in the tax bases and the recognized value for GAAP purposes of the assets acquired and liabilities assumed in the Eagle Property Acquisition.
	-2
	In the third quarter of 2013, the Company determined that its 2012 accounting for the tax impacts of the merger of certain entities that occurred in connection with the Company's initial public offering was in error. The Company identified that certain tax attributes acquired from the merged entities were not properly identified. Because the tax attributes were acquired as a result of a merger of entities under common control, the impacts of these tax attributes should have been recorded through equity at the time the Company became a taxable entity.

Earnings_Loss_Per_Share_Tables

Earnings (Loss) Per Share (Tables)	12 Months Ended
	Dec. 31, 2013
Earnings (Loss) Per Share	'
Schedule of reconciliation of net losses to preferred shareholders, common shareholders, and participating securities for purposes of computing net loss per share	'
	The following table (in thousands, except per share amounts) provides a reconciliation of net losses to preferred shareholders, common shareholders, and participating securities for purposes of computing net loss per share for the year ended December 31, 2013:
		Total			Series A		Common			Non-vested
					Preferred		Stock			Restricted
					Stock					Stock(2)
	Net loss	$	(343,985	)	$	—	$	(343,985	)	$	—
	Preferred Dividend(1)	$	(15,589	)		—		(15,589	)		—
	Calculated allocation of net loss attributable to shareholders	$	(359,574	)	$	—	$	(359,574	)	$	—
	Weighted average shares outstanding							65,766
	Net loss per share						$	(5.47	)
	-1
	Calculation of the preferred stock dividend is discussed in Note 10.
	-2
	As these shares are participating securities that participate in earnings, but are not required to participate in losses, this calculation demonstrates that there is not an allocation of the loss to the non-vested restricted stockholders.
	The following table (in thousands, except per share amounts) provides a reconciliation of net losses to preferred shareholders, common shareholders, and non-vested restricted shareholders for purposes of computing net loss per share for the year ended December 31, 2012:
		Total			Series A		Common			Non-vested
					Preferred		Stock			Restricted
					Stock					Stock(2)
	Net loss	$	(150,097	)	$	—	$	(150,097	)	$	—
	Preferred Dividend(1)	$	(6,500	)		—		(6,500	)		—
	Calculated allocation of net loss attributable to shareholders	$	(156,597	)	$	—	$	(156,597	)	$	—
	Weighted average shares outstanding							59,979
	Net loss per share						$	(2.61	)
	-1
	Calculation of the preferred stock dividend is discussed in Note 10.
	-2
	As these shares are participating securities that participate in earnings, but are not required to participate in losses, this calculation demonstrates that there is not an allocation of the loss to the non-vested restricted stockholders.

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies	'
Schedule of contractual obligations for drilling contracts, long-term operating leases and seismic contracts	'
	At December 31, 2013, contractual obligations for drilling contracts, long-term operating leases, seismic contracts and other contracts are as follows (in thousands):
		Total		2014		2015		2016		2017		2018 and
												beyond
	Drilling contracts	$	8,192	$	8,192	$	—	$	—	$	—	$	—
	Non-cancellable office lease commitments	$	11,052		1,732		1,857		1,877		1,941		3,645
	Seismic contracts	$	4,410		4,410		—		—		—		—
	Net minimum commitments	$	23,654	$	14,334	$	1,857	$	1,877	$	1,941	$	3,645

Organization_and_Business_Deta

Organization and Business (Details) (USD $)	12 Months Ended		0 Months Ended
	Dec. 31, 2012	Dec. 31, 2013	Apr. 25, 2012
			Initial public offering
Stock issuances and other information	'	'	'
Initial public offering, aggregate number of shares of common stock sold	'	'	27,600,000
Common stock, par value (in dollars per share)	$0.01	$0.01	$0.01
Number of shares of stock sold by the selling shareholders	'	'	6,000,000
Number of shares of sold by the selling shareholders pursuant to an option granted to the underwriters to cover over-allotments	'	'	3,600,000
Public offering price (in dollars per share)	'	'	$13
Proceeds from initial public offering	'	'	$358,800,000
Underwriting discounts and commissions	6,400,000	'	21,500,000
Net proceeds to selling stockholders	'	'	117,300,000
Net proceeds from registration and sale	'	'	220,000,000
Number of shares of common stock sold	'	'	18,000,000
Proceeds from registration and sale, net of estimated offering expenses	213,569,000	'	213,600,000
Amount of net proceeds from initial public offering used to redeem convertible preferred units, including interest and other charges	'	'	67,100,000
Amount of borrowings repaid under the facility	'	'	99,000,000
Amount of net proceeds from common stock offering used to fund the execution of company's growth strategy through its drilling program	'	'	$47,500,000
Number of shares sold by the selling stockholders	'	'	9,600,000

Organization_and_Business_Deta1

Organization and Business (Details 2) (First Reserve or its affiliates)	Apr. 25, 2012
First Reserve or its affiliates	'
Minority ownership interest	'
Ownership interest percentage	41.40%

Organization_and_Business_Deta2

Organization and Business (Details 3) (USD $)	12 Months Ended			0 Months Ended		0 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Oct. 02, 2012	31-May-13	Oct. 02, 2012	Oct. 02, 2012	Oct. 02, 2012	31-May-13
	item	10.75% senior unsecured notes	9.25% senior unsecured notes	Eagle Property Acquisition	Eagle Property Acquisition	Eagle Property Acquisition	Anadarko Basin Acquisition
					10.75% senior unsecured notes	Series A Preferred Stock	9.25% senior unsecured notes
							Panther Energy Company, LLC and its partners
Acquisition information	'	'	'	'	'	'	'
Purchase price, cash	'	'	'	$325	'	'	$618
Purchase price, preferred shares	'	'	'	'	'	325,000	'
Liquidation value (in dollars per share)	'	'	'	'	'	$1,000	'
Aggregate principal amount borrowed	'	$600	$700	'	$600	'	$700
Interest rate (as a percent)	'	10.75%	9.25%	'	10.75%	'	9.25%
Segment information	'	'	'	'	'	'	'
Number of reportable segments	1	'	'	'	'	'	'

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Accounts Receivable and Allowance for Doubtful Accounts	'	'	'
Allowance for doubtful accounts	$0	$0	'
Other Noncurrent Assets	'	'	'
Deferred financing costs	44.7	25.2	'
Field inventory	9.7	'	'
Other noncurrent assets	0.2	0.2	'
Oil and Gas Reserves	'	'	'
Provision for price and cost escalations	0	'	'
Cash interest paid	104.3	7.2	4.2
Accrued Liabilities	'	'	'
Accrued oil and gas capital expenditures	87.2	69	'
Accrued revenue and royalty distributions	64.4	'	'
Accrued interest	21.3	16.2	'
Accrued lease operating and workover expenses	8.3	'	'
Accrued taxes	4.4	'	'
Other accrued liabilities	18.8	13.4	'
Income Taxes	'	'	'
Provision for federal or state income tax prior to company reorganization	0	'	'
Oil and Gas Properties	'	'	'
Property and equipment	'	'	'
Ceiling limit of capitalized cost for determining impairment to oil and gas properties, after tax	319.6	'	'
Gulf Coast unevaluated property costs transferred to the full cost pool	61.2	'	'
Mississippian unevaluated property costs attributable to leases	$168.40	'	'
Other Property and Equipment | Minimum	'	'	'
Property and equipment	'	'	'
Estimated useful lives	'3 years	'	'
Other Property and Equipment | Maximum	'	'	'
Property and equipment	'	'	'
Estimated useful lives	'7 years	'	'

Summary_of_Significant_Account4

Summary of Significant Accounting Policies (Details 2) (Senior Notes, due 2021, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
Senior Notes, due 2021	'
Long-Term Debt	'
Increase in deferred financing costs	$19.30

Summary_of_Significant_Account5

Summary of Significant Accounting Policies (Details 3) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
In Thousands, unless otherwise specified
Balance Sheet	'	'	'	'
Deferred income taxes	$15,291	$156,737	'	'
Total long-term liabilities	1,748,354	871,114	'	'
Additional paid-in-capital	871,047	863,891	'	'
Total stockholders' equity	339,999	677,469	285,502	255,879
As Previously Reported	'	'	'	'
Balance Sheet	'	'	'	'
Deferred income taxes	'	190,625	'	'
Total long-term liabilities	'	905,002	'	'
Additional paid-in-capital	'	830,003	'	'
Total stockholders' equity	'	$643,581	'	'

Fair_Value_Measurements_of_Fin2

Fair Value Measurements of Financial Instruments (Details) (Recurring, Commodity Derivatives, USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified	item	item
Significant Other Observable Inputs (Level 2)	'	'
Fair Value Measurements of Financial Instruments	'	'
Number of bank counterparties for company's commodity derivative contracts	7	5
Assets:	'	'
Total assets	$2,578	$23,601
Liabilities:	'	'
Total liabilities	33,390	27,714
Significant Other Observable Inputs (Level 2) | Swaps | Oil	'	'
Assets:	'	'
Total assets	'	16,133
Liabilities:	'	'
Total liabilities	32,209	15,091
Significant Other Observable Inputs (Level 2) | Swaps | NGL	'	'
Assets:	'	'
Total assets	469	2,353
Liabilities:	'	'
Total liabilities	74	458
Significant Other Observable Inputs (Level 2) | Swaps | Gas	'	'
Assets:	'	'
Total assets	488	'
Liabilities:	'	'
Total liabilities	809	'
Significant Other Observable Inputs (Level 2) | Collars | Oil	'	'
Assets:	'	'
Total assets	64	428
Liabilities:	'	'
Total liabilities	272	287
Significant Other Observable Inputs (Level 2) | Collars | Gas	'	'
Assets:	'	'
Total assets	751	2,026
Liabilities:	'	'
Total liabilities	26	185
Significant Other Observable Inputs (Level 2) | Basis Differential Swaps	'	'
Assets:	'	'
Total assets	806	2,661
Liabilities:	'	'
Total liabilities	'	11,693
Total	'	'
Assets:	'	'
Total assets	2,578	23,601
Liabilities:	'	'
Total liabilities	33,390	27,714
Total | Swaps | Oil	'	'
Assets:	'	'
Total assets	'	16,133
Liabilities:	'	'
Total liabilities	32,209	15,091
Total | Swaps | NGL	'	'
Assets:	'	'
Total assets	469	2,353
Liabilities:	'	'
Total liabilities	74	458
Total | Swaps | Gas	'	'
Assets:	'	'
Total assets	488	'
Liabilities:	'	'
Total liabilities	809	'
Total | Collars | Oil	'	'
Assets:	'	'
Total assets	64	428
Liabilities:	'	'
Total liabilities	272	287
Total | Collars | Gas	'	'
Assets:	'	'
Total assets	751	2,026
Liabilities:	'	'
Total liabilities	26	185
Total | Basis Differential Swaps	'	'
Assets:	'	'
Total assets	806	2,661
Liabilities:	'	'
Total liabilities	'	$11,693

Risk_Management_and_Derivative2

Risk Management and Derivative Instruments (Details) (Not designated as Hedging Instrument, Commodity Derivatives, USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013
	bbl
Risk Management and Derivative Instruments	'
Maximum loss exposure under commodity derivative contracts on failure of the entity's counterparty's performance	$0.70
Oil | WTI | Swaps | 2014	'
Risk Management and Derivative Instruments	'
Hedged Volume	4,344,450
Weighted-Average Fixed Price	88.76
Oil | WTI | Swaps | 2015	'
Risk Management and Derivative Instruments	'
Hedged Volume	1,820,000
Weighted-Average Fixed Price	86.55
Oil | WTI | Collars | 2014	'
Risk Management and Derivative Instruments	'
Hedged Volume	164,400
Oil | WTI | Collars | 2014 | Minimum	'
Risk Management and Derivative Instruments	'
Weighted-Average Fixed Price	88.49
Oil | WTI | Collars | 2014 | Maximum	'
Risk Management and Derivative Instruments	'
Weighted-Average Fixed Price	97.94
Oil | WTI to LLS | Basis Differential Swaps | 2014	'
Risk Management and Derivative Instruments	'
Hedged Volume	501,000
Weighted-Average Fixed Price	5.35
Natural Gas | Swaps | 2014	'
Risk Management and Derivative Instruments	'
Hedged Volume	17,885,000
Weighted-Average Fixed Price	4.17
Hedged Volume, not settled in cash	1,519,000
Natural Gas | Swaps | 2015	'
Risk Management and Derivative Instruments	'
Hedged Volume	18,250,000
Weighted-Average Fixed Price	4.13
Natural Gas | Collars | 2014	'
Risk Management and Derivative Instruments	'
Hedged Volume	1,685,004
Hedged Volume, not settled in cash	64,667
Natural Gas | Collars | 2014 | Minimum	'
Risk Management and Derivative Instruments	'
Weighted-Average Fixed Price	3.99
Natural Gas | Collars | 2014 | Maximum	'
Risk Management and Derivative Instruments	'
Weighted-Average Fixed Price	5.09
NGL | Swaps | 2014	'
Risk Management and Derivative Instruments	'
Hedged Volume	151,500
Weighted-Average Fixed Price	62.16

Risk_Management_and_Derivative3

Risk Management and Derivative Instruments (Details 2) (Commodity Derivatives, USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
		bbl
Option | Put | Oil	'	'
Derivative liabilities:	'	'
Payment of deferred premium	$0	$3,300,000
Number of barrels covered under the commodity contract	'	549,000
Not designated as Hedging Instrument	'	'
Risk Management and Derivative Instruments	'	'
Total derivative fair value	-30,812,000	-4,113,000
Derivative assets:	'	'
Gross Recognized Assets	2,578,000	23,601,000
Gross Amounts Offset, Assets	1,859,000	16,189,000
Net Recognized Fair Value Assets	719,000	7,412,000
Derivative liabilities:	'	'
Gross Recognized Liabilities	33,390,000	27,714,000
Gross Amounts Offset, Liabilities	1,859,000	16,189,000
Net Recognized Fair Value Liabilities	31,531,000	11,525,000
Not designated as Hedging Instrument | Current Assets	'	'
Derivative assets:	'	'
Gross Recognized Assets	2,559,000	21,603,000
Gross Amounts Offset, Assets	1,859,000	15,908,000
Net Recognized Fair Value Assets	700,000	5,695,000
Not designated as Hedging Instrument | Non-Current Assets	'	'
Derivative assets:	'	'
Gross Recognized Assets	19,000	1,998,000
Gross Amounts Offset, Assets	'	281,000
Net Recognized Fair Value Assets	19,000	1,717,000
Not designated as Hedging Instrument | Current Liabilities	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	29,739,000	23,490,000
Gross Amounts Offset, Liabilities	1,859,000	15,908,000
Net Recognized Fair Value Liabilities	27,880,000	7,582,000
Not designated as Hedging Instrument | Non-Current Liabilities	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	3,651,000	4,224,000
Gross Amounts Offset, Liabilities	'	281,000
Net Recognized Fair Value Liabilities	3,651,000	3,943,000
Not designated as Hedging Instrument | Swaps | Current Assets | Oil	'	'
Derivative assets:	'	'
Gross Recognized Assets	'	16,004,000
Not designated as Hedging Instrument | Swaps | Current Assets | NGL	'	'
Derivative assets:	'	'
Gross Recognized Assets	469,000	1,624,000
Not designated as Hedging Instrument | Swaps | Current Assets | Gas	'	'
Derivative assets:	'	'
Gross Recognized Assets	469,000	'
Not designated as Hedging Instrument | Swaps | Non-Current Assets | Oil	'	'
Derivative assets:	'	'
Gross Recognized Assets	'	129,000
Not designated as Hedging Instrument | Swaps | Non-Current Assets | NGL	'	'
Derivative assets:	'	'
Gross Recognized Assets	'	729,000
Not designated as Hedging Instrument | Swaps | Non-Current Assets | Gas	'	'
Derivative assets:	'	'
Gross Recognized Assets	19,000	'
Not designated as Hedging Instrument | Swaps | Current Liabilities | Oil	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	-28,871,000	-11,485,000
Not designated as Hedging Instrument | Swaps | Current Liabilities | NGL	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	-74,000	-336,000
Not designated as Hedging Instrument | Swaps | Current Liabilities | Gas	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	-496,000	'
Not designated as Hedging Instrument | Swaps | Non-Current Liabilities | Oil	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	-3,338,000	-3,606,000
Not designated as Hedging Instrument | Swaps | Non-Current Liabilities | NGL	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	'	-122,000
Not designated as Hedging Instrument | Swaps | Non-Current Liabilities | Gas	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	-313,000	'
Not designated as Hedging Instrument | Collars | Current Assets | Oil	'	'
Derivative assets:	'	'
Gross Recognized Assets	64,000	221,000
Not designated as Hedging Instrument | Collars | Current Assets | Gas	'	'
Derivative assets:	'	'
Gross Recognized Assets	751,000	1,129,000
Not designated as Hedging Instrument | Collars | Non-Current Assets | Oil	'	'
Derivative assets:	'	'
Gross Recognized Assets	'	207,000
Not designated as Hedging Instrument | Collars | Non-Current Assets | Gas	'	'
Derivative assets:	'	'
Gross Recognized Assets	'	897,000
Not designated as Hedging Instrument | Collars | Current Liabilities | Oil	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	-272,000	-238,000
Not designated as Hedging Instrument | Collars | Current Liabilities | Gas	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	-26,000	-112,000
Not designated as Hedging Instrument | Collars | Non-Current Liabilities | Oil	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	'	-49,000
Not designated as Hedging Instrument | Collars | Non-Current Liabilities | Gas	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	'	-73,000
Not designated as Hedging Instrument | Basis Differential Swaps | Current Assets	'	'
Derivative assets:	'	'
Gross Recognized Assets	806,000	2,625,000
Not designated as Hedging Instrument | Basis Differential Swaps | Non-Current Assets	'	'
Derivative assets:	'	'
Gross Recognized Assets	'	36,000
Not designated as Hedging Instrument | Basis Differential Swaps | Current Liabilities	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	'	-11,319,000
Not designated as Hedging Instrument | Basis Differential Swaps | Non-Current Liabilities	'	'
Derivative liabilities:	'	'
Gross Recognized Liabilities	'	($374,000)

Risk_Management_and_Derivative4

Risk Management and Derivative Instruments (Details 3) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Gains/Losses on Commodity Derivative Contracts	'	'	'
Realized net losses	$17,585	$15,825	$16,733
Unrealized net (losses) gains	-26,699	4,667	11,889
Not designated as Hedging Instrument	'	'	'
Gains/Losses on Commodity Derivative Contracts	'	'	'
Realized net losses	-17,585	-15,825	-16,733
Unrealized net (losses) gains	($26,699)	$4,667	$11,889

Property_and_Equipment_Details

Property and Equipment (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Property and Equipment	'	'	'
Proved properties	$2,817,062,000	$1,522,723,000	'
Unevaluated properties	243,599,000	313,941,000	'
Other property and equipment	11,113,000	5,038,000	'
Less accumulated depreciation, depletion, amortization and impairment	-976,880,000	-274,294,000	'
Net property and equipment	2,094,894,000	1,567,408,000	'
Other information	'	'	'
Share-based compensation expense capitalized	1,400,000	200,000	'
Other Property and Equipment	'	'	'
Other information	'	'	'
Depreciation expense	2,200,000	500,000	300,000
Oil and Gas Properties	'	'	'
Other information	'	'	'
Depletion expense related to oil and gas properties	248,200,000	125,100,000	91,400,000
Depletion expense (per Boe)	28.42	34.17	33.4
Costs capitalized to unevaluated properties	32,200,000	11,200,000	2,600,000
Internal cost capitalized	8,400,000	1,500,000	'
Share-based compensation expense capitalized	$1,400,000	$200,000	'

Acquisition_of_Oil_and_Gas_Pro2

Acquisition of Oil and Gas Properties (Details) (USD $)

12 Months Ended

3 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Oct. 02, 2012

31-May-13

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

31-May-13

31-May-13

31-May-13

Oct. 02, 2012

Dec. 31, 2012

Dec. 31, 2013

Oct. 02, 2012

Oct. 02, 2012

Apr. 01, 2013

Unaudited pro forma

Unaudited pro forma

Unaudited pro forma

10.75% senior unsecured notes

9.25% senior unsecured notes

Series A Preferred Stock

Series A Preferred Stock

Anadarko Basin Acquisition

Anadarko Basin Acquisition

Anadarko Basin Acquisition

Anadarko Basin Acquisition

Eagle Property Acquisition

Eagle Property Acquisition

Eagle Property Acquisition

Eagle Property Acquisition

Eagle Property Acquisition

Other Property Acquisitions

Maximum

9.25% senior unsecured notes

10.75% senior unsecured notes

Series A Preferred Stock

Gulf Coast

Panther Energy Company, LLC and its partners

Acquisition of Oil and Gas Properties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase price, cash

'

'

'

'

'

'

'

'

'

'

'

'

'

$618,000,000

$325,000,000

'

'

'

'

'

Preferred shares issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

325,000

'

Liquidation value (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$1,000

'

Oil and gas properties:

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proved

2,817,062,000

1,522,723,000

'

'

'

'

'

'

'

'

'

418,287,000

'

'

419,549,000

'

'

'

'

'

Unevaluated

'

'

'

'

'

'

'

'

'

'

'

207,789,000

'

'

244,236,000

'

'

'

'

'

Commodity derivative contracts

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,453,000

'

'

'

'

'

Total assets acquired

'

'

'

'

'

'

'

'

'

'

'

626,076,000

'

'

672,238,000

'

'

'

'

'

Asset retirement obligations

'

'

'

'

'

'

'

'

'

'

6,296,000

6,296,000

'

'

2,662,000

2,662,000

'

'

'

'

Deferred income tax liabilities

'

26,700,000

'

'

'

'

'

'

'

'

'

'

'

'

25,985,000

26,712,000

-727,000

'

'

'

Total liabilities assumed

'

'

'

'

'

'

'

'

'

'

'

6,296,000

'

'

28,647,000

'

'

'

'

'

Net assets acquired

'

'

'

'

'

'

'

'

'

'

'

619,780,000

'

'

643,591,000

'

'

'

'

'

Additional disclosures

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate principal amount borrowed

'

'

'

'

'

'

600,000,000

700,000,000

'

'

'

'

'

700,000,000

'

'

'

600,000,000

'

'

Interest rate (as a percent)

'

'

'

'

'

'

10.75%

9.25%

'

'

'

'

'

9.25%

'

'

'

10.75%

'

'

Term for finalization of post-closing purchase price adjustments

'

'

'

'

'

'

'

'

'

'

'

'

'1 year

'

'

'

'

'

'

'

Cost of acquiring additional acreage and producing wells

620,112,000

351,276,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,400,000

Revenue included in the statement of consolidated operations

'

'

'

'

'

'

'

'

'

'

104,700,000

'

'

'

'

28,400,000

'

'

'

'

Unaudited Pro forma information

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Revenues and other

'

'

'

539,562,000

490,241,000

287,119,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net income (loss)

'

'

'

-340,400,000

-129,885,000

21,066,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock dividends

'

'

'

-15,589,000

-26,000,000

-26,000,000

'

'

-6,300,000

-15,600,000

'

'

'

'

'

'

'

'

'

'

NET LOSS ATTRIBUTABLE TO COMMON SHAREHOLDERS

-359,574,000

-156,597,000

16,657,000

-355,989,000

-155,885,000

-4,934,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net loss per common share - basic (in dollars per share)

'

'

'

($5.41)

($2.60)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Net loss per common share - diluted (in dollars per share)

'

'

'

($5.41)

($2.60)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition and Transaction Expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition and transaction costs

$11,803,000

$14,884,000

'

'

'

'

'

'

'

'

$11,800,000

'

'

'

'

$14,900,000

'

'

'

'

Asset_Retirement_Obligations_D

Asset Retirement Obligations (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Changes in Company's asset retirement obligations	'	'	'
Asset retirement obligations at the beginning of the period	$15,245	$7,627	$2,859
Liabilities incurred	2,535	3,044	1,294
Liabilities assumed in Anadarko Basin and Eagle Property Acquisition for year ended 2013 and 2012 respectively	6,296	2,662	'
Revisions	858	1,189	3,196
Liabilities settled	-61	'	-56
Current period accretion expense	1,435	723	334
Asset retirement obligations at the end of the period	$26,308	$15,245	$7,627

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

31-May-13

Dec. 31, 2013

Sep. 26, 2013

Sep. 25, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2012

Oct. 02, 2012

Oct. 02, 2012

Oct. 02, 2012

Oct. 02, 2012

31-May-13

Dec. 31, 2013

31-May-13

31-May-13

31-May-13

31-May-13

Midstates Sub

Credit Facility Amendment - September 26, 2013

Credit Facility Amendment - September 26, 2013

Credit Facility Amendment - September 26, 2013

Credit Facility Amendment - September 26, 2013

Credit Facility Amendment - September 26, 2013

Credit Facility Amendment - September 26, 2013

Credit Facility Amendment - September 26, 2013

Senior Revolving Credit Facility, due 2018

Senior Revolving Credit Facility, due 2018

Senior Revolving Credit Facility, due 2018

Senior Revolving Credit Facility, due 2018

Senior Revolving Credit Facility, due 2018

Senior Revolving Credit Facility, due 2018

Senior Revolving Credit Facility, due 2018

Senior Notes, due 2020

Senior Notes, due 2020

Senior Notes, due 2020

Senior Notes, due 2020

Senior Notes, due 2020

Senior Notes, due 2020

Senior Notes, due 2021

Senior Notes, due 2021

Senior Notes, due 2021

Senior Notes, due 2021

Senior Notes, due 2021

Senior Notes, due 2021

item

Fiscal quarter ending December 31, 2013

Fiscal quarter ending March 31, 2014

Fiscal quarter ending June 30, 2014

Fiscal quarter ending September 30, 2014

Fiscal quarter ending December 31, 2014

Fiscal quarter ending March 31, 2015 and each fiscal quarter thereafter

item

Minimum

Maximum

Period One

Period Two

Maximum

Period One

Period Two

Maximum

Maximum

item

Period One

Period One

Period Two

Long-Term Debt

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt

'

'

'

'

'

'

'

'

'

'

'

$401,150,000

'

'

$94,000,000

'

'

$600,000,000

$600,000,000

'

'

'

'

'

$700,000,000

'

'

'

'

Total long-term debt

1,701,150,000

694,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Maximum borrowing capacity

'

'

'

'

'

'

'

'

'

'

'

750,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base

'

'

'

'

'

'

'

'

'

'

'

'

500,000,000

425,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate, description

'

'

'

'

'

'

'

'

'

'

'

'LIBOR

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate added to base rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1.75%

2.75%

'

'

'

'

'

'

'

'

'

'

'

'

Weighted-average interest rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

2.50%

'

'

2.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitment fee, option one (as a percent)

'

'

'

'

'

'

'

'

'

'

'

0.38%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitment fee, option two (as a percent)

'

'

'

'

'

'

'

'

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Additional borrowing base redeterminations at company request per 6 month period following each scheduled borrowing base redetermination

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

Period during which Company may request additional redetermination of borrowing base

'

'

'

'

'

'

'

'

'

'

'

'6 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of outstanding loans and other obligations held by lenders, on whose behalf the administrative agent may request for redetermination of borrowing base

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

67.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Outstanding letters of credit amount

'

'

'

'

'

'

'

'

'

'

'

200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of equal successive monthly payments to make repayment on reduction of borrowing base

'

'

'

'

'

'

'

'

'

'

'

6

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Period for commencement of repayment of equal successive monthly payments following the administrative agent's notice regarding borrowing base reduction

'

'

'

'

'

'

'

'

'

'

'

'30 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt to EBITDA ratio

'

'

'

'

4.75

4.75

4.5

4.25

4.25

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

One-time fee agreed to be paid to each lender on the excess portion of their commitment to the borrowing base (as a percent)

'

'

'

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

One-time fee agreed to be paid to each lender on the lesser of such lenders commitment (as a percent)

'

'

'

0.10%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Current ratio

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

Actual current ratio

'

'

'

'

'

'

'

'

'

'

'

1.3

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Actual Debt to EBITDA

'

'

'

'

'

'

'

'

'

'

'

4.4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Interest rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

10.75%

'

'

'

9.25%

'

'

'

'

'

Proceeds from the offering (net of the initial purchasers' discount and related offering expenses)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

700,000,000

'

'

'

'

'

Repayment of outstanding facility balance

'

'

'

'

'

'

'

'

'

'

34,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Ownership interest (as a percent)

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Percentage of debt that can be redeemed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35.00%

'

'

'

'

'

35.00%

Debt instrument redemption period end date

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

30-Sep-15

30-Sep-16

'

'

'

31-May-14

31-May-16

'

'

Redemption price, expressed as percentage of principal amount

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

101.00%

'

'

110.75%

'

'

'

'

103.00%

109.25%

'

'

Redemption price, percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

100.00%

'

'

Estimated fair value of the Notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

648,000,000

'

'

'

'

'

'

724,500,000

'

'

'

'

Effective annual interest rate (as a percent)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11.10%

11.10%

'

'

'

'

'

9.50%

'

'

'

'

Aggregate principal amount borrowed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

600,000,000

'

'

'

700,000,000

'

'

'

'

'

Number of trailing fiscal quarters used in calculating the company's ratio of total net indebtedness to EBITDA

'

'

'

4

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate principal amount that can be redeemed

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$100,000,000

'

Mandatorily_Redeemable_Convert1

Mandatorily Redeemable Convertible Preferred Units (Details) (USD $)	12 Months Ended			0 Months Ended	2 Months Ended	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Apr. 03, 2012	Feb. 29, 2012	Dec. 31, 2013	Dec. 31, 2012	Apr. 26, 2012	Feb. 09, 2012	Jan. 04, 2012	Dec. 31, 2011
				Mandatorily redeemable convertible preferred units	Mandatorily redeemable convertible preferred units	Mandatorily redeemable convertible preferred units	Mandatorily redeemable convertible preferred units	Mandatorily redeemable convertible preferred units	Mandatorily redeemable convertible preferred units	Mandatorily redeemable convertible preferred units	Mandatorily redeemable convertible preferred units
Mandatorily Redeemable Convertible Preferred Units	'	'	'	'	'	'	'	'	'	'	'
Number of shares authorized	'	'	'	'	'	'	'	'	'	'	65,000
Value of shares authorized to be issued	'	'	'	'	'	'	'	'	'	'	$65,000,000
Liquidation value (in dollars per share)	'	'	'	'	'	$1,000	'	'	'	'	'
Interest rate base (as a percent)	'	'	'	'	'	8.00%	'	'	'	'	'
Description of variable rate added to interest rate base	'	'	'	'	'	'LIBOR	'	'	'	'	'
Fixed interest rate added to interest rate base (as a percent)	'	'	'	'	'	1.50%	'	'	'	'	'
Conversion period, minimum	'	'	'	'	'	'1 year	'	'	'	'	'
Fixed interest charge on aggregate capital invested in preferred units, payable upon redemption or conversion (as a percent)	'	'	'	'	'	1.50%	'	'	'	'	'
Preferred units issued	'	'	'	25,000	40,000	'	'	'	20,000	20,000	'
Proceeds from issuance of preferred units	'	65,000,000	'	25,000,000	40,000,000	'	'	'	'	'	'
Redemption amount	'	'	'	'	'	'	'	67,100,000	'	'	'
Interest expense	$83,138,000	$12,999,000	$2,094,000	'	'	$0	$2,100,000	'	'	'	'

Equity_and_ShareBased_Compensa2

Equity and Share-Based Compensation (Details) (USD $)

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Dec. 31, 2013

Sep. 30, 2013

Mar. 30, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Sep. 28, 2012

Dec. 31, 2013

Dec. 31, 2013

Apr. 24, 2012

Apr. 25, 2012

Dec. 31, 2013

Dec. 31, 2012

Sep. 30, 2013

Mar. 30, 2013

Sep. 30, 2013

Mar. 30, 2013

Apr. 25, 2012

Dec. 31, 2013

Apr. 24, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Mar. 31, 2011

Apr. 25, 2012

Dec. 31, 2011

Apr. 30, 2012

Dec. 31, 2013

Nov. 22, 2011

Restricted stock awards

Restricted stock awards

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Eagle Property Acquisition

Eagle Property Acquisition

Eagle Property Acquisition

Eagle Property Acquisition

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Preferred Stock

Treasury Stock

Holdings LLC

Holdings LLC

Holdings LLC

Petroleum Inc.

Petroleum Inc.

Petroleum Inc.

Petroleum Inc.

Petroleum Inc.

Petroleum Inc.

Petroleum Inc.

Petroleum Inc.

$13.50

$11.00

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

item

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Series A Preferred Stock

Common units

Common Stock

Restricted stock awards

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Common Stock

Maximum

Minimum

Maximum

Maximum

Minimum

Minimum

Common units

Common units

Common units

Restricted stock awards

Restricted stock awards

Restricted stock awards

Chief executive officer of MPCI

Chief executive officer of MPCI

Chief executive officer of MPCI

Transactions with Chief Executive Officer of Petroleum Inc.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Units issued and outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

256,742

'

'

0

'

'

'

'

0

'

Shares issued for each unit upon conversion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

185.5

'

'

'

'

'

'

'

18,762

'

'

Shares issued upon conversion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

47,634,353

'

'

47,634,353

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Numbers of shares sold

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

27,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

17.3

'

'

'

'

'

Shares granted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

24.6

'

'

'

'

'

Share price (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$4.26

'

'

'

'

Common stock, par value (in dollars per share)

$0.01

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares of stock sold by the selling shareholders

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of shares of sold by the selling shareholders pursuant to an option granted to the underwriters to cover over-allotments

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock, shares authorized

300,000,000

300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

300,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of votes per share entitled to holders

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock, shares authorized

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock, par value (in dollars per share)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0.01

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock, shares designated

'

'

'

'

'

'

'

'

'

'

'

325,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of preferences or rights of conversion or rights of conversion, exchange, pre-exemption or other subscription rights for common stock

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Preferred stock dividends

'

'

'

'

$6,300,000

$15,600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Number of Common Shares Issuable Upon Conversion

'

'

'

'

639,127

2,459,127

'

'

26,077,807

32,004,582

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Notional dividend amount of convertible preferred stock

'

'

'

'

7,000,000

27,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Changes in number of outstanding shares

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share count at the beginning of the period (in shares)

'

'

'

'

'

325,000

'

'

'

'

'

'

'

'

'

'

66,619,711

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

Issuance of common stock in pre IPO reorganization (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

47,634,353

'

'

47,634,353

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Proceeds from the sale of common stock to public (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

18,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Grants of restricted stock (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

2,840,241

1,029,509

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Forfeitures of restricted stock (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-534,207

-44,151

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisition of treasury stock (in shares)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-118,702

'

'

'

'

'

'

'

'

'

'

'

Share count at the end of the period (in shares)

'

'

'

'

325,000

325,000

'

'

'

'

'

'

'

'

'

'

68,925,745

66,619,711

'

'

'

'

'

118,702

'

'

'

'

'

'

'

0

'

'

'

Common stock, shares issued

68,925,745

66,619,711

'

'

'

'

'

'

'

'

'

'

'

'

'

'

68,925,745

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Common stock, shares outstanding

68,807,043

66,619,711

'

'

'

'

'

'

'

'

'

'

'

'

'

'

68,807,043

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Series A Preferred Stock issued

'

'

'

'

325,000

325,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Series A Preferred Stock outstanding

'

'

'

'

325,000

325,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Liquidation value (in dollars per share)

'

'

'

'

'

'

$1,082

$1,040

'

'

'

$1,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Rate of interest for preferred stock (as a percent)

'

'

'

'

'

'

'

'

'

'

8.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Conversion rate for preferred stock (in dollars per share)

'

'

'

'

$11

$11

'

'

$13.50

$11

$13.50

'

$13.50

$11

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Dividends payable

'

'

'

'

'

'

13,500,000

13,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Additional shares of common stock to be issued upon conversion

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,229,091

1,181,818

1,001,481

962,963

'

'

'

'

'

'

'

'

'

'

'

'

'

Period required to convert preferred stock into common stock

'

'

'

'

'

'

'

'

'

'

'15 days

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Other shares or units were issued

'

'

'

'

325,000

325,000

'

'

'

'

'

'

'

'

'

'

68,925,745

66,619,711

'

'

'

'

'

118,702

'

'

'

'

'

'

'

0

'

'

'

Grant date fair value (in dollars per share)

'

'

$6.82

$12.63

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$80,013

'

'

'

'

'

Grant date fair value (in dollars)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,400,000

'

'

'

'

'

Cost of shares awarded to recipient

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

Unrecognized compensation cost

'

'

$16,300,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$0

Units outstanding

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

'

'

'

'

'

'

'

'

Equity_and_ShareBased_Compensa3

Equity and Share-Based Compensation (Details 2) (Incentive units, USD $)	12 Months Ended
	Dec. 31, 2013
Incentive units	'
Restricted Stock Awards	'
Incentive units issued	1,513
Stock-based compensation expense (in dollars)	$0

Equity_and_ShareBased_Compensa4

Equity and Share-Based Compensation (Details 3) (USD $)	12 Months Ended
In Millions, except Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Restricted stock awards	'	'
Restricted Stock Awards	'	'
Requisite service period for recognition of compensation expense	'3 years	'
Shares	'	'
Non-vested shares outstanding at the beginning of the period	985,358	'
Granted (in shares)	2,840,241	1,029,509
Vested (in shares)	-327,720	'
Forfeited (in shares)	-534,207	-44,151
Non-vested shares outstanding at the end of the period	2,963,672	985,358
Weighted Average Grant Date Fair Value	'	'
Non-vested shares outstanding at the beginning of the period (in dollars per share)	$12.61	'
Granted (in dollars per share)	$6.82	$12.63
Vested (in dollars per share)	$12.62	'
Forfeited (in dollars per share)	$8.65	$12.99
Non-vested shares outstanding at the end of the period (in dollars per share)	$7.78	$12.61
Additional information	'	'
Unrecognized expense (in dollars)	$16.30	'
Weighted-average period for over which unrecognized expense will be recognized	'2 years 29 days	'
LTIP	'	'
Additional information	'	'
Shares available for issuance	3,272,043	'
LTIP | Restricted stock awards	'	'
Restricted Stock Awards	'	'
Number of shares registered for future issuance	6,563,435	'
Number of restricted common stock issued to directors, management and employees under the long term incentive plan (in shares)	2,963,672	'
Vesting period	'3 years	'
Percentage of awards vesting on each anniversary of the grant	33.00%	'
LTIP | Restricted stock awards | Directors	'	'
Restricted Stock Awards	'	'
Vesting period	'1 year	'

Equity_and_ShareBased_Compensa5

Equity and Share-Based Compensation (Details 4) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Share-based Compensation, Post-Initial Public Offering	'	'	'
Total share-based compensation expense	$5,713,000	$2,459,000	$53,744,000
Capitalized qualifying share-based compensation costs to oil and gas properties	1,400,000	200,000	'
Restricted and unrestricted Petroleum Inc. shares and Holdings LLC units	'	'	'
Share-based Compensation, Post-Initial Public Offering	'	'	'
Total share-based compensation expense	'	'	53,744,000
2012 LTIP | Restricted stock awards	'	'	'
Share-based Compensation, Post-Initial Public Offering	'	'	'
Total share-based compensation expense	$5,713,000	$2,459,000	'

Income_Taxes_Details

Income Taxes (Details) (USD $)	3 Months Ended	12 Months Ended
	Jun. 30, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Taxes	'	'	'	'
Provision for federal or state income tax prior to company reorganization	'	$0	'	'
Net deferred income tax expense	149,500,000	-146,529,000	157,886,000	'
Valuation allowance	'	0	'	'
Income tax payments expected in the upcoming four quarterly reporting periods	'	0	'	'
Income Taxes	'	'	'	'
Tax refund	'	0	'	'
Deferred	'	'	'	'
United States	'	-130,906,000	137,496,000	'
State	'	-15,623,000	20,390,000	'
Total deferred	149,500,000	-146,529,000	157,886,000	'
Total income tax provision (benefit)	'	-146,529,000	157,886,000	'
Reconciliation of income tax expense	'	'	'	'
Income before taxes	'	-490,514,000	7,789,000	16,657,000
Statutory rate (as a percent)	'	35.00%	35.00%	'
Income tax expense computed at statutory rate	'	-171,680,000	2,726,000	'
Reconciling items:	'	'	'	'
Non-deductible pre-IPO loss	'	'	4,561,000	'
State income taxes, net of federal tax benefit	'	-10,886,000	1,053,000	'
Change in valuation allowance	'	45,688,000	'	'
Change in state rate	'	-10,500,000	'	'
Other, net	'	849,000	57,000	'
Change in tax status	'	'	149,489,000	'
Total income tax provision (benefit)	'	-146,529,000	157,886,000	'
Federal change in tax status	'	'	130,200,000	'
State change in tax status	'	'	19,300,000	'
Deferred tax assets - current	'	'	'	'
Derivative instruments and other	'	15,581,000	6,027,000	'
Less valuation allowance	'	-3,744,000	'	'
Total deferred tax assets, current	'	11,837,000	6,027,000	'
Deferred tax assets - noncurrent	'	'	'	'
US tax loss carryforwards	'	151,872,000	90,735,000	'
State tax loss carryforwards	'	14,154,000	12,258,000	'
Employee benefit plans	'	1,539,000	985,000	'
Less valuation allowance	'	-41,944,000	'	'
Total deferred tax assets, noncurrent	'	125,621,000	103,978,000	'
Deferred tax liabilities - noncurrent	'	'	'	'
Oil and gas properties and equipment	'	140,912,000	260,715,000	'
Total deferred tax liabilities, noncurrent	'	140,912,000	260,715,000	'
Reflected in the accompanying balance sheet as:	'	'	'	'
Net deferred tax assets, current	'	11,837,000	6,027,000	'
Net deferred tax liability noncurrent	'	15,291,000	156,737,000	'
Deferred tax liability recognized as a result of the Eagle Property Acquisition	'	'	26,700,000	'
Federal | Louisiana	'	'	'	'
Income Taxes	'	'	'	'
Valuation allowance against net operating loss carryforwards	'	45,700,000	'	'
State | Louisiana	'	'	'	'
Income Taxes	'	'	'	'
Valuation allowance against net operating loss carryforwards	'	$45,700,000	'	'

Earnings_Loss_Per_Share_Detail

Earnings (Loss) Per Share (Details) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings (Loss) Per Share	'	'	'
Net loss	($343,985)	($150,097)	$16,657
Preferred Dividend	-15,589	-6,500	'
Calculated allocation of net loss attributable to shareholders	-359,574	-156,597	16,657
Weighted average shares outstanding (in shares)	65,766	59,979	'
Net loss per share (in dollars per share)	($5.47)	($2.61)	'
Common Stock	'	'	'
Earnings (Loss) Per Share	'	'	'
Net loss	-343,985	-150,097	'
Preferred Dividend	-15,589	-6,500	'
Calculated allocation of net loss attributable to shareholders	($359,574)	($156,597)	'
Weighted average shares outstanding (in shares)	65,766	59,979	'
Net loss per share (in dollars per share)	($5.47)	($2.61)	'

Concentrations_of_Credit_Risk_

Concentrations of Credit Risk (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	item	item	item
Concentrations of Credit Risk	'	'	'
Short-term contracts usual term	'1 month	'	'
Revenue | Customer concentration	'	'	'
Concentrations of Credit Risk	'	'	'
Number of purchasers	5	3	2
Revenue | Customer concentration | Purchaser one	'	'	'
Concentrations of Credit Risk	'	'	'
Concentration risk (as a percent)	28.00%	41.00%	39.00%
Revenue | Customer concentration | Purchaser two	'	'	'
Concentrations of Credit Risk	'	'	'
Concentration risk (as a percent)	16.00%	32.00%	38.00%
Revenue | Customer concentration | Purchaser three	'	'	'
Concentrations of Credit Risk	'	'	'
Concentration risk (as a percent)	13.00%	10.00%	'
Revenue | Customer concentration | Purchaser four	'	'	'
Concentrations of Credit Risk	'	'	'
Concentration risk (as a percent)	12.00%	'	'
Revenue | Customer concentration | Purchaser five	'	'	'
Concentrations of Credit Risk	'	'	'
Concentration risk (as a percent)	11.00%	'	'
Accounts receivable | Customer concentration	'	'	'
Concentrations of Credit Risk	'	'	'
Number of purchasers	3	4	'
Accounts receivable | Customer concentration | Purchaser one	'	'	'
Concentrations of Credit Risk	'	'	'
Concentration risk (as a percent)	31.00%	38.00%	'
Accounts receivable | Customer concentration | Purchaser two	'	'	'
Concentrations of Credit Risk	'	'	'
Concentration risk (as a percent)	16.00%	18.00%	'
Accounts receivable | Customer concentration | Purchaser three	'	'	'
Concentrations of Credit Risk	'	'	'
Concentration risk (as a percent)	13.00%	14.00%	'
Accounts receivable | Customer concentration | Purchaser four	'	'	'
Concentrations of Credit Risk	'	'	'
Concentration risk (as a percent)	'	10.00%	'

Commitments_and_Contingencies_1

Commitments and Contingencies (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net minimum commitments	'	'	'
Total	$23,654,000	'	'
2014	14,334,000	'	'
2015	1,857,000	'	'
2016	1,877,000	'	'
2017	1,941,000	'	'
2018 and beyond	3,645,000	'	'
Office rent	1,700,000	1,100,000	600,000
Drilling contracts	'	'	'
Net minimum commitments	'	'	'
Total	8,192,000	'	'
2014	8,192,000	'	'
Non-cancellable office lease commitments	'	'	'
Net minimum commitments	'	'	'
Total	11,052,000	'	'
2014	1,732,000	'	'
2015	1,857,000	'	'
2016	1,877,000	'	'
2017	1,941,000	'	'
2018 and beyond	3,645,000	'	'
Seismic contracts	'	'	'
Net minimum commitments	'	'	'
Total	4,410,000	'	'
2014	$4,410,000	'	'
Gas transportation gathering and processing contract | Minimum	'	'	'
Net minimum commitments	'	'	'
Fee used as multiple for payment to the counterparty equal to the shortfall amount (in dollars per gallon/MMBTU)	0.06	'	'
Gas transportation gathering and processing contract | Maximum	'	'	'
Net minimum commitments	'	'	'
Fee used as multiple for payment to the counterparty equal to the shortfall amount (in dollars per gallon/MMBTU)	0.125	'	'
Gas transportation gathering and processing contract | Natural Gas	'	'	'
Net minimum commitments	'	'	'
Period after which company would receive volumetric credit for any deficiency payment under contract	'30 months	'	'
Gas transportation gathering and processing contract | Natural Gas | Delivery during first 30 months of the contract	'	'	'
Net minimum commitments	'	'	'
Fee used as multiple for payment to the counterparty equal to the shortfall amount (in dollars per gallon/MMBTU)	0.36	'	'
Contractual obligation	38,100,000	'	'
Gas transportation gathering and processing contract | Natural Gas | Delivery during first 60 months of the contract	'	'	'
Net minimum commitments	'	'	'
Fee used as multiple for payment to the counterparty equal to the shortfall amount (in dollars per gallon/MMBTU)	0.36	'	'
Contractual obligation	76,200,000	'	'
Gas transportation gathering and processing contract | NGL | Minimum	'	'	'
Net minimum commitments	'	'	'
Volume commitments per day over the remaining term of the contract	2,800	'	'
Gas transportation gathering and processing contract | NGL | Maximum	'	'	'
Net minimum commitments	'	'	'
Volume commitments per day over the remaining term of the contract	5,460	'	'

Subsequent_Events_Details

Subsequent Events (Details) (USD $)	12 Months Ended			1 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Sep. 26, 2013	Sep. 25, 2013	Mar. 31, 2014	Mar. 31, 2014	Mar. 05, 2014
	Secured revolving credit facility	Secured revolving credit facility	Secured revolving credit facility	Subsequent event	Subsequent event	Subsequent event
				Bridge Facility	Secured revolving credit facility	Pine Prairie field area of Evangeline Parish, Louisiana
					RBL Backstop
					item
Subsequent Event	'	'	'	'	'	'
Purchase price of subject to standard post-closing adjustments received in cash	'	'	'	'	'	$170
Maximum borrowing capacity	750	'	'	125	750	'
Borrowing base	'	500	425	'	475	'
Advances available in tranches	'	'	'	50	'	'
Interest rate, description	'LIBOR	'	'	'LIBOR	'	'
Interest rate added to base rate (as a percent)	'	'	'	4.50%	'	'
Step in interest rate (as a percent)	'	'	'	0.50%	'	'
Minimum liquidity amount to avoid securities demand by lenders	'	'	'	50	'	'
Commitment fee (as a percent)	'	'	'	1.75%	'	'
Funding fee (as a percent)	'	'	'	1.25%	'	'
Fee upon rollover into senior secured notes (as a percent)	'	'	'	2.25%	'	'
Borrowing base before amendment	'	'	'	'	500	'
Increase in leverage ratio for minimum net proceeds upon the sale of Pine Prairie	'	'	'	'	0.5	'
Number of quarters upon the sale of Pine Prairie to increase leverage ratio	'	'	'	'	2	'
Minimum net proceeds upon the sale of Pine Prairie to increase leverage covenant	'	'	'	'	$100	'
Increase in interest rate of debt on nonfulfillment of condition (as a percent)	'	'	'	'	0.25%	'
Amended underwriting fee (as a percent)	'	'	'	'	0.25%	'
Additional underwriting fee (as a percent)	'	'	'	'	1.00%	'