Epl Oil & Gas 10-K 28 Feb 14 2013 FY Annual report Financial data

Document_And_Entity_Informatio

Document And Entity Information (USD $)	12 Months Ended
	Dec. 31, 2013	Jun. 30, 2013	Feb. 21, 2013
Document And Entity Information [Abstract]	'	'	'
Entity Registrant Name	'EPL OIL & GAS, INC.	'	'
Entity Central Index Key	'0000750199	'	'
Document Type	'10-K	'	'
Document Period End Date	31-Dec-13	'	'
Amendment Flag	'false	'	'
Document Fiscal Year Focus	'2013	'	'
Document Fiscal Period Focus	'FY	'	'
Current Fiscal Year End Date	'--12-31	'	'
Entity Filer Category	'Large Accelerated Filer	'	'
Entity Common Stock, Shares Outstanding	'	'	39,206,958
Entity Public Float	'	$1,066,066,044	'
Entity Well-known Seasoned Issuer	'Yes	'	'
Entity Voluntary Filers	'No	'	'
Entity Current Reporting Status	'Yes	'	'
Trading Symbol	'EPL	'	'

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current assets:	'	'
Cash and cash equivalents	$8,812	$1,521
Trade accounts receivable - net	70,707	67,991
Fair value of commodity derivative instruments	501	3,302
Deferred tax asset	8,949	3,322
Prepaid expenses	6,868	9,873
Total current assets	95,837	86,009
Property and equipment, at cost under the successful efforts method of accounting	2,355,219	2,025,647
Less accumulated depreciation, depletion, amortization and impairments	-618,788	-427,580
Net property and equipment	1,736,431	1,598,067
Deposit for Nexen Acquisition	7,040	'
Restricted cash	6,023	6,023
Fair value of commodity derivative instruments	238	211
Deferred financing costs -- net of accumulated amortization of $5,549 and $2,596 at December 31, 2013 and 2012, respectively	10,106	12,386
Other assets	2,156	2,931
Total Assets	1,857,831	1,705,627
Current liabilities:	'	'
Accounts payable	59,431	34,772
Accrued expenses	131,125	117,372
Asset retirement obligations	51,601	30,179
Fair value of commodity derivative instruments	29,636	10,026
Total current liabilities	271,793	192,349
Long-term debt	627,355	689,911
Asset retirement obligations	203,849	204,931
Deferred tax liabilities	122,812	67,694
Fair value of commodity derivative instruments	2,136	3,637
Other	673	1,132
Total Liabilities	1,228,618	1,159,654
Commitments and contingencies (Note 13)	'	'
Stockholders' equity:	'	'
Preferred stock, $0.001 par value. Authorized 1,000,000 shares; no shares issued and outstanding at December 31, 2012 and 2011, respectively	'	'
Common stock, par value $0.001 per share. Authorized 75,000,000 shares; shares issued: 40,970,137 and 40,601,887 at December 31, 2013 and 2012, respectively; shares outstanding: 39,097,394 and 39,103,203 December 31, 2012 and 2011, respectively	41	40
Additional paid-in capital	519,114	510,469
Treasury stock, at cost, 1,498,684 and 922,345 shares at December 31, 2012 and 2011, respectively	-31,157	-20,477
Retained earnings	141,215	55,941
Total stockholders' equity	629,213	545,973
Total liabilities and stockholders' equity	$1,857,831	$1,705,627

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, except Share data, unless otherwise specified
Condensed Consolidated Balance Sheets [Abstract]	'	'
Accumulated amortization, deferred financing costs	$5,549	$2,596
Preferred stock, par value	$0.00	$0.00
Preferred stock, shares authorized	1,000,000	1,000,000
Preferred stock, shares issued	0	0
Common stock, par value	$0.00	$0.00
Common stock, shares authorized	75,000,000	75,000,000
Common stock, shares issued	40,970,137	40,601,887
Common stock, shares outstanding	39,097,394	39,103,203
Treasury stock, shares	1,872,743	1,498,684

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Revenue:	'	'	'	'	'	'	'	'	'	'	'
Oil and natural gas	'	'	'	'	'	'	'	'	$688,743	$422,529	$348,207
Other	'	'	'	'	'	'	'	'	4,295	1,104	120
Total Revenues	142,610	183,992	184,087	182,349	138,899	86,668	99,270	98,796	693,038	423,633	348,327
Costs and expenses:	'	'	'	'	'	'	'	'	'	'	'
Lease operating	'	'	'	'	'	'	'	'	165,841	94,850	70,281
Transportation	'	'	'	'	'	'	'	'	3,568	615	779
Exploration expenditures and dry hole costs	'	'	'	'	'	'	'	'	26,555	18,799	14,268
Impairments	'	'	'	'	'	'	'	'	2,937	8,883	32,466
Depreciation, depletion and amortization	'	'	'	'	'	'	'	'	200,359	113,581	104,624
Accretion of liability for asset retirement obligations	'	'	'	'	'	'	'	'	28,299	15,565	15,942
General and administrative	'	'	'	'	'	'	'	'	28,137	23,208	18,741
Taxes, other than on earnings	'	'	'	'	'	'	'	'	11,490	13,007	14,365
Gain on sale of assets	'	'	'	'	'	'	'	'	-28,681	'	'
Other	'	'	'	'	'	'	'	'	34,942	4,678	9,735
Total costs and expenses	122,077	143,178	98,535	109,657	86,235	67,379	68,071	71,501	473,447	293,186	281,201
Income from operations	20,533	40,814	85,552	72,692	52,664	19,289	31,199	27,295	219,591	130,447	67,126
Other income (expense):	'	'	'	'	'	'	'	'	'	'	'
Interest income	'	'	'	'	'	'	'	'	99	136	102
Interest expense	'	'	'	'	'	'	'	'	-52,368	-28,568	-17,548
Loss on derivative instruments	'	'	'	'	'	'	'	'	-32,361	-13,305	-5,870
Loss on early extinguishment of debt	'	'	'	'	'	'	'	'	'	'	-2,377
Total other income (expense)	'	'	'	'	'	'	'	'	-84,630	-41,737	-25,693
Income before income taxes	'	'	'	'	'	'	'	'	134,961	88,710	41,433
Deferred income tax expense	'	'	'	'	'	'	'	'	-49,687	-29,900	-14,822
Net income	($12,058)	($1,284)	$69,579	$29,037	$24,153	($2,247)	$35,401	$1,503	$85,274	$58,810	$26,611
Basic earnings per share	($0.31)	($0.03)	$1.77	$0.74	$0.62	($0.06)	$0.90	$0.04	$2.18	$1.50	$0.66
Diluted earnings per share	($0.31)	($0.03)	$1.75	$0.73	$0.61	($0.06)	$0.90	$0.04	$2.15	$1.50	$0.66
Weighted average common shares used in computing earnings per share:	'	'	'	'	'	'	'	'	'	'	'
Basic	'	'	'	'	'	'	'	'	38,730	38,885	39,946
Diluted	'	'	'	'	'	'	'	'	39,236	39,034	40,050

Consolidated_Statement_of_Chan

Consolidated Statement of Changes in Stockholders' Equity (USD $)	Treasury Stock [Member]	Common Stock [Member]	Additional Paid-in Capital [Member]	Retained Earnings [Member]	Total
In Thousands, except Share data
Balance at Dec. 31, 2010	'	$40	$502,556	($29,480)	$473,116
Balance, shares at Dec. 31, 2010	'	40,092,000	'	'	'
Net income	'	'	'	26,611	26,611
Stock option and restricted share awards	'	'	2,509	'	2,509
Stock option and restricted share awards, shares	'	217,000	'	'	'
Exercise of stock options	'	'	119	'	119
Exercise of stock options, shares	'	13,000	'	'	'
Purchase of shares into treasury, shares	916,000	'	'	'	'
Purchase of shares into treasury	-11,353	'	'	'	-11,353
Restricted Stock used for tax withholding	-8	'	'	'	-8
Restricted Stock used for tax withholding, shares	6,000	'	'	'	'
Other	'	'	51	'	51
Shares, Other	'	4,000	'	'	'
Balance at Dec. 31, 2011	-11,361	40	505,235	-2,869	491,045
Balance, shares at Dec. 31, 2011	922,000	40,326,000	'	'	'
Net income	'	'	'	58,810	58,810
Stock option and restricted share awards	'	'	4,717	'	4,717
Stock option and restricted share awards, shares	'	226,000	'	'	'
Exercise of stock options	'	'	441	'	441
Exercise of stock options, shares	'	48,000	'	'	'
Purchase of shares into treasury, shares	549,000	'	'	'	'
Purchase of shares into treasury	-8,798	'	'	'	-8,798
Restricted Stock used for tax withholding	-318	'	'	'	-318
Restricted Stock used for tax withholding, shares	28,000	'	'	'	'
Other	'	'	76	'	76
Shares, Other	'	2,000	'	'	'
Balance at Dec. 31, 2012	-20,477	40	510,469	55,941	545,973
Balance, shares at Dec. 31, 2012	1,499,000	40,602,000	'	'	'
Net income	'	'	'	85,274	85,274
Stock option and restricted share awards	'	'	7,344	'	7,344
Stock option and restricted share awards, shares	2,000	258,000	'	'	'
Exercise of stock options	'	1	1,384	'	1,385
Exercise of stock options, shares	'	108,000	'	'	'
Purchase of shares into treasury, shares	334,000	'	'	'	'
Purchase of shares into treasury	-9,640	'	'	'	-9,640
Restricted Stock used for tax withholding	-1,040	'	'	'	-1,040
Restricted Stock used for tax withholding, shares	38,000	'	'	'	'
Other	'	'	-83	'	-83
Shares, Other	'	2,000	'	'	'
Balance at Dec. 31, 2013	($31,157)	$41	$519,114	$141,215	$629,213
Balance, shares at Dec. 31, 2013	1,873,000	40,970,000	'	'	'

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Cash flows from operating activities:	'	'	'
Net income	$85,274	$58,810	$26,611
Adjustments to reconcile net income to net cash provided by operating activities:	'	'	'
Depreciation, depletion and amortization	200,359	113,581	104,624
Accretion of liability for asset retirement obligations	28,299	15,565	15,942
Change in fair value of derivative instruments	20,884	9,491	-11,475
Non-cash compensation	7,344	4,717	2,509
Deferred income taxes	49,687	29,900	14,822
Exploration expenditures	5,520	4,227	11,239
Impairments	2,937	8,883	32,466
Amortization of deferred financing costs and discount on debt	5,396	2,556	1,657
Gain on sale of assets	-28,681	'	'
Loss on early extinguisment of debt	'	'	2,377
Other	27,235	2,448	6,984
Changes in operating assets and liabilities:	'	'	'
Trade accounts receivable	-1,916	-33,547	-10,037
Other receivables	'	'	2,088
Prepaid expenses	2,081	1,047	-7,623
Other assets	790	145	-1,215
Accounts payable and accrued expenses	35,658	31,477	12,650
Asset retirement obligation settlements	-53,308	-35,429	-32,364
Other liabilities	'	'	-3
Net cash provided by operating activities	387,559	213,871	171,252
Cash flows used in investing activities:	'	'	'
Decrease in restricted cash	'	'	2,466
Property acquisitions	-27,560	-578,372	-235,486
Deposit for Nexen Acquisition	-7,040	'	'
Exploration and development expenditures	-322,040	-184,850	-76,003
Other property and equipment additions	-2,016	-1,743	-1,568
Proceeds from sale of assets	52,317	'	'
Net cash used in investing activities	-306,339	-764,965	-310,591
Cash flows provided by (used in) financing activities:	'	'	'
Proceeds from indebtedness	'	509,313	203,794
Repayments of indebtedness	-65,000	-20,000	'
Deferred financing costs	-674	-8,469	-6,646
Purchase of shares into treasury	-9,640	-8,798	-11,353
Exercise of stock options	1,385	441	119
Net cash provided by (used in) financing activities	-73,929	472,487	185,914
Net increase (decrease) in cash and cash equivalents	7,291	-78,607	46,575
Cash and cash equivalents at beginning of period	1,521	80,128	33,553
Cash and cash equivalents at end of period	8,812	1,521	80,128
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION	'	'	'
Interest	$47,339	$21,129	$9,395

Organization_and_Summary_of_Si

Organization and Summary of Significant Accounting Policiies	12 Months Ended
	Dec. 31, 2013
Organization and Summary of Significant Accounting Policies [Abstract]	'
Organization and Summary of Significant Accounting Policies	'
	1) Organization and Summary of Significant Accounting Policies
	EPL Oil & Gas, Inc. (“we,” “our,” “us,” or “the Company”) was incorporated as a Delaware corporation on January 29, 1998. We are an independent oil and natural gas exploration and production company. Our current operations are concentrated in the U.S. Gulf of Mexico shelf focusing on state and federal waters offshore Louisiana.  Effective September 1, 2012, we changed our legal corporate name from “Energy Partners, Ltd.” to “EPL Oil & Gas, Inc.” through a short-form merger pursuant to Section 253 of the General Corporation Law of the State of Delaware.
	Recent Events.  On January 15, 2014, we acquired 100% working interest of certain shallow-water central Gulf of Mexico shelf oil and natural gas assets comprised of five leases in the Eugene Island 258/259 field for $70.4 million, subject to customary adjustments to reflect the September 1, 2013, economic effective date.  This acquisition was financed with borrowings under our Senior Credit Facility.  In January 2014, we requested and received, with the approval of our lenders, a $50.0 million increase in our borrowing base bringing our borrowing base under the Senior Credit Facility to $475.0 million.  See Note 7, “Indebtedness” for more information regarding our Senior Credit Facility.
	A summary of acquisition activity during 2013, 2012 and 2011 is as follows (purchase prices are before economic effective date adjustments):
		·	On September 26, 2013, we acquired an asset package consisting of certain Gulf of Mexico shelf oil and natural gas interests in the West Delta 29 field for $21.8 million;
		·	On October 31, 2012, we acquired from Hilcorp Energy GOM Holdings, LLC 100% of the membership interests of Hilcorp Energy GOM, LLC, which owned certain shallow water Gulf of Mexico shelf oil and natural gas interests for $550.0 million;
		·	On May 15, 2012, we acquired an asset package consisting of certain shallow-water Gulf of Mexico shelf oil and natural gas interests in our South Timbalier 41 field located in the Gulf of Mexico for $32.4 million;
		·	On November 17, 2011, we acquired interests in the Main Pass 296/311 complex along with other unit interests in the Main Pass complex and an interest in a Main Pass 295 primary term lease for $38.6 million; and
		·	On February 14, 2011, we acquired an asset package consisting of certain shallow-water Gulf of Mexico shelf oil and natural gas interests surrounding the Mississippi River delta and a related gathering system for $200.7 million.
	In addition, on April 2, 2013, we sold certain shallow water Gulf of Mexico shelf oil and natural gas interests located within the non-operated Bay Marchand field for total consideration of $62.8 million. See Note 2, “Acquisitions and Disposition” for more information regarding these transactions.
	A summary of significant accounting policies followed in the preparation of the accompanying consolidated financial statements is set forth below.
	(a) Basis of Presentation
	The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and include the accounts of EPL Oil & Gas, Inc. and our wholly-owned subsidiaries. All significant intercompany accounts and transactions are eliminated in consolidation. Our interests in oil and natural gas exploration and production ventures and partnerships are proportionately consolidated.
	(b) Property and Equipment
	We use the successful efforts method of accounting for oil and natural gas producing activities. Costs to acquire mineral interests in oil and natural gas properties, to drill and equip exploratory wells that find proved reserves, and to drill and equip development wells are capitalized. Exploratory drilling costs are initially capitalized, but charged to expense if and when the well is determined not to have found reserves in commercial quantities. We may capitalize exploratory well costs beyond one year if (a) we found a sufficient quantity of reserves to justify its completion as a producing well and (b) we are making sufficient progress assessing the reserves and the economic and operating viability of the project; otherwise, these costs are expensed. Geological and geophysical costs are charged to expense as incurred.
	Leasehold acquisition costs are capitalized as unproved properties. If proved reserves are found on undeveloped leases, the related leasehold costs are transferred to proved properties and amortized using the units of production method. For individual unevaluated properties with capitalized costs below a threshold amount, we allocate capitalized costs to earnings generally over the primary lease terms. Properties that are subject to amortization and those with capitalized costs greater than the threshold amount are assessed for impairment periodically. Capitalized costs of producing oil and natural gas properties are depreciated and depleted by the units-of-production method.
	We evaluate our capitalized costs of proved oil and natural gas properties for potential impairment when circumstances indicate that the carrying values may not be recoverable. The need to test a property for impairment can be based on several factors, including a significant reduction in sales prices for oil and/or natural gas, unfavorable adjustments to reserve volumes, actual operating and development costs in excess of expected amounts, changes in estimates of future operating and capital expenditure requirements, or other changes to contracts, environmental regulations or tax laws. The calculation is performed on a field-by-field basis, utilizing our current estimates of future revenues and operating expenses. In the event net undiscounted cash flow is less than the carrying value, an impairment loss is recorded based on the present value of expected future net cash flows over the economic lives of the reserves.
	On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depletion, depreciation and amortization are eliminated from the property accounts, along with the related asset retirement obligations, unless retained by us, and the resulting gain or loss is recognized in earnings.
	(c) Asset Retirement Obligations
	We record our obligations associated with the retirement of tangible long-lived assets at their fair values in the period incurred. The fair value of the obligation is also recorded to the related asset’s carrying amount. Accretion of the liability is recognized as an operating expense and the capitalized cost is amortized using the units-of-production method. We revise our estimates of asset retirement obligations as information about material changes to the liability becomes known. Revisions are recorded as adjustments to existing liabilities and to the carrying amount of the related assets. Revisions occurring at or near the end of an asset’s useful life may result in impairments or losses and could materially impact earnings. Our asset retirement obligations relate primarily to the plugging and abandonment of our oil and natural gas wellbores and to decommissioning related pipelines, facilities and structures.
	(d) Income Taxes
	We account for income taxes under the asset and liability method, which requires that we recognize deferred tax assets and liabilities for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis amounts. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. We recognize the effect on deferred tax assets and liabilities of a change in the tax rates in income in the period that includes the enactment date.
	We follow the provisions of Accounting Standards Codification (“ASC”) Topic 740, “Income Taxes,” which apply to the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements and prescribe a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. These provisions also contain guidance on de-recognition, classification, interest and penalties. Interest, if any, is classified as a component of interest expense, and statutory penalties, if any, are classified as a component of general and administrative expense.
	(e) Deferred Financing Costs
	We defer costs incurred to obtain debt financing and then amortize such costs as additional interest expense over the maturity period of the related debt using the effective interest rate method.
	(f) Earnings Per Share
	Basic earnings per share is computed by dividing income or loss available to common stockholders by the weighted average number of common shares outstanding during each period. According to GAAP, we have determined that our unvested restricted share awards, which contain non-forfeitable rights to dividends, are participating securities and should be included in the computation of earnings per share pursuant to the “two-class” method. The “two-class” method allocates undistributed earnings between common shares and participating securities. The diluted earnings per share calculation under the “two-class” method also includes the effect, if dilutive, of potential common shares associated with stock option awards outstanding during each period. The dilutive effect of stock options is determined using the treasury stock method.
	(g) Revenue Recognition
	We record revenues from the sales of oil and natural gas when the product is delivered at a determinable price, title has transferred and collectability is reasonably assured. When we have an interest with other producers in properties from which natural gas is produced, we use the entitlement method for recording natural gas sales revenue. Under this method of accounting, revenue is recorded based on our net revenue interest in production. Deliveries of natural gas in excess of our revenue interest are recorded as liabilities and under-deliveries are recorded as receivables. We had natural gas imbalance liabilities of $2.0 million and $1.7 million at December 31, 2013 and 2012, respectively. We had natural gas imbalance receivables of $1.9 million and $0.8 million at December 31, 2013 and 2012, respectively.
	(h) Cash and Cash Equivalents
	We include in cash and cash equivalents our highly-liquid investments with original maturities of three months or less. At December 31, 2013 and 2012, cash and cash equivalents includes investments in overnight interest-bearing deposits of $7.3 million and $2.3 million, respectively. These amounts are reduced by overdraft balances on other operating accounts with legal right of offset in the same banking institution to arrive at the cash and cash equivalent balances reported in our consolidated balance sheets.
	(i) Derivative Activities
	Derivative instruments, including certain derivative instruments embedded in other contracts, are recorded at fair value and included as either assets or liabilities in the balance sheet. The accounting for changes in fair value depends on the intended use of the derivative and the resulting designation, which is established at the inception of the derivative. We do not elect to designate derivative instruments as hedges. Gains and losses resulting from changes in the fair value of derivative instruments are recorded in other income (expense). Gains and losses related to contract settlements are also recorded in other income (expense).
	(j) Share-Based Compensation
	We recognize share-based compensation expense based on the estimated grant-date fair value of all share-based awards, net of an estimated forfeiture rate, over the requisite service period of the awards, which is generally equivalent to the vesting term. We record share-based compensation expense only for those awards expected to vest. We periodically revise our estimated forfeiture rate if actual forfeitures differ from our estimates.
	We are required to report excess tax benefits from the exercise of stock options as financing cash flows. For the year ended December 31, 2013 and 2012, no excess tax benefits were reported in the statement of cash flows as we were in a net operating loss carryforward position. See Note 12 for additional disclosures.
	(k) Allowance for Doubtful Accounts
	We routinely assess the recoverability of all material trade and other receivables to determine their collectability. Our crude oil and natural gas revenue receivables are typically collected within two months. We may have the ability to withhold future revenue disbursements to recover any non-payment of joint interest receivables on properties where we are the operator. When we believe collection of the full amount of our accounts receivable is in doubt, we record an allowance to reflect accounts receivable at the net realizable value, which may be reflected in earnings or as an increase to the net book value of our oil and natural gas properties depending on the nature of the transaction that created the receivable. The nature of the transaction resulting in the receivable balance determines whether the allowance, when recorded, impacts our earnings (ordinarily through LOE) or our property and equipment balances. As of December 31, 2013, our allowance for doubtful accounts was $0.7 million, $0.1 million of which was recorded as a recovery in earnings in 2013. As of December 31, 2012, our allowance for doubtful accounts was $0.7 million, $0.1 million of which was recorded as a recovery in earnings in 2012.
	(l) Accrued Expenses
	As of December 31, 2013, our accrued expenses included accrued exploration costs, development costs and lease operating expenses totaling approximately $107.8 million, other accrued expenses of $7.5 million and interest payable of approximately $15.8 million. As of December 31, 2012, our accrued expenses included accrued exploration costs, development costs and lease operating expenses totaling approximately $84.9 million, other accrued expenses of $16.3 million and interest payable of approximately $16.2 million.
	(m) 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 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. Certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions, or if different assumptions had been used. We evaluate our estimates and assumptions on a regular basis. We use historical experience and various other assumptions that are believed to be reasonable under the circumstances to form the basis for making judgments about carrying values of assets and liabilities that are not readily apparent from other sources. Our actual results may differ from these estimates and assumptions used in preparation of our financial statements. Significant estimates with regard to these financial statements and related unaudited disclosures include the estimate of proved oil and natural gas reserve quantities and the related present value of estimated future net cash flows therefrom disclosed in Note 15.
	(n) New Accounting Pronouncements
	Effective January 1, 2013, we adopted the amended disclosure requirements contained in ASU 2011-11, “Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities.” This guidance impacted the disclosures associated with our derivative instruments and did not impact our consolidated financial position, results of operations or cash flows.  See Note 7, “Fair Value Measurements,” of our consolidated financial statements in Part I, Item 1 of this Quarterly Report for related disclosures.
	In July 2013, the Financial Accounting Standards Board issued Accounting Standards Update (ASU) No. 2013-11, “Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists.”  The amendments in this update clarify the financial statement presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists.  The amendments are effective for fiscal years, and interim periods within those years, beginning December 15, 2013.  We do not expect this guidance to have a material impact on our consolidated financial position, results of operations or cash flows.

Acquisitions_and_Dispositions

Acquisitions and Dispositions	12 Months Ended
	Dec. 31, 2013
Acquisitions and Dispositions [Abstract]	'
Acquisitions and Dispositions [Text Block]	'
	(2) Acquisitions and Dispositions
	Sale of Non-Operated Bay Marchand Asset
	On April 2, 2013, we sold certain shallow water Gulf of Mexico shelf oil and natural gas interests located within the non-operated Bay Marchand field (the “BM Interests”) to the property operator for $51.5 million in cash and the buyer’s assumption of liabilities recorded on our balance sheet of $11.3 million resulting in total consideration of $62.8 million, subject to customary adjustments to reflect the January 1, 2013 economic effective date. Our results for the year ended December 31, 2013 reflect a pre-tax gain of $28.1 million from this sale.  The following table summarizes the carrying amount of the net assets sold and reflects management’s estimates of customary adjustments to the sale price of approximately $0.7 million to reflect the economic effective date of January 1, 2013.
	(In thousands)	1-Jan-13
	Oil and natural gas properties	$	35,298
	Asset retirement obligations		-3,959
	Other liabilities		-7,311
	Net assets sold	$	24,028
	The cash proceeds from this sale of assets were held on deposit with a qualified intermediary in contemplation of a potential tax-deferred exchange of properties and classified as restricted cash at June 30, 2013.  On September 26, 2013, we used $16.5 million of these proceeds to fund the WD29 Acquisition (defined and described below), which was a qualifying purchase for tax-deferral purposes. On September 29, 2013, the underlying escrow agreement expired, and the remaining amount of the deposit became unrestricted.
	The West Delta 29 Acquisition
	On September 26, 2013, we acquired from W&T Offshore, Inc. (“W&T”) an asset package consisting of certain Gulf of Mexico shelf oil and natural gas interests in the West Delta 29 field (the “WD29 Interests”) for $21.8 million in cash, subject to customary adjustments to reflect an economic effective date of January 1, 2013 (the “WD29 Acquisition”). We estimate that the proved reserves as of the January 1, 2013 economic effective date totaled approximately 0.7 Mmboe, of which 95% were oil and 58% were proved developed reserves. The WD29 Acquisition was funded with a portion of the proceeds from the sale of the BM Interests held by the qualified intermediary as described above.
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects management’s estimate of customary adjustments to purchase price provided for by the purchase and sale agreement of approximately $7.1 million to reflect an economic effective date of January 1, 2013.
	(In thousands)	1-Jan-13
	Oil and natural gas properties	$	16,696
	Asset retirement obligations		-1,398
	Net assets acquired	$	15,298
	The Hilcorp Acquisition
	On October 31, 2012, we acquired from Hilcorp Energy GOM Holdings, LLC (“Hilcorp”) 100% of the membership interests of Hilcorp Energy GOM, LLC (the “Hilcorp Acquisition”), which owned certain shallow water Gulf of Mexico shelf oil and natural gas interest (the “Hilcorp Properties”) for $550.0 million in cash, subject to customary adjustments to reflect an economic effective date of July 1, 2012.  As of December 31, 2012, the Hilcorp Properties had estimated proved reserves of approximately 37.2 Mmboe, of which 49% were oil and 58% were proved developed reserves. The primary factors considered by management in acquiring the Hilcorp Properties include the belief that the Hilcorp Acquisition provides an opportunity to significantly increase our reserves, production volumes and drilling portfolio, while maintaining our focus on oil-weighted assets in our core area of expertise on the Gulf of Mexico shelf.  The Hilcorp Acquisition also provides us with access to infrastructure and extensive acreage, with significant exploitation and development potential.
	The Hilcorp Acquisition was financed with cash on hand, the net proceeds from the sale of $300 million in aggregate principal amount of 8.25% senior notes due 2018 (the “2012 Senior Notes”) and borrowings under our expanded Senior Credit Facility.  After deducting the initial purchasers’ discount, we realized net proceeds of $289.5 million.  See Note 7, “Indebtedness,” for more information regarding our 2012 Senior Notes.
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects final adjustments to purchase price provided for by the purchase and sale agreement of approximately $5.7 million to reflect an economic effective date of July 1, 2012.
	(In thousands)	1-Jul-12
	Oil and natural gas properties	$	698,660
	Asset retirement obligations		-150,959
	Net assets acquired	$	547,701
	During the quarter ended December 31, 2013, we completed the allocation of the Hilcorp Acquisition purchase price resulting in an increase in the acquired asset retirement obligation of $22.1 million.  This change was due primarily to changes in the timing of expected cash flows for the related abandonment and decommissioning activities.
	The South Timbalier Acquisition
	On May 15, 2012, we acquired from W&T an asset package consisting of certain shallow-water Gulf of Mexico shelf oil and natural gas interests in our South Timbalier 41 field (the “ST41 Interests”) located in the Gulf of Mexico for $32.4 million in cash, subject to customary adjustments to reflect an economic effective date of April 1, 2012. We estimate that the proved reserves as of the April 1, 2012 economic effective date totaled approximately 1.0 Mmboe, of which 51% were oil and 84% were proved developed reserves. Prior to the ST41 Acquisition, we owned a 60% working interest in these properties, and W&T owned a 40% working interest. As a result of the ST41 Acquisition, we have become the sole working interest owner of the South Timbalier 41 field. We funded the ST41 Acquisition with cash on hand.
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects final adjustments to purchase price provided for by the purchase and sale agreement of approximately $0.4 million to reflect an economic effective date of April 1, 2012.
	(In thousands)	April 1, 2012
	Oil and natural gas properties	$	33,206
	Asset retirement obligations		-1,878
	Net assets acquired	$	31,328
	The ASOP Acquisition
	On February 14, 2011, we acquired an asset package consisting of certain shallow-water Gulf of Mexico shelf oil and natural gas interests surrounding the Mississippi River delta and a related gathering system (the “ASOP Properties”) from Anglo-Suisse Offshore Pipeline Partners, LLC (“ASOP”) for $200.7 million in cash, subject to purchase price adjustments to reflect an economic effective date of January 1, 2011. As of December 31, 2010, the ASOP Properties had estimated proved reserves of approximately 8.1 Mmboe, of which 84% were oil and 76% were proved developed reserves. The primary factors considered by management in acquiring the ASOP Properties include the belief that the ASOP Acquisition provided an opportunity to significantly increase our reserves, production volumes and drilling portfolio, while maintaining our focus on oil-weighted assets in our core area of expertise in the Gulf of Mexico shelf. We financed the ASOP Acquisition with the proceeds from the sale of $210.0 million in aggregate principal amount of the 2011 Senior Notes. After deducting the initial purchasers’ discount and offering expenses, we realized net proceeds of approximately $202.0 million. See Note 7, “Indebtedness” for more information regarding our 2011 Senior Notes.
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects final adjustments to purchase price provided for by the purchase and sale agreement of approximately $3.8 million to reflect an economic effective date of January 1, 2011.
	(In thousands)	1-Jan-11
	Oil and natural gas properties	$	221,751
	Asset retirement obligations		-24,858
	Net assets acquired	$	196,893
	The Main Pass Acquisition
	On November 17, 2011, we acquired certain interests in producing oil and natural gas assets in the shallow-water central Gulf of Mexico shelf (the “Main Pass Interests”) from Stone Energy Offshore, L.L.C. for $38.6 million in cash, subject to customary adjustments to reflect the economic effective date of November 1, 2011. The Main Pass Interests consist of additional interests in the Main Pass 296/311 complex that was included in the ASOP Acquisition, along with other unit interests in the Main Pass complex and an interest in a Main Pass 295 primary term lease. We estimate that the proved reserves as of the November 1, 2011 economic effective date totaled approximately 1.3 Mmboe, all of which were proved developed reserves and 96% of which were oil reserves. We funded the Main Pass Acquisition with cash on hand.
	The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects final adjustments to purchase price provided for by the purchase and sale agreement of approximately $0.7 million to reflect an economic effective date of November 1, 2011.
	(In thousands)	1-Nov-11
	Oil and natural gas properties	$	40,826
	Asset retirement obligations		-2,991
	Net assets acquired	$	37,835
	We have accounted for our acquisitions using the purchase method of accounting for business combinations, and therefore we have estimated the fair value of the assets acquired and the liabilities assumed as of their respective acquisition dates. In the estimation of fair value, management uses various valuation methods including (i) comparable company analysis, which estimates the value of the acquired properties based on the implied valuations of other similar operations; (ii) comparable asset transaction analysis, which estimates the value of the acquired operations based upon publicly announced transactions of assets with similar characteristics; (iii) comparable merger transaction analysis, which, much like comparable asset transaction analysis, estimates the value of operations based upon publicly announced transactions with similar characteristics, except that merger analysis analyzes public to public merger transactions rather than solely asset transactions; and (iv) discounted cash flow analysis. The fair value is based on subjective estimates and assumptions, which are inherently subject to significant uncertainties which are beyond our control. These assumptions represent Level 3 inputs, as further discussed in Note 10, “Fair Value Measurements.”
	Results of Operations and Pro Forma Information
	Revenues and lease operating expenses attributable to acquired interests and properties were as follows:
			Year Ended December 31,
			2013		2012		2011
			(In thousands)
	WD29 Interests:
	Revenues		$	3,011	$	-	$	-
	Lease operating expenses		$	44	$	-	$	-
	Hilcorp Properties:
	Revenues		$	208,241	$	37,978	$	-
	Lease operating expenses		$	74,404	$	10,982	$	-
	ST41 Interests:
	Revenues		$	11,189	$	9,262	$	-
	Lease operating expenses		$	2,468	$	1,760	$	-
	ASOP Properties and Main Pass Interests:
	Revenues		$	328,070	$	175,538	$	125,975
Lease operating expenses		$	33,978	$	26,467	$	17,161
We have determined that the presentation of net income attributable to the acquired interests and properties is impracticable due to the integration of the related operations upon acquisition. We incurred fees of approximately $0.5 million related to the Hilcorp Acquisition and approximately $0.1 million related to the ST41 Acquisition, which were included in general and administrative expenses in the accompanying consolidated statement of operations for the year ended December 31, 2012. We incurred fees of approximately $0.5 million related to the ASOP Acquisition and approximately $0.1 million related to the Main Pass Acquisition, which were included in general and administrative expenses in the accompanying consolidated statement of operations for the year ended December 31, 2011.
The following supplemental pro forma information presents consolidated results of operations as if the Hilcorp Acquisition and the ST41 Acquisition had occurred on January 1, 2012. The supplemental unaudited pro forma information was derived from a) our historical consolidated statements of operations, b) the statements of operations of Hilcorp Energy GOM, LLC, and c) the statements of revenues and direct operating expenses for the ST41 Interests, which were derived from our historical accounting records.  This information does not purport to be indicative of results of operations that would have occurred had the acquisitions occurred on January 1, 2012, nor is such information indicative of any expected future results of operations.
		Year Ended December 31,
		Pro Forma
		2012
(in thousands, except per share data)
Revenue		$	594,510
Net income		$	59,324
Basic earnings per share		$	1.51
Diluted earnings per share		$	1.51
Subsequent Events
On January 15, 2014, we acquired from Nexen Petroleum Offshore U.S.A., Inc. (“Nexen”) 100% working interest of certain shallow-water central Gulf of Mexico shelf oil and natural gas assets for $70.4 million, subject to customary adjustments to reflect the September 1, 2013, economic effective date (the “Nexen Acquisition”).  The assets we acquired comprise five leases in the Eugene Island 258/259 field (the “EI Interests”).  Estimated proved reserves as of the September 1, 2013 effective date consist of approximately 2.6 Mmboe of proved developed producing reserves, about 91% of which is oil.
The Nexen Acquisition was financed with borrowings under our Senior Credit Facility. In January 2014, our lenders approved a $50.0 million increase in our borrowing base under our Senior Credit Facility, increasing our borrowing base to $475.0 million.  See Note 7, “Indebtedness” for more information regarding our Senior Credit Facility.
The Nexen Acquisition will be accounted for using the purchase method of account for business combinations.  The following allocation of the purchase price as of January 15, 2014, is preliminary and includes significant use of estimates.  This preliminary allocation is based on information that was available to management at the time these consolidated financial statements were prepared and takes into account current market conditions and estimated market prices for oil and natural gas.  Management has not yet had the opportunity to complete its assessment of the fair value of the assets acquired and liabilities assumed.  Accordingly, the allocation will change as additional information becomes available and is assessed by management, and the impact of such changes may be material.
The following table summarizes the estimated values of assets acquired and liabilities assumed and reflects management’s estimate of customary adjustments of $3.6 million to reflect an economic effective date of September 1, 2013.
(In thousands)	1-Sep-13
Oil and natural gas properties	$	93,932
Asset retirement obligations		-27,133
Net assets acquired	$	66,799
Pro forma results of operations are not provided as the historical results of the EI Interests were not available at the time these consolidated financial statements were prepared.

Common_Stock

Common Stock	12 Months Ended
	Dec. 31, 2013
Common Stock [Abstract]	'
Common Stock	'
	(3) Common Stock
	In August 2011, the Board of Directors authorized a program for the repurchase of our outstanding common stock for up to an aggregate cash purchase price of $20.0 million and increased the program to $40.0 million in May 2012. In July 2013, the Board of Directors increased the program to $80.0 million. Through December 31, 2013, we executed trades to repurchase 1,799,000 shares at an aggregate cash purchase price of approximately $29.7 million. Such shares are held in treasury and could be used to provide available shares for possible resale in future public or private offerings and our employee benefit plans. The repurchases have been, and will be, carried out in accordance with certain volume, timing and price constraints imposed by the Securities and Exchange Commission (the “SEC”) rules applicable to such transactions. The amount, timing and price of purchases otherwise depend on market conditions and other factors, including restrictions under our Senior Credit Facility. In July 2013, our Senior Credit Facility was amended to increase the limit applicable to certain restricted payments, which includes share repurchases, permitted by the agreement.
	We have reserved up to 3,574,000 shares of common stock for the issuance of restricted shares and option shares under our 2009 Long-Term Incentive Plan, with 1,184,322 shares remaining for issuance as of December 31, 2013. In April 2013, the reserved shares were increased from 2,474,000 shares to 3,574,000. See Note 12, “Employee Benefit Plans” for information regarding the 2009 Long-Term Incentive Plan.
	Covenants in certain debt instruments to which we are a party, including our Senior Credit Facility and the indenture related to our 8.25% Senior Notes, place certain restrictions and conditions on our ability to pay dividends on our common stock.

Earnings_per_Share

Earnings per Share	12 Months Ended
	Dec. 31, 2013
Earnings per Share [Abstract]	'
Earnings per Share	'
	(4) Earnings Per Share
	The following table sets forth the calculation of basic and diluted weighted average shares outstanding and earnings per share for the indicated periods.
		Year Ended December 31,
		2013		2012		2011
		(in thousands, except per share data)
	Income (numerator):
	Net income	$	85,274	$	58,810	$	26,611
	Net income attributable to participating securities		-943		-455		-77
	Net income attributable to common shares	$	84,331	$	58,355	$	26,534
	Weighted average shares (denominator):
	Weighted average shares—basic		38,730		38,885		39,946
	Dilutive effect of stock options		506		149		104
	Weighted average shares—diluted		39,236		39,034		40,050
	Basic earnings per share	$	2.18	$	1.50	$	0.66
	Diluted earnings per share	$	2.15	$	1.50	$	0.66
	The following table indicates the number of shares underlying outstanding stock-based awards excluded from the computation of dilutive weighted average shares because their effect was antidilutive for the periods indicated.
		Year Ended December 31,
		2013		2012		2011
		(in thousands)
	Weighted average shares		273		687		442

Property_and_Equipment

Property and Equipment	12 Months Ended
	Dec. 31, 2013
Property and Equipment [Abstract]	'
Property and Equipment	'
	(5) Property and Equipment
	The following table summarizes our property and equipment.
		December 31,
			2013		2012
		(In thousands)
	Proved oil and natural gas properties	$	2,307,891	$	1,982,657
	Unproved oil and natural gas properties		39,191		36,992
	Other		8,137		5,998
	Total property and equipment	$	2,355,219	$	2,025,647
	Substantially all of our oil and natural gas properties serve as collateral under our credit facility.
	We recognized impairments of $2.9 million, $8.9 million and $32.5 million in the years ended December 31, 2013, 2012 and 2011, respectively.
	Impairments for the year ended December 31, 2013 were primarily related to reservoir performance at a gas well in one of our smaller producing fields.  This field was determined to have future net cash flows less than its carrying value resulting in the write down of this property to its estimated fair value.
	Impairments for the year ended December 31, 2012 were primarily due to the decline in our estimate of future natural gas prices affecting certain of our natural gas producing fields and to reservoir performance at two of those fields. These fields were determined to have future net cash flows less than their carrying values resulting in the write down of these properties to their estimated fair values.  We also recorded impairments for undeveloped leases that are expiring in 2013 for which we had no development plans.
	Impairments for the year ended December 31, 2011 were primarily related to our natural gas producing fields and our deepwater producing well (primarily natural gas). Impairments related to our deepwater producing well were primarily due to the decline in our estimate of future natural gas prices, reservoir performance and higher estimated operating costs. Additional impairments for the year ended December 31, 2011 were primarily related to reservoir performance at other natural gas producing fields.
	At December 31, 2013 and 2012, we did not have any exploratory projects that were suspended for a period greater than one year.

Asset_Retirement_Obligations

Asset Retirement Obligations	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligations [Abstract]	'
Asset Retirement Obligations	'
	(6) Asset Retirement Obligations
	We record the fair value of a liability for an asset retirement obligation in the period in which it is incurred, along with a corresponding increase in the carrying amount of the related long-lived asset. The following table reconciles the beginning and ending aggregate recorded amount of our asset retirement obligations.
			Year Ended December 31,
			2013		2012
			(in thousands)
	Beginning of period total	$	235,110	$	99,347
	Accretion expense		28,299		15,565
	Liabilities assumed in acquisitions		23,541		132,109
	Liabilities incurred		1,187		1,210
	Revisions		24,586		22,308
	Liabilities associated with assets sold		-3,965		-
	Liabilities settled		-53,308		-35,429
	End of period total		255,450		235,110
	Less: End of period, current portion		51,601		30,179
	End of period, noncurrent portion	$	203,849	$	204,931
	We revise our estimates of ARO as information about material changes to the liability becomes known.   During the year ended December 31, 2013, our revisions include an increase to our estimated asset retirement obligations (“ARO”) of $20.8 million related to our only remaining four non-producing wellbores in our non-operated deepwater properties.  These deepwater abandonment costs are primarily attributable to changes in regulatory interpretations and enforcement by the Bureau of Safety and Environmental Enforcement in the deepwater that increased the required scope of work. As a result, we recorded an associated $20.8 million loss on abandonment activities, which is included in Other costs and expenses in our consolidated statements of operations for the year ended December 31, 2013.

Indebtedness

Indebtedness	12 Months Ended
	Dec. 31, 2013
Indebtedness [Abstract]	'
Indebtedness	'
	(7) Indebtedness
	The following table sets forth our indebtedness.
			December 31,
			2013		2012
			(In thousands)
	8.25% senior notes issued February 14, 2011 and October 25, 2012, face amount of $510.0 million,  interest rate of 8.25% payable semi-annually, in arrears on  February 15 and August 15 of each year, maturity date February 15, 2018		$	497,355	$	494,911
	Senior Credit Facility, interest rate based on base rate or LIBOR plus a floating spread, maturity date October 31, 2016			130,000		195,000
	Total indebtedness			627,355		689,911
	Current portion of indebtedness			-		-
	Noncurrent portion of indebtedness		$	627,355	$	689,911
	8.25% Senior Notes
	The 8.25% senior notes consist of $510.0 million in aggregate principal amount of our 8.25% senior notes due 2018 (the “8.25% Senior Notes”) issued under an Indenture dated February 14, 2011 (the “2011 Indenture”). The 8.25% Senior Notes bear interest from the date of their issuance at an annual rate of 8.25% with interest due semi-annually, in arrears, on February 15th and August 15th of each year. The 8.25% Senior Notes are fully and unconditionally guaranteed, jointly and severally, on an unsecured senior basis initially by each of our existing direct and indirect domestic subsidiaries (other than immaterial subsidiaries). The 8.25% Senior Notes will mature on February 15, 2018.  The effective interest rate on the 8.25% Senior Notes is approximately 9.1%.  We issued the 8.25% Senior Notes in two different private placements, described below.
	On February 14, 2011, we issued the $210.0 million in aggregate principal amount of our 8.25% senior notes due 2018 (the “2011 Senior Notes”) under the 2011 Indenture.  We used the net proceeds from the offering of the 2011 Senior Notes of $202.0 million, after deducting the initial purchasers’ discount and offering expenses payable by us, to acquire the ASOP Properties for a purchase price of $200.7 million, before adjustments to reflect an economic effective date of January 1, 2011.
	On October 25, 2012, we issued the $300.0 million in aggregate principal amount of our 2012 Senior Notes under an Indenture dated as of October 25, 2012 (the “2012 Indenture”).  We used the net proceeds from the offering of the 2012 Senior Notes of $289.5 million, after deducting the initial purchasers’ discount, to fund a portion of the Hilcorp Acquisition.  The purchase price of the 2012 Senior Notes included $4.8 million of accrued interest for the period from August 15, 2012 to October 25, 2012, which we recorded as interest payable.
	The 2012 Senior Notes were offered in a private placement only to qualified institutional buyers under Rule 144A promulgated under the Securities Act of 1933, as amended (the “Securities Act”), or to persons outside of the United States in compliance with Regulation S promulgated under the Securities Act. The 2012 Senior Notes had terms that were substantially identical to the terms of our 2011 Senior Notes. Pursuant to a registration rights agreement executed as part of the sale of the 2012 Senior Notes, we have issued publicly registered additional notes under our 2011 Indenture in exchange for the 2012 Senior Notes. As a result of this exchange offer, 100% in aggregate principal amount of the 2012 Senior Notes was exchanged for the notes under the 2011 Indenture, effective as of June 10, 2013.  All of the 8.25% Senior Notes are now issued under the 2011 Indenture, regardless of which private placement they were issued under.
	On or after February 15, 2015, we may on any one or more occasions redeem all or a part of the 8.25% Senior Notes upon not less than 30 nor more than 60 days’ notice, at the redemption prices (expressed as percentages of principal amount) set forth below, plus accrued and unpaid interest and special interest, if any, on the notes redeemed, to the applicable date, if redeemed during the twelve-month period beginning on February 15 of the years indicated below, subject to the rights of holders of notes on the relevant record date to receive interest on the relevant interest payment date:
	Year	Percentage
	2015	104.125%
	2016	102.063%
	2017 and thereafter	100.000%
	Any such redemption and notice may, in our discretion, be subject to the satisfaction of one or more conditions, precedent, including, but not limited to, the occurrence of a change of control. Unless we default in the payment of the redemption price, interest will cease to accrue on the 8.25% Senior Notes or portions thereof called for redemption on the applicable redemption date.
	At any time prior to February 15, 2014, we may, at our option, on any one or more occasions redeem with the net cash proceeds of certain equity offerings up to 35% of the aggregate principal amount of outstanding 8.25% Senior Notes, upon not less than 30 nor more than 60 days’ notice, at a redemption price equal to 108.25% of the principal amount of the notes redeemed, plus the accrued and unpaid interest and special interest, if any, to the redemption date, provided that: (1) at least 65% of the aggregate principal amount of notes issued under the 2011 Indenture remains outstanding immediately after the occurrence of such redemption; and (2) the redemption occurs within 90 days of the date after the closing of such equity offering.  This option to redeem up to 35% of the aggregate principal amount of outstanding 8.25% Senior Notes with the net cash proceeds of certain equity offerings is considered an embedded derivative.  We estimate that the fair value of this option at December 31, 2013 is not material.  In addition, we may, at our option, on any one or more occasions redeem all or a part of the 8.25% Senior Notes prior to February 15, 2015 at a redemption price equal to 100% of the principal amount of the 8.25% Senior Notes redeemed plus a “make-whole” premium as of, and accrued and unpaid interest to the redemption date.
	If we experience a change of control (as defined in the 2011 Indenture), each holder of the 8.25% Senior Notes will have the right to require us to repurchase all or any part (equal to $2,000 or an integral multiple of $1,000 in excess thereof) of the 8.25% Senior Notes at a price in cash equal to 101% of the aggregate principal amount of the 8.25% Senior Notes repurchased, plus accrued and unpaid interest to the date of repurchase. If we engage in certain asset sales, within 360 days of such sale, we generally must use the net cash proceeds from such sales to repay outstanding senior secured debt (other than intercompany debt or any debt owed to an affiliate), to acquire all or substantially all of the assets, properties or capital stock of one or more companies in our industry, to make capital expenditures or to invest in our business. When any such net proceeds that are not so applied or invested exceed $20.0 million, we must make an offer to purchase the 8.25% Senior Notes and other pari passu debt that is subject to similar asset sale provisions in an aggregate principal amount equal to the excess net cash proceeds. The purchase price of each 8.25% Senior Note (or other pari passu debt) so purchased will be 100% of its principal amount, plus accrued and unpaid interest to the repurchase date, and will be payable in cash.
	The 2011 Indenture, among other things, limits our ability to: (i) declare or pay dividends, redeem subordinated debt or make other restricted payments; (ii) incur or guarantee additional debt or issue preferred stock; (iii) create or incur liens; (iv) incur dividend or other payment restrictions affecting restricted subsidiaries; (v) consummate a merger, consolidation or sale of all or substantially all of our assets; (vi) enter into sale-leaseback transactions, (vii) enter into transactions with affiliates; (viii) transfer or sell assets; (ix) engage in business other than our current business and reasonably related extensions thereof; or (x) issue or sell capital stock of certain subsidiaries. These covenants are subject to a number of important exceptions and qualifications set forth in the 2011 Indenture.
	Senior Credit Facility
	On February 14, 2011, we entered into our senior secured credit facility with BMO Capital Markets, as lead arranger, and Bank of Montreal, as administrative agent and a lender, and the other lender parties thereto (as amended and restated, the “Senior Credit Facility”). The original terms of our Senior Credit Facility established a revolving credit facility with a four-year term that could be used for revolving credit loans and letters of credit up to an aggregate principal amount of $250.0 million. On October 31, 2012, in connection with the Hilcorp Acquisition, through an amendment and restatement of our Senior Credit Facility, the aggregate commitment under this facility was increased to a maximum of $750.0 million and the maturity date was extended to October 31, 2016. The maximum amount of letters of credit that may be outstanding at any one time is $20.0 million. The amount available under the revolving credit facility is limited by the borrowing base. The borrowing base under our Senior Credit Facility has been determined at the discretion of the lenders, based on the collateral value of our proved reserves and is subject to potential special and regular semi-annual redeterminations. On October 31, 2012, the borrowing base under the expanded credit facility was increased from $200.0 million to $425.0 million. On November 26, 2013, we completed our semi-annual redetermination and our borrowing base remained at $425.0 million. In January 2014, our lenders approved a $50.0 million increase in our borrowing base under the $750.0 million facility, increasing our borrowing base to $475.0 million. In addition, in July 2013, our Senior Credit Facility was amended to increase the limit applicable to certain restricted payments permitted by the agreement to accommodate our expanded stock repurchase program. As of December 31, 2013 and 2012, we had outstanding under the Senior Credit Facility $130.0 million and $195.0 million, respectively.
	The interest rate spread on loans and letters of credit under our Senior Credit Facility is based on the level of utilization and range from a base rate plus a margin of 0.75% to 1.75% for base rate borrowings and LIBOR plus a margin of 1.75% to 2.75% for LIBOR borrowings.  Commitment fees ranging from 0.375% to 0.50% are payable on the unused portion of the borrowing base. Interest on our base rate borrowings is payable quarterly, in arrears, and interest on our LIBOR borrowings is payable on the last day of each relevant interest period, except that in the case of any interest period that is longer than three months, interest is payable on each successive date three months after the first day of such interest period.
	Our Senior Credit Facility contains customary covenants, default provisions and collateral requirements. As described in the agreement underlying our Senior Credit Facility, we must maintain, for each period for which a covenant certification is required, (a) a minimum current ratio (as defined in the agreement for our Senior Credit Facility) of 1.0 to 1.0 and (b) a maximum total debt to EBITDAX ratio of 3.5 to 1.0. We are also required to maintain a commodities hedging program that is in compliance with the requirements set forth in our Senior Credit Facility. Our Senior Credit Facility also places restrictions on the maximum estimated future production volumes that can be subject to commodity derivative instruments.
	Our obligations under our Senior Credit Facility, as well as any hedging contracts and treasury management agreements with the lenders or affiliates of lenders, are secured by substantially all of our assets, including a) mortgages on at least 80% of the total value of our oil and gas properties evaluated in the most recently completed reserve report, after giving effect to exploration and production activities, acquisitions and dispositions, and b) the stock of certain wholly-owned subsidiaries.

Concentrations

Concentrations	12 Months Ended
	Dec. 31, 2013
Concentrations [Abstract]	'
Concentrations	'
	(8) Concentrations
	Significant Customers
	We had oil and natural gas sales to three customers accounting for 63%, 24% and 6%, respectively, of total oil and natural gas revenues, excluding the effects of hedging activities, for the year ended December 31, 2013.  We had oil and natural gas sales to three customers accounting for 45%, 31% and 11%, respectively, of total oil and natural gas revenues, excluding the effects of hedging activities, for the year ended December 31, 2012. We had oil and natural gas sales to three customers accounting for 51%, 17% and 12%, respectively, of total oil and natural gas revenues, excluding the effects of hedging activities, for the year ended December 31, 2011.
	Geographic Concentration
	Virtually all of our current operations and proved reserves are concentrated in the Gulf of Mexico region.  Therefore, we are exposed to operational, regulatory and other risks associated with the Gulf of Mexico, including the risk of adverse weather conditions.  We maintain insurance coverage against some, but not all, of the operating risks to which our business is exposed.

Derivative_Instruments_and_Hed

Derivative Instruments and Hedging Activities	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities [Abstract]	'
Derivative Instruments and Hedging Activities	'
	(9) Derivative Instruments and Hedging Activities
	We enter into derivative instruments to reduce exposure to fluctuations in the price of oil and natural gas for a portion of our production. Our fixed-price swaps fix the sales price for a limited amount of our production and, for the contracted volumes, eliminate our ability to benefit from increases in the sales price of the production. Derivative instruments are carried at their fair value on the consolidated balance sheets as Fair value of commodity derivative instruments and all gains and losses due to changes in fair market value and contract settlements are recorded in Gain (loss) on derivative instruments in Other income (expense) in the consolidated statements of operations. See Note 10 for information regarding fair values of our derivative instruments.
	The following tables set forth our derivative instruments outstanding as of December 31, 2013.
	Oil Contracts
		Fixed-Price Swaps
		Daily Average				Average
		Volume		Volume		Swap Price
	Remaining Contract Term	(Bbls)		(Bbls)		($/Bbl)
	Jan-14		16,350		506,850		93.11
	Feb-14		16,350		457,800		93.11
	Mar-14		16,350		506,850		93.11
	Apr-14		15,350		460,500		94.27
	May-14		15,350		475,850		94.27
	Jun-14		15,350		460,500		94.27
	Jul-14		14,350		444,850		93.56
	Aug-14		8,750		271,250		94.28
	Sep-14		8,750		262,500		94.28
	Oct-14		8,750		271,250		94.28
	Nov-14		8,750		262,500		94.28
	Dec-14		11,700		362,700		91.90
	2014 Total		12,996		4,743,400		93.67
	January 2015 - December 2015		1,500		547,500		97.70
	Gas Contracts
		Fixed-Price Swaps
		Daily Average				Average
		Volume		Volume		Swap Price
	Remaining Contract Term	(Mmbtu)		(Mmbtu)		($/Mmbtu)
	January 2014 - December 2014		5,000		1,825,000		4.01
	January 2015 - December 2015		4,300		1,569,500		4.31
	The following table presents information about the components of loss on derivative instruments.
		Year Ended December 31,
		2013		2012		2011
		(in thousands)
	Change in fair market value	$	-20,884	$	-9,491	$	11,475
	Loss on settlement		-11,477		-3,814		-17,345
	Total loss on derivative instruments	$	-32,361	$	-13,305	$	-5,870

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2013
Fair Value Measurements [Abstract]	'
Fair Value Measurements	'
	(10) Fair Value Measurements
	Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. ASC Topic 820, “Fair Value Measurements and Disclosures,” establishes a fair value hierarchy with three levels based on the reliability of the inputs used to determine fair value. These levels include: Level 1, defined as inputs such as unadjusted quoted prices in active markets for identical assets and liabilities; Level 2, defined as inputs other than quoted prices in active markets that are either directly or indirectly observable; and Level 3, defined as unobservable inputs for use when little or no market data exists, therefore requiring an entity to develop its own assumptions.
	As of December 31, 2013 and 2012, we held certain financial assets and liabilities that are required to be measured at fair value on a recurring basis, primarily our commodity derivative instruments. The fair values of derivative instruments were measured using price inputs published by NYMEX and IntercontinentalExchange, Inc., or ICE. These price inputs are quoted prices for assets and liabilities similar to those held by us and meet the definition of Level 2 inputs within the fair value hierarchy. The following table sets forth our financial assets and liabilities that are accounted for at fair value on a recurring basis.
		December 31,
		2013		2012
		(in thousands)
	Assets:
	Current	$	501	$	3,302
	Noncurrent		238		211
	Total gross fair value		739		3,513
	Less: counterparty set-off		-739		-3,513
	Total net fair value		-		-
	Liabilities:
	Current	$	29,636	$	10,026
	Noncurrent		2,136		3,637
	Total gross fair value		31,772		13,663
	Less: counterparty set-off		-739		-3,513
	Total net fair value		31,033		10,150
	The carrying values reported in the consolidated balance sheet for cash and cash equivalents, accounts receivable and accounts payable approximate fair value due to the short term maturities of these instruments. The fair value for the 8.25% Senior Notes is based on quoted prices, which are Level 1 inputs within the fair value hierarchy. The carrying value of the Senior Credit Facility approximates its fair value because the interest rates are variable and reflective of market rates, which are Level 2 inputs within the fair value hierarchy.
	The following table sets forth the carrying values and estimated fair values of our long-term indebtedness.
		31-Dec-13					31-Dec-12
		(In thousands)
			Carrying Value		Estimated Fair Value		Carrying Value		Estimated Fair Value
	8.25% Senior Notes	$	497,355	$	546,338	$	494,911	$	524,600
	Senior Credit Facility		130,000		130,000		195,000		195,000
	Total	$	627,355	$	676,338	$	689,911	$	719,600
	We evaluate our capitalized costs of proved oil and natural gas properties for potential impairment when circumstances indicate that the carrying values may not be recoverable. Our assessment of possible impairment of proved oil and natural gas properties is based on our best estimate of future prices, costs and expected net future cash flows by property (generally analogous to a field or lease). An impairment loss is indicated if undiscounted net future cash flows are less than the carrying value of a property. The impairment expense is measured as the shortfall between the net book value of the property and its estimated fair value, which is measured based on the discounted net future cash flows from the property. The inputs used to estimate the fair value of our oil and natural gas properties are based on our estimates of future events, including projections of future oil and natural gas sales prices, amounts of recoverable oil and natural gas reserves, timing of future production,  future costs to develop and produce our oil and natural gas and discount factors. These inputs meet the definition of Level 3 inputs within the fair value hierarchy. Impairments for the year ended December 31, 2013 were primarily related to reservoir performance at a gas well in one of our smaller producing fields. This field was determined to have future net cash flows less than its carrying value resulting in the write down of this property to its estimated fair value. Impairments for the year ended December 31, 2012 were primarily due to the decline in our estimate of future natural gas prices, which affected three of our natural gas producing fields and reservoir performance at two of those fields. These fields were determined to have future net cash flows less than their carrying values resulting in the write downs of these properties to their estimated fair values. We also recorded impairments for undeveloped leases that are expiring in 2013 for which we had no development plans. Impairments for the year ended December 31, 2011 were primarily related to our natural gas producing fields and our deepwater producing well (primarily natural gas). Impairments related to our deepwater producing well were primarily due to the decline in our estimate of future natural gas prices, reservoir performance and higher estimated operating costs. Additional impairments for the year ended December 31, 2011 were primarily related to reservoir performance at other natural gas producing fields.
	As addressed in Note 2, “Acquisitions,” we apply fair value concepts in estimating and allocating the fair value of assets acquired and liabilities assumed in acquisitions in accordance with purchase accounting for business combinations. The inputs to the estimated fair values of assets acquired and liabilities assumed are described in Note 2.

Income_Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2013
Income Taxes [Abstract]	'
Income Taxes	'
	(11) Income Taxes
	The following table sets forth the components of our provision for income taxes.
			Year Ended December 31,
			2013				2012			2011
		(In thousands)
	Current:
	Federal		$	-			$	-		$	-
	State			-				-			-
	Total current		$	-			$	-		$	-
	Deferred:
	Federal		$	-47,723			$	-28,719		$	-14,468
	State			-1,964				-1,181			-354
	Total deferred		$	-49,687			$	-29,900		$	-14,822
	Total:
	Federal		$	-47,723			$	-28,719		$	-14,468
	State			-1,964				-1,181			-354
	Total provision for income taxes.		$	-49,687			$	-29,900		$	-14,822
	The following table reconciles the expected statutory federal income tax rate to our effective income tax rate.
			Percentage of Pretax Earnings
			Year Ended December 31,
			2013				2012				2011
	Expected statutory federal income tax rate			35.0	%			35.0	%		35.0	%
	State taxes			1.4				1.4			2.3
	State tax rate changes			-				-2.7			-1.7
	Statutory depletion			-0.3				-0.4			-1
	Other			0.7				0.4			1.2
	Effective income tax rate			36.8	%			33.7	%		35.8	%
	The following table sets forth the tax effects of temporary differences that give rise to significant portions of our deferred tax assets and liabilities.
			December 31,
			2013			2012
			(In thousands)
	Deferred tax assets:
	Federal and state net operating loss carryforwards		$	62,015		$	62,130
	Fair value of commodity derivative instruments			11,578			3,912
	Restricted stock awards and options			3,843			2,313
	Percentage depletion carryforward			5,003			4,575
	Accruals and other			1,130			2,613
	Deferred tax asset			83,569			75,543
	Deferred tax liabilities:
	Property, plant and equipment, principally due to differences in depreciation		$	193,191		$	136,016
	Fair value of commodity derivative instruments			182			214
	Prepaid assets			1,482			1,778
	Accruals and other			2,577			1,907
	Deferred tax liabilities			197,432			139,915
	Net deferred tax liability			113,863			64,372
	Reflected in accompanying balance sheets as:
	Current deferred asset			8,949			3,322
	Non-current deferred liability			122,812			67,694
	Total net deferred tax liability		$	113,863		$	64,372
	As a result of our reorganization under Chapter 11 in 2009, the income from the discharge of indebtedness, represented for tax purposes as the excess of the principal and accrued interest on the debt discharged over the fair value of the stock of the reorganized company received in exchange for the discharged obligations, as defined by Internal Revenue Code (the “IRC”) Section 108 (“IRC 108”), reduced our net operating loss carryforwards (“NOLs”) by $97 million (“Tax Attribute Reduction”). Our remaining NOLs as of December 31, 2013 were approximately $167 million.
	Ownership changes, as defined in IRC Section 382, limit the amount of NOLs that can be utilized annually to offset future taxable income and reduce our tax liability (“Section 382 Limitation”). In 2009, as part of our Chapter 11 reorganization, we had an ownership change which resulted in a Section 382 Limitation on the amount of NOLs available annually for use. Unused annual limited NOLs (those NOLs in existence immediately after the application of IRC 108) totaled $137 million. The annual limitation is approximately $21 million per year beginning in 2010 and, if unused, can be carried over and aggregated with limited NOLs in future years subject to the ultimate expiration of the NOLs. We have not used any limited NOLs since the reorganization. The amount of limited NOLs available for our 2013 federal tax return is approximately $121 million. We believe that we will be able to utilize all of our federal NOLs prior to their expiration.
	At December 31, 2013, we had approximately $167 million of federal NOLs, of which approximately $3.8 million relates to excess tax benefits with respect to share-based compensation that have not been recognized in our consolidated financial statements. Our federal NOLs are available to reduce future federal taxable income subject to the limitations and estimates described above and the application of the tax rules and regulations. The NOLs begin expiring in the years 2025 through 2033.
	As of January 1, 2013, our 2009-2012 income tax years remain subject to examination by the Internal Revenue Service. In addition, our 2009-2012 state income/franchise tax years remain subject to examination by the States of Louisiana and Texas. As of the date of these financial statements, our 2013 U.S. federal and state income tax returns have not been filed, although management expects to file such returns in a timely manner during 2014. We have no material uncertain tax positions as of December 31, 2013.

Employee_Benefit_Plan

Employee Benefit Plan	12 Months Ended
	Dec. 31, 2013
Employee Benefit Plan [Abstract]	'
Employee Benefit Plans	'
	(12) Employee Benefit Plans
	Share-Based Compensation Plans
	In September 2009 the Board of Directors adopted the 2009 Long Term Incentive Plan (the “2009 LTIP”). The purpose of the 2009 LTIP is to provide a means to enhance our profitable growth by attracting and retaining directors, officers and other key employees through affording such individuals a means to acquire and maintain stock ownership or awards the value of which is tied to the performance of our common stock. All directors, officers and other key employees providing services to the Company are potentially eligible to participate in the 2009 LTIP. The 2009 LTIP provides for grants of (i) incentive stock options qualified as such under income tax rules and regulations, (ii) stock options that do not qualify as incentive stock options, (iii) restricted stock awards, (iv) restricted stock units, (v) stock appreciation rights, (vi) bonus stock and awards in lieu of Company obligations, (vii) dividend equivalents in connection with other awards, (viii) deferred shares, (ix) performance units or shares, or (x) any combination of such awards (collectively referred to as “Awards”). The 2009 LTIP is administered by the Compensation Committee of our Board of Directors (the “Compensation Committee”).
	Without stockholder or participant approval, the Board of Directors may amend, alter, suspend, discontinue or terminate the 2009 LTIP or the Compensation Committee’s authority to grant Awards under the 2009 LTIP, except that any amendment or alteration of the 2009 LTIP, including any increase in any share limitation, shall be subject to the approval of the stockholders not later than the next annual meeting if stockholder approval is required by any state or federal law or regulation or the rules of any stock exchange or automated quotation system on which the common stock may then be listed or quoted.
	On the date of the 2013 Annual Meeting of Stockholders, the stockholders approved an increase in the maximum aggregate number of shares of our common stock that may be issued pursuant to any and all Awards under the 2009 LTIP from 2,474,000 shares to 3,574,000 shares, subject to adjustment due to recapitalization or reorganization, or related to forfeitures or the expiration of Awards, as provided under the 2009 LTIP. As of December 31, 2013, 1,184,322 shares remained available for future grants.
	The 2009 LTIP provides for the grant of stock options for which the exercise price, set at the time of the grant, will not be less than the fair market value per share at the date of grant. Our outstanding stock options generally have a term of 10 years and vest ratably on an annual basis over a three-year period from the date of grant, other than the stock option grant to our chief executive officer described in the following paragraph.
	Pursuant to an employment agreement and the 2009 LTIP, on September 30, 2009, our new chief executive officer was granted an option to purchase 68,116 shares of our common stock, which was memorialized in an option award agreement dated as of October 1, 2009 (the “Option Agreement”). The terms of the Option Agreement provided for an exercise price equal to $10.00 per share. The closing price of our common stock on the NYSE on September 30, 2009 was $7.46 per share. The option vested ratably on a monthly basis over a 36-month period from the date of grant; however, the vesting for the first six months of the vesting period (the “Initial Period”) was deferred until the end of the Initial Period and any remaining unvested portion vested ratably on a monthly basis over the remainder of the 36-month vesting period, subject to the executive remaining continuously employed. Under the original terms of the award agreement, vested stock options under the Option Agreement were to expire 30 months following the applicable vesting date of such stock options. On May 1, 2012, the Compensation Committee modified the terms of the Option Agreement to extend the expiration of the stock options granted thereunder to September 30, 2019, resulting in additional compensation expense of $0.1 million in the year ended December 31, 2012.  Upon a change in control as defined in the 2009 LTIP, all stock options under the Option Agreement remain exercisable for a period of not less than 30 months following the change in control.
	In November 2009, the Compensation Committee approved a compensation program for each of our non-employee directors which provides for the annual grant of a stock award with a market value of $100,000 (as measured on the date of grant and prorated from the date of grant, as applicable). Pursuant to the terms of the program, one-half of each stock award vests immediately on the date of grant, and the remaining one-half vests immediately prior to the next annual meeting of stockholders held after the grant date.  The grant date for these awards is typically on the date of our annual meeting of stockholders. Pursuant to this program and the 2009 LTIP, the five members of the Board of Directors were awarded, in the aggregate, a total of 15,305 shares, a total of 31,095 shares and a total of 31,405 shares during the years ended December 31, 2013, 2012, and 2011, respectively. Pursuant to elections made by two directors applicable to certain of these awards, the receipt of such awards totaling 39,009 shares is deferred until such directors cease to serve on our Board of Directors. During the year ended December 31, 2013, one of our non-employee directors resigned, forfeiting 1,531 shares awarded under this program.
	The following table sets forth our stock option activity for the year ended December 31, 2013.
		Options			Weighted-			Weighted-			Aggregate Intrinsic Value
					Average			Average
					Exercise			Remaining
					Price Per			Contractual
					Share			Terms
								(in years)			(in thousands)
	Outstanding on December 31, 2012		1,192,158		$	14.30
	Granted		369,137			27.48
	Exercised		-108,122			12.80
	Forfeited/Cancelled		-			-
	Outstanding on December 31, 2013		1,453,173		$	17.76			7.8		$	15,970
	Exercisable on December 31, 2013		705,814		$	13.45			6.9		$	10,624
	The fair value of each stock option award was estimated on the date of grant using the Black-Scholes option valuation model using the weighted average assumptions in the table below.
			Year Ended December 31,
			2013			2012			2011
	Black-Scholes option pricing model assumptions:
	Risk free interest rate		1.4	%		1.0	%		1.9	%
	Expected life (years)		6.0			6.0			6.0
	Expected volatility		56	%		56	%		53	%
	Dividend yield		-			-			-
	Expected volatility is generally based on the historical volatility of our stock over the period of time equivalent to the expected term of the options granted. As a result of our Chapter 11 reorganization in 2009 for purposes of determining expected volatility in 2013, 2012 and 2011, we included consideration of the historical volatility of the share prices of our peers over the relevant time periods in addition to our historical volatility before, during and after our reorganization. We disregarded our share price for the periods during which our stock price was impacted by factors leading up to the Chapter 11 filing and during the period of the Chapter 11 reorganization proceedings because we do not expect these events to reoccur during the expected term of the options. The expected term of options granted is generally derived from historical exercise patterns over a period of time, with consideration of the expected term of unvested options. However, because we do not have sufficient historical stock option exercise experience upon which to base an estimate of expected term, we used the simplified method for estimating expected term in 2013, 2012 and 2011. The risk-free interest rate is based on the interest rate on constant maturity bonds published by the Federal Reserve with a maturity commensurate with the expected term of the options granted.
	The weighted-average grant-date fair value of stock options granted during the years ended December 31, 2013, 2012 and 2011 was $14.50, $8.84 and $7.97, respectively. The aggregate intrinsic value (the amount by which the market price of the stock on the date of exercise exceeded the market price of the stock on the date of grant) of stock options exercised during the years ended December 31, 2013, 2012 and 2011 was $2.1 million, $0.5 million and $0.1 million, respectively.
	The following table sets forth the activity related to our non-vested share awards for the year ended December 31, 2013.
		Shares			Weighted-
					Average
					Grant-
					Date
					Fair Value
	Non-vested share awards outstanding at December 31, 2012		326,952		$	15.98
	Granted		264,383			26.60
	Vested		-145,309			16.77
	Forfeited		-1,531			32.67
	Non-vested share awards outstanding at December 31, 2013		444,495		$	21.98
	The fair value of non-vested share awards equals the market value of the underlying stock on the date of grant. The weighted-average grant-date fair value of the non-vested share awards granted during the years ended December 31, 2013, 2012 and 2011 was $26.60, $16.33 and $15.34 per share, respectively.  The total fair value of non-vested share awards that vested during the years ended December 31, 2013, 2012 and 2011 was $4.1 million, $2.0 million and $0.6 million, respectively.
	The following table sets forth share-based compensation expense and related recognized tax benefits.
			Year Ended December 31,
			2013			2012			2011
	Compensation Expense:
	Stock Options	$	3,426		$	2,621		$	1,497
	Non-vested share awards		3,918			2,096			1,012
	Deferred Income Tax Benefit		2,704			1,726			936
	As of December 31, 2013, $5.6 million of total unrecognized compensation expense related to outstanding stock options was expected to be recognized over a weighted-average period of 2.0 years. As of December 31, 2013, $6.1 million of total unrecognized compensation expense related to non-vested share awards was expected to be recognized over a weighted-average period of approximately 2.0 years.
	401(k) Plan
	We also have a 401(k) Plan that covers all employees. We match 100% of each individual participant’s contribution not to exceed 6% of the participant’s compensation. Our matching contributions are made in cash. During the years ended December 31, 2013, 2012 and 2011, we made matching contributions to the 401(k) Plan of approximately $0.9 million, $0.8 million and $0.7 million, respectively.
	Employee Retention Plans
	The Company has two plans under which, in the event of termination of employment in connection with a change of control of our company, our officers and employees are entitled to receive a multiple of their salaries and bonuses (typically up to one or two-and-one-half times such amount) and certain other benefits in a lump sum cash payment. Additionally, all options, restricted stock, restricted share units and other similar awards would become fully vested.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies [Abstract]	'
Commitments and Contingencies	'
	(13) Commitments and Contingencies
	We have operating leases for office space and equipment, which expire on various dates through 2019. Expense relating to operating obligations for the years ended December 31, 2013, 2012 and 2011 was $7.5 million, $2.4 million and $1.8 million, respectively. Future minimum commitments as of December 31, 2013 under these operating obligations are as follows (in thousands):
	2014	$	1,073
	2015		1,222
	2016		1,239
	2017		661
	2018		542
	Thereafter		406
	Future minimum commitments	$	5,143
	In connection with our exploration and development efforts, we are contractually committed to the acquisition of seismic data in the aggregate amount of $40.5 million to be incurred over the next four years.
	We maintain restricted escrow funds in a trust for future abandonment costs at our East Bay property. The trust was originally funded with $15.0 million and, with accumulated interest, increased to $16.7 million at December 31, 2008. We may draw from the trust upon completion of qualifying abandonment activities at our East Bay field. At December 31, 2013, we had $6.0 million remaining in restricted escrow funds for decommissioning work in our East Bay field, which will remain restricted until substantially all required decommissioning in the East Bay field is complete. Amounts on deposit in the trust account are reflected in Restricted cash on our consolidated balance sheets.
	We record liabilities when we deliver production that is in excess of our interest in certain properties. In addition to these imbalances, we may, from time to time, be allocated cash sales proceeds in excess of amounts that we estimate are due to us for our interest in production. These allocations may be subject to further review, may require more information to resolve or may be in dispute. In July 2010, we were notified by a purchaser of oil production from one of our non-operated fields that we were allocated, and received sales proceeds from, more oil production than we actually sold to that purchaser. The oil purchaser’s initial estimate of the oil volumes misallocated to us was approximately 74,000 barrels, which may have been valued at up to $6.9 million based on information provided by the oil purchaser. We had previously recorded an amount that we believed may have been payable related to a potential reallocation, which amount was reflected in Accrued expenses in the accompanying consolidated balance sheet as of December 31, 2012. In connection with the sale of the BM Interests in 2013, the buyer assumed any liability we may have had related to this matter.
	We and our oil and gas joint interest owners are subject to periodic audits of the joint interest accounts for leases in which we participate and/or operate. As a result of these joint interest audits, amounts payable or receivable by us for costs incurred or revenue distributed by the operator or by us on a lease may be adjusted, resulting in adjustments, increases or decreases, to our net costs or revenues and the related cash flows. Such adjustments may be material. When they occur, these adjustments are recorded in the current period, which generally is one or more years after the related cost or revenue was incurred or recognized by the joint account.
	We are a defendant in a number of lawsuits and are involved in governmental and regulatory proceedings, all of which  arose in the ordinary course of business, including, but not limited to, personal injury claims, royalty claims, contract claims, and environmental claims, including claims involving assets owned by acquired companies. While the ultimate outcome and impact on us cannot be predicted with certainty, management believes that the resolution of pending proceedings will not have a material adverse effect on our consolidated financial position, results of operations, or cash flows.

Interim_Financial_Information_

Interim Financial Information (Unaudited)	12 Months Ended
	Dec. 31, 2013
Interim Financial Information (Unaudited) [Abstract]	'
Interim Financial Information (Unaudited)	'
	(14) Interim Financial Information (Unaudited)
	The following tables summarize our consolidated unaudited interim financial information for the years ended December 31, 2013 and 2012.
			Three Months Ended
			31-Mar		30-Jun		September 30(1)		December 31(2)
			(In thousands, except per share data)
	2013
	Revenues		$	182,349	$	184,087	$	183,992	$	142,610
	Costs and expenses			109,657		98,535		143,178		122,077
	Income from operations			72,692		85,552		40,814		20,533
	Net income (loss)			29,037		69,579		-1,284		-12,058
	Earnings (loss) per share:
	Basic		$	0.74	$	1.77	$	-0.03	$	-0.31
	Diluted			0.73		1.75		-0.03		-0.31
		-1		Included in net income (loss) for the three months ended September 30, 2013 is the loss on abandonment activities totaling $22.6 million resulting from an increase in required scope of work attributable to changes in regulatory interpretations and enforcement by BSEE in the deepwater.
		-2		The decrease in revenue for the quarter ended December 31, 2013 compared to the quarter ended September 30, 2013 is primarily due to a decrease in oil production and a decrease in the average selling prices of our oil.
				Three Months Ended
			31-Mar		30-Jun		30-Sep		December 31 (1)
			(In thousands, except per share data)
	2012
	Revenues		$	98,796	$	99,270	$	86,668	$	138,899
	Costs and expenses			71,501		68,071		67,379		86,235
	Income from operations			27,295		31,199		19,289		52,664
	Net income (loss)			1,503		35,401		-2,247		24,153
	Earnings (loss) per share:
	Basic		$	0.04	$	0.90	$	-0.06	$	0.62
	Diluted			0.04		0.90		-0.06		0.61
	(1)Includes the results of operations of the Hilcorp Properties, which we acquired on October 31, 2012.

Supplementary_Oil_and_Natural_

Supplementary Oil and Natural Gas Disclosures (Unaudited)	12 Months Ended
	Dec. 31, 2013
Supplementary Oil and Natural Gas Disclosures (Unaudited) [Abstract]	'
Supplementary Oil and Natural Gas Disclosures (Unaudited)	'
	(15) Supplementary Oil and Natural Gas Disclosures—(Unaudited)
	Our estimates of proved reserves are based on a reserve report prepared as of December 31, 2013 by the independent petroleum engineering firm Netherland, Sewell & Associates, Inc. Users of this information should be aware that the process of estimating quantities of “proved” and “proved developed” natural gas and crude oil reserves is very complex, requiring significant professional judgment in the evaluation of all available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors including, but not limited to, additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Consequently, material revisions to existing reserve estimates occur from time to time. Although every reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the significance of the professional judgment required and variances in available data for various reservoirs make these estimates generally less precise than other estimates presented in connection with financial statement disclosures. Proved reserves are estimated quantities of natural gas, crude oil and condensate that geological and engineering data demonstrate, with reasonable certainty, to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed reserves are proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods.
	The following table sets forth our estimated net proved reserves, changes in our estimated net proved reserves and our net proved developed and undeveloped reserves.
			Oil		Gas		Oil Equivalent
			(Mbbls)		(Mmcf)		(Mboe)
	Estimated Proved Reserves:
	31-Dec-10			17,223		61,251		27,431
	Acquisitions (a)			7,987		8,640		9,427
	Extensions and discoveries			2,266		4,664		3,043
	Revisions			2,778		-6,678		1,666
	Production			-2,953		-9,092		-4,468
	31-Dec-11			27,301		58,785		37,099
	Acquisitions (b)			16,430		115,876		35,742
	Extensions and discoveries (c)			6,388		10,241		8,095
	Revisions			1,128		4,033		1,800
	Production			-3,805		-8,996		-5,304
	31-Dec-12			47,442		179,939		77,432
	Acquisitions			366		209		401
	Sales			-1,415		-916		-1,568
	Extensions and discoveries (d)			7,354		20,247		10,729
	Revisions			3,952		-10,128		2,264
	Production			-6,182		-15,767		-8,810
	31-Dec-13			51,517		173,584		80,448
	Proved developed reserves:
	31-Dec-11			24,791		52,739		33,581
	31-Dec-12			37,908		120,687		58,022
	31-Dec-13			39,439		107,687		57,387
	Proved undeveloped reserves:
	31-Dec-11			2,510		6,046		3,518
	31-Dec-12			9,534		59,252		19,409
	31-Dec-13			12,078		65,897		23,061
	(a)Reserves acquired in the acquisitions of the ASOP Properties and Main Pass Interests.
	(b)Reserves acquired in the acquisitions of the Hilcorp Properties and the ST41 Interests.
	(c)Includes extensions and discoveries across 6 different fields, primarily within our West Delta and Ship Shoal areas.  These extensions and discoveries added volumes ranging from 18 Mboe to 1.2 Mmboe each, with three exceeding 1.0 Mmboe each.
	(d)Includes extensions and discoveries across 12 different fields, primarily within our Ship Shoal and West Delta areas.  The Ship Shoal 208 field accounts for 46% of our total extensions and discoveries with 4,973 Mboe, consisting of 3,967 Mbbls of oil and 6,035 Mmcf of produced gas.  The remaining 11 locations account for up to 16% each of total extensions and discoveries with reserves ranging from 10 Mboe to 1.6 Mmboe.
	Capitalized costs for oil and natural gas producing activities consist of the following:
			Year Ended December 31,
			2013		2012
			(In thousands)
	Proved properties		$	2,307,891	$	1,982,657
	Unproved properties			39,191		36,992
	Accumulated depreciation, depletion and amortization			-614,068		-424,520
	Net capitalized costs		$	1,733,014	$	1,595,129
	The following table sets forth the costs incurred associated with finding, acquiring and developing our proved oil and natural gas reserves.
			Year Ended December 31,
			2013		2012		2011
			(In thousands)
	Acquisitions — Proved (1)		$	46,047	$	706,322	$	261,812
	Acquisitions — Unproved			2,200		7,496		14
	Exploration			46,100		43,338		17,129
	Development (2)			303,245		180,938		83,577
	Costs incurred		$	397,592	$	938,094	$	362,532
	(1)For the year ended December 31, 2013, includes $29.7 million associated with the Hilcorp Acquisition and $16.7 million associated with the WD29 Acquisition.  See Note 2, “Acquisitions and Dispositions” for more information.
	(2)Includes our estimates during the years ended December 31, 2013, 2012 and 2011 of incurred asset retirement obligations associated with finding and developing our proved oil and natural gas reserves of $1.2 million, $1.2 million and $0.2 million, respectively.
	Expenditures incurred for exploratory dry holes are included in investing activities in the consolidated statements of cash flows.
	Standardized Measure of Discounted Future Net Cash Flows Relating to Reserves
	The following information has been developed utilizing procedures prescribed by ASC 932. It may be useful for certain comparative purposes, but should not be solely relied upon in evaluating our performance. Further, information contained in the following table should not be considered as representative of realistic assessments of future cash flows, nor should the Standardized Measure of Discounted Future Net Cash Flows be viewed as representative of the current value of our oil and natural gas reserves or the current value of the Company.
	We believe that the following factors should be taken into account in reviewing the following information: (1) future costs and sales prices are likely to differ materially from those required to be used in these calculations; (2) due to future market conditions, governmental regulations and other factors, actual rates of production achieved in future years may vary significantly from the rate of production assumed in the calculations; (3) the use of a 10% discount rate, while mandated under ASC 932, is arbitrary and may not be reasonable as a measure of the relative risk inherent in realizing future net oil and gas revenues; and (4) future net revenues may be subject to different rates of income taxation.
	The Standardized Measure of Discounted Future Net Cash Flows uses future cash inflows estimated using oil and natural gas prices computed by applying the use of physical pricing based on the simple average of the closing price on the first day of each of the twelve months during the fiscal year (as required by ASC 932) and by applying historical adjustments, including transportation, quality differentials, and purchaser bonuses, on an individual property basis, to the year-end quantities of estimated proved reserves. The historical adjustments applied to the computed prices are determined by comparing our historical realized price experience with the comparable historical market, or posted, price. These adjustments can vary significantly over time both in amount and as a percentage of the posted price, especially related to our oil prices during periods when the market price for oil varies widely. The price adjustments reflected in our computed reserve prices may not represent the amount of price adjustments we may actually obtain in the future when we sell our production, nor do they give effect to any hedging transactions that we may enter into.  Future cash inflows were reduced by estimated future development, abandonment and production costs based on period-end costs with the assumption of the continuation of existing economic conditions in order to arrive at net cash flows before tax. Future income tax expense has been computed by applying period-end statutory tax rates to aggregate future net cash flows, reduced by the tax basis of the properties involved and tax carryforwards. Use of a 10% annual discount rate in computing Standardized Measure of Discounted Future Net Cash Flows is required by ASC 932.
	The standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves is as follows:
			Year Ended December 31,
			2013		2012
			(In thousands)
Future cash inflows		$	5,937,536	$	5,401,290
Future production costs			-1,957,868		-1,823,303
Future development costs (1)			-1,085,440		-936,580
Future income taxes			-641,536		-537,546
Future net cash flows after income taxes			2,252,692		2,103,861
10% annual discount for estimated timing of cash flows			-603,614		-529,579
Standardized measure of discounted future net cash flows		$	1,649,078	$	1,574,282
	-1		Future development costs as of December 31, 2013, include $569.9 million of estimated abandonment and decommissioning costs, net of $25.8 million of estimated salvage values.  Future development costs as of December 31, 2012 include $466.9 million of estimated abandonment and decommissioning costs, net of $32.6 million of estimated salvage values.
A summary of the changes in the standardized measure of discounted future net cash flows applicable to proved oil and natural gas reserves for the years ended December 31, 2013 and 2012 is as follows:
		Year Ended December 31,
		2013		2012
		(In thousands)
Beginning of the period		$	1,574,282	$	876,169
Sales and transfers of oil and natural gas produced, net of production costs			-513,906		-317,059
Net changes in prices and production costs			96,751		-244,824
Purchase of minerals in place			26,708		797,085
Sales of minerals in place			-64,539		-
Extensions, discoveries and improved recoveries, net of future production costs			363,493		452,258
Revision of quantity estimates			84,490		55,133
Previously estimated development costs incurred during the period			33,920		39,321
Changes in estimated future development costs			18,229		746
Changes in production rates (timing) and other			-113,022		-14,157
Accretion of discount			197,927		110,070
Net change in income taxes			-55,255		-180,460
Net increase (decrease)			74,796		698,113
End of period		$	1,649,078	$	1,574,282
At December 31, 2013 and 2012, the computation of the standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves was based on the following computed prices:
		2013		2012
per barrel of oil		$	105.30	$	105.13
per Mcf for natural gas		$	3.73	$	2.92

Supplemental_Condensed_Consoli

Supplemental Condensed Consolidating Financial Information	12 Months Ended
	Dec. 31, 2013
Supplemental Condensed Consolidating Financial Information [Abstract]	'
Supplemental Condensed Consolidating Financial Information	'
	(16) Supplemental Condensed Consolidating Financial Information
	In connection with issuing the 8.25% Senior Notes described in Note 7, all of our existing direct and indirect domestic subsidiaries (other than immaterial subsidiaries) each of which is 100% owned by EPL Oil & Gas, Inc. (the “Guarantor Subsidiaries”) jointly and severally guaranteed the payment obligations under our 8.25% Senior Notes. The guarantees are full and unconditional, as those terms are used in Rule 3-10 of Regulation S-X, except that a Guarantor Subsidiary can be automatically released and relieved of its obligations under certain customary circumstances contained in the 2011 Indenture.  So long as other applicable provisions of the indenture are adhered to, these customary circumstances include: when a Guarantor Subsidiary is declared “unrestricted” for covenant purposes, when the requirements for legal defeasance or covenant defeasance or to discharge the indenture have been satisfied, or when the Guarantor Subsidiary is sold or sells all of its assets. The following supplemental financial information sets forth, on a consolidating basis, the balance sheets, statements of operations and cash flow information for EPL Oil & Gas, Inc. (Parent Company Only) and for the Guarantor Subsidiaries. We have not presented separate financial statements and other disclosures concerning the Guarantor Subsidiaries, or for any individual Guarantor Subsidiary, because management has determined that such information is not material to investors.
	The supplemental condensed consolidating financial information has been prepared pursuant to the rules and regulations for condensed financial information and does not include all disclosures included in annual financial statements. Certain reclassifications were made to conform all of the financial information to the financial presentation on a consolidated basis. The principal eliminating entries eliminate investments in subsidiaries, intercompany balances and intercompany revenues and expenses.
	Supplemental Condensed Consolidating Balance Sheet
	As of December 31, 2013
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	8,812	$	-	$	-	$	8,812
	Trade accounts receivable - net		70,520		187		-		70,707
	Intercompany receivables		39,085		-		-39,085		-
	Fair value of commodity derivative instruments		501		-		-		501
	Deferred tax asset		8,949		-		-		8,949
	Prepaid expenses		6,868		-		-		6,868
	Total current assets		134,735		187		-39,085		95,837
	Property and equipment		2,041,689		313,530		-		2,355,219
	Less accumulated depreciation, depletion, amortization and impairments		-526,736		-92,052		-		-618,788
	Net property and equipment		1,514,953		221,478		-		1,736,431
	Investment in affiliates		122,697		-		-122,697		-
	Deposit for Nexen Acquisition		7,040		-		-		7,040
	Restricted cash		6,023		-		-		6,023
	Fair value of commodity derivative instruments		238		-		-		238
	Deferred financing costs		10,106		-		-		10,106
	Other assets		2,067		89		-		2,156
	Total assets	$	1,797,859	$	221,754	$	-161,782	$	1,857,831
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Current liabilities:
	Accounts payable	$	58,758	$	673	$	-	$	59,431
	Intercompany payables		-		39,085		-39,085		-
	Accrued expenses		131,111		14		-		131,125
	Asset retirement obligations		51,601		-		-		51,601
	Fair value of commodity derivative instruments		29,636		-		-		29,636
	Total current liabilities		271,106		39,772		-39,085		271,793
	Long-term debt		627,355		-		-		627,355
	Asset retirement obligations		160,466		43,383		-		203,849
	Deferred tax liabilities		106,910		15,902		-		122,812
	Fair value of commodity derivative instruments		2,136		-		-		2,136
	Other		673		-		-		673
	Total liabilities		1,168,646		99,057		-39,085		1,228,618
	Stockholders’ equity:
	Preferred stock		-		-		-		-
	Common stock		41		-		-		41
	Additional paid-in capital		519,114		85,479		-85,479		519,114
	Treasury stock, at cost		-31,157		-		-		-31,157
	Retained earnings		141,215		37,218		-37,218		141,215
	Total stockholders’ equity		629,213		122,697		-122,697		629,213
	Total liabilities and stockholders' equity	$	1,797,859	$	221,754	$	-161,782	$	1,857,831
	Supplemental Condensed Consolidating Balance Sheet
	As of December 31, 2012
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	1,521	$	-	$	-	$	1,521
	Trade accounts receivable - net		66,994		997		-		67,991
	Intercompany receivables		55,575		-		-55,575		-
	Fair value of commodity derivative instruments		3,302		-				3,302
	Deferred tax asset		3,322		-		-		3,322
Prepaid expenses		9,873		-				9,873
Total current assets		140,587		997		-55,575		86,009
Property and equipment		1,754,294		271,353		-		2,025,647
Less accumulated depreciation, depletion, amortization and impairments		-353,526		-74,054		-		-427,580
Net property and equipment		1,400,768		197,299		-		1,598,067
Investment in affiliates		111,191		-		-111,191		-
Restricted cash		6,023		-		-		6,023
Fair value of commodity derivative instruments		211		-		-		211
Deferred financing costs		12,386		-		-		12,386
Other assets		2,841		90		-		2,931
Total assets	$	1,674,007	$	198,386	$	-166,766	$	1,705,627
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	34,740	$	32	$	-	$	34,772
Intercompany payables		-		55,575		-55,575		-
Accrued expenses		117,245		127		-		117,372
Asset retirement obligations		23,982		6,197		-		30,179
Fair value of commodity derivative instruments		10,026		-		-		10,026
Total current liabilities		185,993		61,931		-55,575		192,349
Long-term debt		689,911		-		-		689,911
Asset retirement obligations		187,790		17,141		-		204,931
Deferred tax liabilities		59,571		8,123		-		67,694
Fair value of commodity derivative instruments		3,637		-		-		3,637
Other		1,132		-		-		1,132
Total liabilities		1,128,034		87,195		-55,575		1,159,654
Stockholders’ equity:
Preferred stock		-		-		-		-
Common stock		40		-		-		40
Additional paid-in capital		510,469		85,479		-85,479		510,469
Treasury stock		-20,477		-		-		-20,477
Retained earnings		55,941		25,712		-25,712		55,941
Total stockholders’ equity		545,973		111,191		-111,191		545,973
Total liabilities and stockholders' equity	$	1,674,007	$	198,386	$	-166,766	$	1,705,627
Supplemental Condensed Consolidating Statement of Operations
Year Ended December 31, 2013
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	606,743	$	82,000	$	-	$	688,743
Other		689		3,606		-		4,295
Total revenue		607,432		85,606		-		693,038
Costs and expenses:
Lease operating		140,605		25,236		-		165,841
Transportation		3,548		20		-		3,568
Exploration expenditures and dry hole costs		22,265		4,290		-		26,555
Impairments		2,937		-		-		2,937
Depreciation, depletion and  amortization		178,427		21,932		-		200,359
Accretion of liability for asset retirement obligations		23,196		5,103		-		28,299
General and administrative		28,137		-		-		28,137
Taxes, other than on earnings		1,084		10,406		-		11,490
Gain on sale of assets		-28,219		-462		-		-28,681
Other		34,072		870		-		34,942
Total costs and expenses		406,052		67,395		-		473,447
Income from operations		201,380		18,211		-		219,591
Other income (expense):
Interest income		99		-		-		99
Interest expense		-52,368		-		-		-52,368
Loss on derivative instruments		-32,361		-		-		-32,361
Income from equity investments		11,506		-		-11,506		-
Total other income (expense)		-73,124		-		-11,506		-84,630
Income before provision for income taxes		128,256		18,211		-11,506		134,961
Deferred income tax expense		-42,982		-6,705		-		-49,687
Net income	$	85,274	$	11,506	$	-11,506	$	85,274
Supplemental Condensed Consolidating Statement of Operations
Year Ended December 31, 2012
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	318,749	$	103,780	$	-	$	422,529
Other		15,152		952		-15,000		1,104
Total revenue		333,901		104,732		-15,000		423,633
Costs and expenses:
Lease operating		71,002		23,848		-		94,850
Transportation		611		4		-		615
Exploration expenditures and dry hole costs		18,790		9		-		18,799
Impairments		8,883		-		-		8,883
Depreciation, depletion and  amortization		92,689		20,892		-		113,581
Accretion of liability for asset retirement obligations		10,551		5,014		-		15,565
General and administrative		22,845		15,363		-15,000		23,208
Taxes, other than on earnings		1,162		11,845		-		13,007
Other		5,496		-818		-		4,678
Total costs and expenses		232,029		76,157		-15,000		293,186
Income from operations		101,872		28,575		-		130,447
Other income (expense):
Interest income		136		-		-		136
Interest expense		-28,568		-		-		-28,568
Loss on derivative instruments		-13,305		-		-		-13,305
Income from equity investments		18,945		-		-18,945		-
Total other income (expense)		-22,792		-		-18,945		-41,737
Income before provision for income taxes		79,080		28,575		-18,945		88,710
Deferred income tax expense		-20,270		-9,630		-		-29,900
Net income	$	58,810	$	18,945	$	-18,945	$	58,810
Supplemental Condensed Consolidating Statement of Operations
Year Ended December 31, 2011
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	245,567	$	102,640	$	-	$	348,207
Other		15,007		113		-15,000		120
Total revenue		260,574		102,753		-15,000		348,327
Costs and expenses:
Lease operating		51,618		18,663		-		70,281
Transportation		766		13		-		779
Exploration expenditures and dry hole costs		14,045		223		-		14,268
Impairments		32,532		-66		-		32,466
Depreciation, depletion and  amortization		82,168		22,456				104,624
Accretion of liability for asset retirement obligations		9,013		6,929				15,942
General and administrative		18,281		15,460		-15,000		18,741
Taxes, other than on earnings		-733		15,098		-		14,365
Other		9,940		-205		-		9,735
Total costs and expenses		217,630		78,571		-15,000		281,201
Income from operations		42,944		24,182		-		67,126
Other income (expense):
Interest income		102		-		-		102
Interest expense		-17,548		-		-		-17,548
Loss on derivative instruments		-5,870		-		-		-5,870
Loss on early extinguishment of debt		-2,377		-		-		-2,377
Loss from equity investments		15,532		-		-15,532		-
Total other income (expense)		-10,161		-		-15,532		-25,693
Loss  before provision for income taxes		32,783		24,182		-15,532		41,433
Deferred income tax expense		-6,172		-8,650		-		-14,822
Net income	$	26,611	$	15,532	$	-15,532	$	26,611
Supplemental Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2013
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Net cash provided by operating activities	$	356,597	$	30,962	$	-	$	387,559
Cash flows provided by (used in) investing activities:
Property acquisitions		-27,560		-		-		-27,560
Deposit for Nexen Acquisition		-7,040		-		-		-7,040
Exploration and development expenditures		-284,073		-37,967		-		-322,040
Other property and equipment additions		-2,016		-		-		-2,016
Proceeds from sale of assets		45,312		7,005		-		52,317
Net cash used in investing activities		-275,377		-30,962		-		-306,339
Cash flows provided by (used in) financing activities:
Repayments of indebtedness		-65,000		-		-		-65,000
Deferred financing costs		-674		-		-		-674
Purchase of shares into treasury		-9,640		-		-		-9,640
Exercise of stock options		1,385		-		-		1,385
Net cash used in financing activities		-73,929		-		-		-73,929
Net decrease in cash and cash equivalents		7,291		-		-		7,291
Cash and cash equivalents at beginning of period		1,521		-		-		1,521
Cash and cash equivalents at end of period	$	8,812	$	-	$	-	$	8,812
Supplemental Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2012
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Net cash provided by operating activities	$	190,851	$	23,020	$	-	$	213,871
Cash flows provided by (used in) investing activities:
Property acquisitions		-575,372		-3,000		-		-578,372
Exploration and development expenditures		-165,308		-19,542		-		-184,850
Other property and equipment additions		-1,265		-478		-		-1,743
Net cash used in investing activities		-741,945		-23,020		-		-764,965
Cash flows provided by (used in) financing activities:
Proceeds from indebtedness		509,313		-		-		509,313
Repayments of indebtedness		-20,000		-		-		-20,000
Deferred financing costs		-8,469		-		-		-8,469
Purchase of shares into treasury		-8,798		-		-		-8,798
Exercise of stock options		441		-		-		441
Net cash provided by financing activities		472,487		-		-		472,487
Net increase in cash and cash equivalents		-78,607		-		-		-78,607
Cash and cash equivalents at beginning of period		80,128		-		-		80,128
Cash and cash equivalents at end of period	$	1,521	$	-	$	-	$	1,521
Supplemental Condensed Consolidating Statement of Cash Flows
Year Ended December 31, 2011
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Net cash provided by operating activities	$	136,245	$	35,007	$	-	$	171,252
Cash flows provided by (used in) investing activities:
Decrease in restricted cash		2,466		-		-		2,466
Property acquisitions		-235,486		-		-		-235,486
Exploration and development expenditures		-40,996		-35,007		-		-76,003
Other property and equipment additions		-1,568		-		-		-1,568
Net cash used in investing activities		-275,584		-35,007		-		-310,591
Cash flows provided by (used in) financing activities:
Proceeds from indebtedness		203,794		-		-		203,794
Deferred financing costs		-6,646		-		-		-6,646
Purchase of shares into treasury		-11,353		-		-		-11,353
Exercise of stock options		119		-		-		119
Net cash provided by financing activities		185,914		-		-		185,914
Net increase in cash and cash equivalents		46,575		-		-		46,575
Cash and cash equivalents at beginning of period		33,553		-		-		33,553
Cash and cash equivalents at end of period	$	80,128	$	-	$	-	$	80,128

Organization_and_Summary_of_Si1

Organization and Summary of Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2013
Organization and Summary of Significant Accounting Policies [Abstract]	'
Basis of Presentation	'
	(a) Basis of Presentation
	The consolidated financial statements have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”) and include the accounts of EPL Oil & Gas, Inc. and our wholly-owned subsidiaries. All significant intercompany accounts and transactions are eliminated in consolidation. Our interests in oil and natural gas exploration and production ventures and partnerships are proportionately consolidated.
Property and Equipment	'
	(b) Property and Equipment
	We use the successful efforts method of accounting for oil and natural gas producing activities. Costs to acquire mineral interests in oil and natural gas properties, to drill and equip exploratory wells that find proved reserves, and to drill and equip development wells are capitalized. Exploratory drilling costs are initially capitalized, but charged to expense if and when the well is determined not to have found reserves in commercial quantities. We may capitalize exploratory well costs beyond one year if (a) we found a sufficient quantity of reserves to justify its completion as a producing well and (b) we are making sufficient progress assessing the reserves and the economic and operating viability of the project; otherwise, these costs are expensed. Geological and geophysical costs are charged to expense as incurred.
	Leasehold acquisition costs are capitalized as unproved properties. If proved reserves are found on undeveloped leases, the related leasehold costs are transferred to proved properties and amortized using the units of production method. For individual unevaluated properties with capitalized costs below a threshold amount, we allocate capitalized costs to earnings generally over the primary lease terms. Properties that are subject to amortization and those with capitalized costs greater than the threshold amount are assessed for impairment periodically. Capitalized costs of producing oil and natural gas properties are depreciated and depleted by the units-of-production method.
	We evaluate our capitalized costs of proved oil and natural gas properties for potential impairment when circumstances indicate that the carrying values may not be recoverable. The need to test a property for impairment can be based on several factors, including a significant reduction in sales prices for oil and/or natural gas, unfavorable adjustments to reserve volumes, actual operating and development costs in excess of expected amounts, changes in estimates of future operating and capital expenditure requirements, or other changes to contracts, environmental regulations or tax laws. The calculation is performed on a field-by-field basis, utilizing our current estimates of future revenues and operating expenses. In the event net undiscounted cash flow is less than the carrying value, an impairment loss is recorded based on the present value of expected future net cash flows over the economic lives of the reserves.
	On the sale or retirement of a complete unit of a proved property, the cost and related accumulated depletion, depreciation and amortization are eliminated from the property accounts, along with the related asset retirement obligations, unless retained by us, and the resulting gain or loss is recognized in earnings.
Asset Retirement Obligation	'
	(c) Asset Retirement Obligations
	We record our obligations associated with the retirement of tangible long-lived assets at their fair values in the period incurred. The fair value of the obligation is also recorded to the related asset’s carrying amount. Accretion of the liability is recognized as an operating expense and the capitalized cost is amortized using the units-of-production method. We revise our estimates of asset retirement obligations as information about material changes to the liability becomes known. Revisions are recorded as adjustments to existing liabilities and to the carrying amount of the related assets. Revisions occurring at or near the end of an asset’s useful life may result in impairments or losses and could materially impact earnings. Our asset retirement obligations relate primarily to the plugging and abandonment of our oil and natural gas wellbores and to decommissioning related pipelines, facilities and structures.
Income Taxes	'
	(d) Income Taxes
	We account for income taxes under the asset and liability method, which requires that we recognize deferred tax assets and liabilities for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis amounts. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. We recognize the effect on deferred tax assets and liabilities of a change in the tax rates in income in the period that includes the enactment date.
	We follow the provisions of Accounting Standards Codification (“ASC”) Topic 740, “Income Taxes,” which apply to the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements and prescribe a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. These provisions also contain guidance on de-recognition, classification, interest and penalties. Interest, if any, is classified as a component of interest expense, and statutory penalties, if any, are classified as a component of general and administrative expense.
Deferred Financing Costs	'
	(e) Deferred Financing Costs
	We defer costs incurred to obtain debt financing and then amortize such costs as additional interest expense over the maturity period of the related debt using the effective interest rate method.
Earnings Per Share	'
	(f) Earnings Per Share
	Basic earnings per share is computed by dividing income or loss available to common stockholders by the weighted average number of common shares outstanding during each period. According to GAAP, we have determined that our unvested restricted share awards, which contain non-forfeitable rights to dividends, are participating securities and should be included in the computation of earnings per share pursuant to the “two-class” method. The “two-class” method allocates undistributed earnings between common shares and participating securities. The diluted earnings per share calculation under the “two-class” method also includes the effect, if dilutive, of potential common shares associated with stock option awards outstanding during each period. The dilutive effect of stock options is determined using the treasury stock method.
Revenue Recognition	'
	(g) Revenue Recognition
	We record revenues from the sales of oil and natural gas when the product is delivered at a determinable price, title has transferred and collectability is reasonably assured. When we have an interest with other producers in properties from which natural gas is produced, we use the entitlement method for recording natural gas sales revenue. Under this method of accounting, revenue is recorded based on our net revenue interest in production. Deliveries of natural gas in excess of our revenue interest are recorded as liabilities and under-deliveries are recorded as receivables. We had natural gas imbalance liabilities of $2.0 million and $1.7 million at December 31, 2013 and 2012, respectively. We had natural gas imbalance receivables of $1.9 million and $0.8 million at December 31, 2013 and 2012, respectively.
Cash and Cash Equivalents	'
	(h) Cash and Cash Equivalents
	We include in cash and cash equivalents our highly-liquid investments with original maturities of three months or less. At December 31, 2013 and 2012, cash and cash equivalents includes investments in overnight interest-bearing deposits of $7.3 million and $2.3 million, respectively. These amounts are reduced by overdraft balances on other operating accounts with legal right of offset in the same banking institution to arrive at the cash and cash equivalent balances reported in our consolidated balance sheets.
Derivative Activities	'
	(i) Derivative Activities
	Derivative instruments, including certain derivative instruments embedded in other contracts, are recorded at fair value and included as either assets or liabilities in the balance sheet. The accounting for changes in fair value depends on the intended use of the derivative and the resulting designation, which is established at the inception of the derivative. We do not elect to designate derivative instruments as hedges. Gains and losses resulting from changes in the fair value of derivative instruments are recorded in other income (expense). Gains and losses related to contract settlements are also recorded in other income (expense).
Share-Based Compensation	'
	(j) Share-Based Compensation
	We recognize share-based compensation expense based on the estimated grant-date fair value of all share-based awards, net of an estimated forfeiture rate, over the requisite service period of the awards, which is generally equivalent to the vesting term. We record share-based compensation expense only for those awards expected to vest. We periodically revise our estimated forfeiture rate if actual forfeitures differ from our estimates.
	We are required to report excess tax benefits from the exercise of stock options as financing cash flows. For the year ended December 31, 2013 and 2012, no excess tax benefits were reported in the statement of cash flows as we were in a net operating loss carryforward position. See Note 12 for additional disclosures.
Allowance for Doubtful Accounts	'
	(k) Allowance for Doubtful Accounts
	We routinely assess the recoverability of all material trade and other receivables to determine their collectability. Our crude oil and natural gas revenue receivables are typically collected within two months. We may have the ability to withhold future revenue disbursements to recover any non-payment of joint interest receivables on properties where we are the operator. When we believe collection of the full amount of our accounts receivable is in doubt, we record an allowance to reflect accounts receivable at the net realizable value, which may be reflected in earnings or as an increase to the net book value of our oil and natural gas properties depending on the nature of the transaction that created the receivable. The nature of the transaction resulting in the receivable balance determines whether the allowance, when recorded, impacts our earnings (ordinarily through LOE) or our property and equipment balances. As of December 31, 2013, our allowance for doubtful accounts was $0.7 million, $0.1 million of which was recorded as a recovery in earnings in 2013. As of December 31, 2012, our allowance for doubtful accounts was $0.7 million, $0.1 million of which was recorded as a recovery in earnings in 2012.
Accrued Expenses	'
	(l) Accrued Expenses
	As of December 31, 2013, our accrued expenses included accrued exploration costs, development costs and lease operating expenses totaling approximately $107.8 million, other accrued expenses of $7.5 million and interest payable of approximately $15.8 million. As of December 31, 2012, our accrued expenses included accrued exploration costs, development costs and lease operating expenses totaling approximately $84.9 million, other accrued expenses of $16.3 million and interest payable of approximately $16.2 million.
Use of Estimates	'
	(m) 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 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. Certain accounting policies involve judgments and uncertainties to such an extent that there is reasonable likelihood that materially different amounts could have been reported under different conditions, or if different assumptions had been used. We evaluate our estimates and assumptions on a regular basis. We use historical experience and various other assumptions that are believed to be reasonable under the circumstances to form the basis for making judgments about carrying values of assets and liabilities that are not readily apparent from other sources. Our actual results may differ from these estimates and assumptions used in preparation of our financial statements. Significant estimates with regard to these financial statements and related unaudited disclosures include the estimate of proved oil and natural gas reserve quantities and the related present value of estimated future net cash flows therefrom disclosed in Note 15.
New Accounting Pronouncements	'
	(n) New Accounting Pronouncements
	Effective January 1, 2013, we adopted the amended disclosure requirements contained in ASU 2011-11, “Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities.” This guidance impacted the disclosures associated with our derivative instruments and did not impact our consolidated financial position, results of operations or cash flows.  See Note 7, “Fair Value Measurements,” of our consolidated financial statements in Part I, Item 1 of this Quarterly Report for related disclosures.
	In July 2013, the Financial Accounting Standards Board issued Accounting Standards Update (ASU) No. 2013-11, “Presentation of an Unrecognized Tax Benefit When a Net Operating Loss Carryforward, a Similar Tax Loss, or a Tax Credit Carryforward Exists.”  The amendments in this update clarify the financial statement presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists.  The amendments are effective for fiscal years, and interim periods within those years, beginning December 15, 2013.  We do not expect this guidance to have a material impact on our consolidated financial position, results of operations or cash flows.

Acquisitions_and_Dispositions_

Acquisitions and Dispositions (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule of Revenues and Lease Operating Expenses Attributable to the ST 41 Interests, the ASOP Properties and the Main Pass Interests	'
			Year Ended December 31,
			2013		2012		2011
			(In thousands)
	WD29 Interests:
	Revenues		$	3,011	$	-	$	-
	Lease operating expenses		$	44	$	-	$	-
	Hilcorp Properties:
	Revenues		$	208,241	$	37,978	$	-
	Lease operating expenses		$	74,404	$	10,982	$	-
	ST41 Interests:
	Revenues		$	11,189	$	9,262	$	-
	Lease operating expenses		$	2,468	$	1,760	$	-
	ASOP Properties and Main Pass Interests:
	Revenues		$	328,070	$	175,538	$	125,975
	Lease operating expenses		$	33,978	$	26,467	$	17,161
Schedule of Consolidated Results of Operations	'
			Year Ended December 31,
			Pro Forma
			2012
	(in thousands, except per share data)
	Revenue		$	594,510
	Net income		$	59,324
	Basic earnings per share		$	1.51
	Diluted earnings per share		$	1.51
Nexen Acquisition [Member]	'
Schedule of Assets Acquired and Liabilities Assumed	'
	(In thousands)	1-Sep-13
	Oil and natural gas properties	$	93,932
	Asset retirement obligations		-27,133
	Net assets acquired	$	66,799
Non-Operated Bay Marchand Field Disposition [Member]	'
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block]	'
	(In thousands)	1-Jan-13
	Oil and natural gas properties	$	35,298
	Asset retirement obligations		-3,959
	Other liabilities		-7,311
	Net assets sold	$	24,028
Hilcorp Acquisition [Member]	'
Schedule of Assets Acquired and Liabilities Assumed	'
	(In thousands)	1-Jul-12
	Oil and natural gas properties	$	698,660
	Asset retirement obligations		-150,959
	Net assets acquired	$	547,701
South Timbalier Acquisition [Member]	'
Schedule of Assets Acquired and Liabilities Assumed	'
	(In thousands)	April 1, 2012
	Oil and natural gas properties	$	33,206
	Asset retirement obligations		-1,878
	Net assets acquired	$	31,328
ASOP Acquisition [Member]	'
Schedule of Assets Acquired and Liabilities Assumed	'
	(In thousands)	1-Jan-11
	Oil and natural gas properties	$	221,751
	Asset retirement obligations		-24,858
	Net assets acquired	$	196,893
Main Pass Acquisition [Member]	'
Schedule of Assets Acquired and Liabilities Assumed	'
	(In thousands)	1-Nov-11
	Oil and natural gas properties	$	40,826
	Asset retirement obligations		-2,991
	Net assets acquired	$	37,835
West Delta 29 Acquisition [Member]	'
Schedule of Assets Acquired and Liabilities Assumed	'
	(In thousands)	1-Jan-13
	Oil and natural gas properties	$	16,696
	Asset retirement obligations		-1,398
	Net assets acquired	$	15,298

Earnings_per_Share_Tables

Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2013
Earnings per Share [Abstract]	'
Basic and Diluted Weighted Average Shares Outstanding and Earnings per Share	'
		Year Ended December 31,
		2013		2012		2011
		(in thousands, except per share data)
	Income (numerator):
	Net income	$	85,274	$	58,810	$	26,611
	Net income attributable to participating securities		-943		-455		-77
	Net income attributable to common shares	$	84,331	$	58,355	$	26,534
	Weighted average shares (denominator):
	Weighted average shares—basic		38,730		38,885		39,946
	Dilutive effect of stock options		506		149		104
	Weighted average shares—diluted		39,236		39,034		40,050
	Basic earnings per share	$	2.18	$	1.50	$	0.66
	Diluted earnings per share	$	2.15	$	1.50	$	0.66
Number of Antidilutive Shares Excluded from the Computation of Dilutive Weighted Average Shares	'
		Year Ended December 31,
		2013		2012		2011
		(in thousands)
	Weighted average shares		273		687		442

Property_and_Equipment_Tables

Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2013
Property and Equipment [Abstract]	'
Property and Equipment	'
		December 31,
			2013		2012
		(In thousands)
	Proved oil and natural gas properties	$	2,307,891	$	1,982,657
	Unproved oil and natural gas properties		39,191		36,992
	Other		8,137		5,998
	Total property and equipment	$	2,355,219	$	2,025,647

Asset_Retirement_Obligations_T

Asset Retirement Obligations (Tables)	12 Months Ended
	Dec. 31, 2013
Asset Retirement Obligations [Abstract]	'
Schedule of Changes in Asset Retirement Obligations	'
			Year Ended December 31,
			2013		2012
			(in thousands)
	Beginning of period total	$	235,110	$	99,347
	Accretion expense		28,299		15,565
	Liabilities assumed in acquisitions		23,541		132,109
	Liabilities incurred		1,187		1,210
	Revisions		24,586		22,308
	Liabilities associated with assets sold		-3,965		-
	Liabilities settled		-53,308		-35,429
	End of period total		255,450		235,110
	Less: End of period, current portion		51,601		30,179
	End of period, noncurrent portion	$	203,849	$	204,931

Indebtedness_Tables

Indebtedness (Tables)	12 Months Ended
	Dec. 31, 2013
Schedule of Indebtedness	'
			December 31,
			2013		2012
			(In thousands)
	8.25% senior notes issued February 14, 2011 and October 25, 2012, face amount of $510.0 million,  interest rate of 8.25% payable semi-annually, in arrears on  February 15 and August 15 of each year, maturity date February 15, 2018		$	497,355	$	494,911
	Senior Credit Facility, interest rate based on base rate or LIBOR plus a floating spread, maturity date October 31, 2016			130,000		195,000
	Total indebtedness			627,355		689,911
	Current portion of indebtedness			-		-
	Noncurrent portion of indebtedness		$	627,355	$	689,911
8.25% Senior Notes [Member]	'
Schedule of Redeemable Debt	'
	Year	Percentage
	2015	104.125%
	2016	102.063%
	2017 and thereafter	100.000%

Recovered_Sheet1

Derivative Instruments And Hedging Activities (Tables)	12 Months Ended
	Dec. 31, 2013
Derivative Instruments and Hedging Activities [Abstract]	'
Schedule of Derivative Instruments Outstanding	'
		Fixed-Price Swaps
		Daily Average				Average
		Volume		Volume		Swap Price
	Remaining Contract Term	(Bbls)		(Bbls)		($/Bbl)
	Jan-14		16,350		506,850		93.11
	Feb-14		16,350		457,800		93.11
	Mar-14		16,350		506,850		93.11
	Apr-14		15,350		460,500		94.27
	May-14		15,350		475,850		94.27
	Jun-14		15,350		460,500		94.27
	Jul-14		14,350		444,850		93.56
	Aug-14		8,750		271,250		94.28
	Sep-14		8,750		262,500		94.28
	Oct-14		8,750		271,250		94.28
	Nov-14		8,750		262,500		94.28
	Dec-14		11,700		362,700		91.90
	2014 Total		12,996		4,743,400		93.67
	January 2015 - December 2015		1,500		547,500		97.70
	Gas Contracts
		Fixed-Price Swaps
		Daily Average				Average
		Volume		Volume		Swap Price
	Remaining Contract Term	(Mmbtu)		(Mmbtu)		($/Mmbtu)
	January 2014 - December 2014		5,000		1,825,000		4.01
	January 2015 - December 2015		4,300		1,569,500		4.31
Components of Gain (Loss) on Derivative Instruments	'
		Year Ended December 31,
		2013		2012		2011
		(in thousands)
	Change in fair market value	$	-20,884	$	-9,491	$	11,475
	Loss on settlement		-11,477		-3,814		-17,345
	Total loss on derivative instruments	$	-32,361	$	-13,305	$	-5,870

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2013
Fair Value Measurements [Abstract]	'
Schedule of Fair Value Measurements of Assets and Liabilities	'
		December 31,
		2013		2012
		(in thousands)
	Assets:
	Current	$	501	$	3,302
	Noncurrent		238		211
	Total gross fair value		739		3,513
	Less: counterparty set-off		-739		-3,513
	Total net fair value		-		-
	Liabilities:
	Current	$	29,636	$	10,026
	Noncurrent		2,136		3,637
	Total gross fair value		31,772		13,663
	Less: counterparty set-off		-739		-3,513
	Total net fair value		31,033		10,150
Schedule of Carrying Values and Estimated Fair Values of Debt Instruments [Table Text Block]	'
		31-Dec-13					31-Dec-12
		(In thousands)
			Carrying Value		Estimated Fair Value		Carrying Value		Estimated Fair Value
	8.25% Senior Notes	$	497,355	$	546,338	$	494,911	$	524,600
	Senior Credit Facility		130,000		130,000		195,000		195,000
	Total	$	627,355	$	676,338	$	689,911	$	719,600

Income_Taxes_Tables

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2013
Income Taxes [Abstract]	'
Schedule of Components of Income Tax Expense (Benefit)	'
			Year Ended December 31,
			2013				2012			2011
		(In thousands)
	Current:
	Federal		$	-			$	-		$	-
	State			-				-			-
	Total current		$	-			$	-		$	-
	Deferred:
	Federal		$	-47,723			$	-28,719		$	-14,468
	State			-1,964				-1,181			-354
	Total deferred		$	-49,687			$	-29,900		$	-14,822
	Total:
	Federal		$	-47,723			$	-28,719		$	-14,468
	State			-1,964				-1,181			-354
	Total provision for income taxes.		$	-49,687			$	-29,900		$	-14,822
Schedule of Effective Income Tax Rate Reconciliation	'
			Percentage of Pretax Earnings
			Year Ended December 31,
			2013				2012				2011
	Expected statutory federal income tax rate			35.0	%			35.0	%		35.0	%
	State taxes			1.4				1.4			2.3
	State tax rate changes			-				-2.7			-1.7
	Statutory depletion			-0.3				-0.4			-1
	Other			0.7				0.4			1.2
	Effective income tax rate			36.8	%			33.7	%		35.8	%
Schedule of Deferred Tax Assets and Liabilities	'
			December 31,
			2013			2012
			(In thousands)
	Deferred tax assets:
	Federal and state net operating loss carryforwards		$	62,015		$	62,130
	Fair value of commodity derivative instruments			11,578			3,912
	Restricted stock awards and options			3,843			2,313
	Percentage depletion carryforward			5,003			4,575
	Accruals and other			1,130			2,613
	Deferred tax asset			83,569			75,543
	Deferred tax liabilities:
	Property, plant and equipment, principally due to differences in depreciation		$	193,191		$	136,016
	Fair value of commodity derivative instruments			182			214
	Prepaid assets			1,482			1,778
	Accruals and other			2,577			1,907
	Deferred tax liabilities			197,432			139,915
	Net deferred tax liability			113,863			64,372
	Reflected in accompanying balance sheets as:
	Current deferred asset			8,949			3,322
	Non-current deferred liability			122,812			67,694
	Total net deferred tax liability		$	113,863		$	64,372

Employee_Benefit_Plans_Tables

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2013
Employee Benefit Plan [Abstract]	'
Schedule of Share-based Compensation, Stock Options, Activity	'
		Options			Weighted-			Weighted-			Aggregate Intrinsic Value
					Average			Average
					Exercise			Remaining
					Price Per			Contractual
					Share			Terms
								(in years)			(in thousands)
	Outstanding on December 31, 2012		1,192,158		$	14.30
	Granted		369,137			27.48
	Exercised		-108,122			12.80
	Forfeited/Cancelled		-			-
	Outstanding on December 31, 2013		1,453,173		$	17.76			7.8		$	15,970
	Exercisable on December 31, 2013		705,814		$	13.45			6.9		$	10,624
Schedule of Share-based Payment Award, Stock Options, Valuation Assumptions	'
			Year Ended December 31,
			2013			2012			2011
	Black-Scholes option pricing model assumptions:
	Risk free interest rate		1.4	%		1.0	%		1.9	%
	Expected life (years)		6.0			6.0			6.0
	Expected volatility		56	%		56	%		53	%
	Dividend yield		-			-			-
Schedule of Nonvested Share Activity	'
		Shares			Weighted-
					Average
					Grant-
					Date
					Fair Value
	Non-vested share awards outstanding at December 31, 2012		326,952		$	15.98
	Granted		264,383			26.60
	Vested		-145,309			16.77
	Forfeited		-1,531			32.67
	Non-vested share awards outstanding at December 31, 2013		444,495		$	21.98
Schedule of Share-Based Compensation Expense and Related Tax Benefits	'
			Year Ended December 31,
			2013			2012			2011
	Compensation Expense:
	Stock Options	$	3,426		$	2,621		$	1,497
	Non-vested share awards		3,918			2,096			1,012
	Deferred Income Tax Benefit		2,704			1,726			936

Commitments_and_Contingencies_

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2013
Commitments and Contingencies [Abstract]	'
Schedule of Future Minimum Commitments Under Operating Lease Obligations	'
	2014	$	1,073
	2015		1,222
	2016		1,239
	2017		661
	2018		542
	Thereafter		406
	Future minimum commitments	$	5,143

Interim_Financial_Information_1

Interim Financial Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2013
Interim Financial Information (Unaudited) [Abstract]	'
Schedule of Interim Financial Information (Unaudited)	'
			Three Months Ended
			31-Mar		30-Jun		September 30(1)		December 31(2)
			(In thousands, except per share data)
	2013
	Revenues		$	182,349	$	184,087	$	183,992	$	142,610
	Costs and expenses			109,657		98,535		143,178		122,077
	Income from operations			72,692		85,552		40,814		20,533
	Net income (loss)			29,037		69,579		-1,284		-12,058
	Earnings (loss) per share:
	Basic		$	0.74	$	1.77	$	-0.03	$	-0.31
	Diluted			0.73		1.75		-0.03		-0.31
		-1		Included in net income (loss) for the three months ended September 30, 2013 is the loss on abandonment activities totaling $22.6 million resulting from an increase in required scope of work attributable to changes in regulatory interpretations and enforcement by BSEE in the deepwater.
		-2		The decrease in revenue for the quarter ended December 31, 2013 compared to the quarter ended September 30, 2013 is primarily due to a decrease in oil production and a decrease in the average selling prices of our oil.
				Three Months Ended
			31-Mar		30-Jun		30-Sep		December 31 (1)
			(In thousands, except per share data)
	2012
	Revenues		$	98,796	$	99,270	$	86,668	$	138,899
	Costs and expenses			71,501		68,071		67,379		86,235
	Income from operations			27,295		31,199		19,289		52,664
	Net income (loss)			1,503		35,401		-2,247		24,153
	Earnings (loss) per share:
	Basic		$	0.04	$	0.90	$	-0.06	$	0.62
	Diluted			0.04		0.90		-0.06		0.61
	-1

Supplementary_Oil_and_Natural_1

Supplementary Oil and Natural Gas Disclosures (Tables)	12 Months Ended
	Dec. 31, 2013
Supplementary Oil and Natural Gas Disclosures (Unaudited) [Abstract]	'
Schedule of Estimated Net Proved Reserves, Changes in Estimated Net Proved Reserves and Proved Developed Reserves	'
		Oil		Gas		Oil Equivalent
		(Mbbls)		(Mmcf)		(Mboe)
	Estimated Proved Reserves:
	31-Dec-10		17,223		61,251		27,431
	Acquisitions (a)		7,987		8,640		9,427
	Extensions and discoveries		2,266		4,664		3,043
	Revisions		2,778		-6,678		1,666
	Production		-2,953		-9,092		-4,468
	31-Dec-11		27,301		58,785		37,099
	Acquisitions (b)		16,430		115,876		35,742
	Extensions and discoveries (c)		6,388		10,241		8,095
	Revisions		1,128		4,033		1,800
	Production		-3,805		-8,996		-5,304
	31-Dec-12		47,442		179,939		77,432
	Acquisitions		366		209		401
	Sales		-1,415		-916		-1,568
	Extensions and discoveries (d)		7,354		20,247		10,729
	Revisions		3,952		-10,128		2,264
	Production		-6,182		-15,767		-8,810
	31-Dec-13		51,517		173,584		80,448
	Proved developed reserves:
	31-Dec-11		24,791		52,739		33,581
	31-Dec-12		37,908		120,687		58,022
	31-Dec-13		39,439		107,687		57,387
	Proved undeveloped reserves:
	31-Dec-11		2,510		6,046		3,518
	31-Dec-12		9,534		59,252		19,409
	31-Dec-13		12,078		65,897		23,061
Capitalized Costs for Oil and Natural Gas Producing Activities	'
		Year Ended December 31,
		2013		2012
		(In thousands)
	Proved properties	$	2,307,891	$	1,982,657
	Unproved properties		39,191		36,992
	Accumulated depreciation, depletion and amortization		-614,068		-424,520
	Net capitalized costs	$	1,733,014	$	1,595,129
Cost Incurred Associated with Finding, Acquiring and Developing Proved Oil and Natural Gas Reserves	'
		Year Ended December 31,
		2013		2012		2011
		(In thousands)
	Acquisitions — Proved (1)	$	46,047	$	706,322	$	261,812
	Acquisitions — Unproved		2,200		7,496		14
	Exploration		46,100		43,338		17,129
	Development (2)		303,245		180,938		83,577
	Costs incurred	$	397,592	$	938,094	$	362,532
Standardized Measure of Discounted Future Cash Flows Relating to Proved Oil and Natural Gas Reserves Disclosure	'
		Year Ended December 31,
		2013		2012
		(In thousands)
	Future cash inflows	$	5,937,536	$	5,401,290
	Future production costs		-1,957,868		-1,823,303
	Future development costs (1)		-1,085,440		-936,580
	Future income taxes		-641,536		-537,546
	Future net cash flows after income taxes		2,252,692		2,103,861
	10% annual discount for estimated timing of cash flows		-603,614		-529,579
	Standardized measure of discounted future net cash flows	$	1,649,078	$	1,574,282
Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows Applicable to Proved Oil and Natural Gas Reserves	'
		Year Ended December 31,
		2013		2012
		(In thousands)
	Beginning of the period	$	1,574,282	$	876,169
	Sales and transfers of oil and natural gas produced, net of production costs		-513,906		-317,059
	Net changes in prices and production costs		96,751		-244,824
	Purchase of minerals in place		26,708		797,085
	Sales of minerals in place		-64,539		-
	Extensions, discoveries and improved recoveries, net of future production costs		363,493		452,258
	Revision of quantity estimates		84,490		55,133
	Previously estimated development costs incurred during the period		33,920		39,321
	Changes in estimated future development costs		18,229		746
	Changes in production rates (timing) and other		-113,022		-14,157
	Accretion of discount		197,927		110,070
	Net change in income taxes		-55,255		-180,460
	Net increase (decrease)		74,796		698,113
	End of period	$	1,649,078	$	1,574,282
Oil and Natural Gas Computed Price Used in Computation of Discounted Future Net Cash Flows	'
		2013		2012
	per barrel of oil	$	105.30	$	105.13
	per Mcf for natural gas	$	3.73	$	2.92

Supplemental_Condensed_Consoli1

Supplemental Condensed Consolidating Financial Information (Tables)	12 Months Ended
	Dec. 31, 2013
Supplemental Condensed Consolidating Financial Information [Abstract]	'
Supplemental Condensed Consolidating Balance Sheet	'
	Supplemental Condensed Consolidating Balance Sheet
	As of December 31, 2013
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	8,812	$	-	$	-	$	8,812
	Trade accounts receivable - net		70,520		187		-		70,707
	Intercompany receivables		39,085		-		-39,085		-
	Fair value of commodity derivative instruments		501		-		-		501
	Deferred tax asset		8,949		-		-		8,949
	Prepaid expenses		6,868		-		-		6,868
	Total current assets		134,735		187		-39,085		95,837
	Property and equipment		2,041,689		313,530		-		2,355,219
	Less accumulated depreciation, depletion, amortization and impairments		-526,736		-92,052		-		-618,788
	Net property and equipment		1,514,953		221,478		-		1,736,431
	Investment in affiliates		122,697		-		-122,697		-
	Deposit for Nexen Acquisition		7,040		-		-		7,040
	Restricted cash		6,023		-		-		6,023
	Fair value of commodity derivative instruments		238		-		-		238
	Deferred financing costs		10,106		-		-		10,106
	Other assets		2,067		89		-		2,156
	Total assets	$	1,797,859	$	221,754	$	-161,782	$	1,857,831
	LIABILITIES AND STOCKHOLDERS’ EQUITY
	Current liabilities:
	Accounts payable	$	58,758	$	673	$	-	$	59,431
	Intercompany payables		-		39,085		-39,085		-
	Accrued expenses		131,111		14		-		131,125
	Asset retirement obligations		51,601		-		-		51,601
	Fair value of commodity derivative instruments		29,636		-		-		29,636
	Total current liabilities		271,106		39,772		-39,085		271,793
	Long-term debt		627,355		-		-		627,355
	Asset retirement obligations		160,466		43,383		-		203,849
	Deferred tax liabilities		106,910		15,902		-		122,812
	Fair value of commodity derivative instruments		2,136		-		-		2,136
	Other		673		-		-		673
	Total liabilities		1,168,646		99,057		-39,085		1,228,618
	Stockholders’ equity:
	Preferred stock		-		-		-		-
	Common stock		41		-		-		41
	Additional paid-in capital		519,114		85,479		-85,479		519,114
	Treasury stock, at cost		-31,157		-		-		-31,157
	Retained earnings		141,215		37,218		-37,218		141,215
	Total stockholders’ equity		629,213		122,697		-122,697		629,213
	Total liabilities and stockholders' equity	$	1,797,859	$	221,754	$	-161,782	$	1,857,831
	Supplemental Condensed Consolidating Balance Sheet
	As of December 31, 2012
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	ASSETS
	Current assets:
	Cash and cash equivalents	$	1,521	$	-	$	-	$	1,521
	Trade accounts receivable - net		66,994		997		-		67,991
	Intercompany receivables		55,575		-		-55,575		-
	Fair value of commodity derivative instruments		3,302		-				3,302
	Deferred tax asset		3,322		-		-		3,322
	Prepaid expenses		9,873		-				9,873
	Total current assets		140,587		997		-55,575		86,009
	Property and equipment		1,754,294		271,353		-		2,025,647
Less accumulated depreciation, depletion, amortization and impairments		-353,526		-74,054		-		-427,580
Net property and equipment		1,400,768		197,299		-		1,598,067
Investment in affiliates		111,191		-		-111,191		-
Restricted cash		6,023		-		-		6,023
Fair value of commodity derivative instruments		211		-		-		211
Deferred financing costs		12,386		-		-		12,386
Other assets		2,841		90		-		2,931
Total assets	$	1,674,007	$	198,386	$	-166,766	$	1,705,627
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	34,740	$	32	$	-	$	34,772
Intercompany payables		-		55,575		-55,575		-
Accrued expenses		117,245		127		-		117,372
Asset retirement obligations		23,982		6,197		-		30,179
Fair value of commodity derivative instruments		10,026		-		-		10,026
Total current liabilities		185,993		61,931		-55,575		192,349
Long-term debt		689,911		-		-		689,911
Asset retirement obligations		187,790		17,141		-		204,931
Deferred tax liabilities		59,571		8,123		-		67,694
Fair value of commodity derivative instruments		3,637		-		-		3,637
Other		1,132		-		-		1,132
Total liabilities		1,128,034		87,195		-55,575		1,159,654
Stockholders’ equity:
Preferred stock		-		-		-		-
Common stock		40		-		-		40
Additional paid-in capital		510,469		85,479		-85,479		510,469
Treasury stock		-20,477		-		-		-20,477
Retained earnings		55,941		25,712		-25,712		55,941
Total stockholders’ equity		545,973		111,191		-111,191		545,973
Total liabilities and stockholders' equity	$	1,674,007	$	198,386	$	-166,766	$	1,705,627
Supplemental Condensed Consolidating Statement of Operations	'
	Supplemental Condensed Consolidating Statement of Operations
	Year Ended December 31, 2013
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	Revenue:
	Oil and natural gas	$	606,743	$	82,000	$	-	$	688,743
	Other		689		3,606		-		4,295
	Total revenue		607,432		85,606		-		693,038
	Costs and expenses:
	Lease operating		140,605		25,236		-		165,841
	Transportation		3,548		20		-		3,568
	Exploration expenditures and dry hole costs		22,265		4,290		-		26,555
	Impairments		2,937		-		-		2,937
	Depreciation, depletion and  amortization		178,427		21,932		-		200,359
	Accretion of liability for asset retirement obligations		23,196		5,103		-		28,299
	General and administrative		28,137		-		-		28,137
	Taxes, other than on earnings		1,084		10,406		-		11,490
	Gain on sale of assets		-28,219		-462		-		-28,681
	Other		34,072		870		-		34,942
	Total costs and expenses		406,052		67,395		-		473,447
	Income from operations		201,380		18,211		-		219,591
	Other income (expense):
	Interest income		99		-		-		99
	Interest expense		-52,368		-		-		-52,368
	Loss on derivative instruments		-32,361		-		-		-32,361
	Income from equity investments		11,506		-		-11,506		-
	Total other income (expense)		-73,124		-		-11,506		-84,630
	Income before provision for income taxes		128,256		18,211		-11,506		134,961
	Deferred income tax expense		-42,982		-6,705		-		-49,687
	Net income	$	85,274	$	11,506	$	-11,506	$	85,274
	Supplemental Condensed Consolidating Statement of Operations
	Year Ended December 31, 2012
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	Revenue:
	Oil and natural gas	$	318,749	$	103,780	$	-	$	422,529
	Other		15,152		952		-15,000		1,104
	Total revenue		333,901		104,732		-15,000		423,633
	Costs and expenses:
	Lease operating		71,002		23,848		-		94,850
	Transportation		611		4		-		615
	Exploration expenditures and dry hole costs		18,790		9		-		18,799
	Impairments		8,883		-		-		8,883
	Depreciation, depletion and  amortization		92,689		20,892		-		113,581
	Accretion of liability for asset retirement obligations		10,551		5,014		-		15,565
	General and administrative		22,845		15,363		-15,000		23,208
	Taxes, other than on earnings		1,162		11,845		-		13,007
	Other		5,496		-818		-		4,678
	Total costs and expenses		232,029		76,157		-15,000		293,186
	Income from operations		101,872		28,575		-		130,447
	Other income (expense):
	Interest income		136		-		-		136
	Interest expense		-28,568		-		-		-28,568
	Loss on derivative instruments		-13,305		-		-		-13,305
	Income from equity investments		18,945		-		-18,945		-
	Total other income (expense)		-22,792		-		-18,945		-41,737
	Income before provision for income taxes		79,080		28,575		-18,945		88,710
	Deferred income tax expense		-20,270		-9,630		-		-29,900
	Net income	$	58,810	$	18,945	$	-18,945	$	58,810
Supplemental Condensed Consolidating Statement of Operations
Year Ended December 31, 2011
	Parent
	Company		Guarantor
	Only		Subsidiaries		Eliminations		Consolidated
	(In thousands)
Revenue:
Oil and natural gas	$	245,567	$	102,640	$	-	$	348,207
Other		15,007		113		-15,000		120
Total revenue		260,574		102,753		-15,000		348,327
Costs and expenses:
Lease operating		51,618		18,663		-		70,281
Transportation		766		13		-		779
Exploration expenditures and dry hole costs		14,045		223		-		14,268
Impairments		32,532		-66		-		32,466
Depreciation, depletion and  amortization		82,168		22,456				104,624
Accretion of liability for asset retirement obligations		9,013		6,929				15,942
General and administrative		18,281		15,460		-15,000		18,741
Taxes, other than on earnings		-733		15,098		-		14,365
Other		9,940		-205		-		9,735
Total costs and expenses		217,630		78,571		-15,000		281,201
Income from operations		42,944		24,182		-		67,126
Other income (expense):
Interest income		102		-		-		102
Interest expense		-17,548		-		-		-17,548
Loss on derivative instruments		-5,870		-		-		-5,870
Loss on early extinguishment of debt		-2,377		-		-		-2,377
Loss from equity investments		15,532		-		-15,532		-
Total other income (expense)		-10,161		-		-15,532		-25,693
Loss  before provision for income taxes		32,783		24,182		-15,532		41,433
Deferred income tax expense		-6,172		-8,650		-		-14,822
Net income	$	26,611	$	15,532	$	-15,532	$	26,611
Supplemental Condensed Consolidating Statement of Cash Flows	'
	Supplemental Condensed Consolidating Statement of Cash Flows
	Year Ended December 31, 2013
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	Net cash provided by operating activities	$	356,597	$	30,962	$	-	$	387,559
	Cash flows provided by (used in) investing activities:
	Property acquisitions		-27,560		-		-		-27,560
	Deposit for Nexen Acquisition		-7,040		-		-		-7,040
	Exploration and development expenditures		-284,073		-37,967		-		-322,040
	Other property and equipment additions		-2,016		-		-		-2,016
	Proceeds from sale of assets		45,312		7,005		-		52,317
	Net cash used in investing activities		-275,377		-30,962		-		-306,339
	Cash flows provided by (used in) financing activities:
	Repayments of indebtedness		-65,000		-		-		-65,000
	Deferred financing costs		-674		-		-		-674
	Purchase of shares into treasury		-9,640		-		-		-9,640
	Exercise of stock options		1,385		-		-		1,385
	Net cash used in financing activities		-73,929		-		-		-73,929
	Net decrease in cash and cash equivalents		7,291		-		-		7,291
	Cash and cash equivalents at beginning of period		1,521		-		-		1,521
	Cash and cash equivalents at end of period	$	8,812	$	-	$	-	$	8,812
	Supplemental Condensed Consolidating Statement of Cash Flows
	Year Ended December 31, 2012
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	Net cash provided by operating activities	$	190,851	$	23,020	$	-	$	213,871
	Cash flows provided by (used in) investing activities:
	Property acquisitions		-575,372		-3,000		-		-578,372
	Exploration and development expenditures		-165,308		-19,542		-		-184,850
	Other property and equipment additions		-1,265		-478		-		-1,743
	Net cash used in investing activities		-741,945		-23,020		-		-764,965
	Cash flows provided by (used in) financing activities:
	Proceeds from indebtedness		509,313		-		-		509,313
	Repayments of indebtedness		-20,000		-		-		-20,000
	Deferred financing costs		-8,469		-		-		-8,469
	Purchase of shares into treasury		-8,798		-		-		-8,798
	Exercise of stock options		441		-		-		441
	Net cash provided by financing activities		472,487		-		-		472,487
	Net increase in cash and cash equivalents		-78,607		-		-		-78,607
	Cash and cash equivalents at beginning of period		80,128		-		-		80,128
	Cash and cash equivalents at end of period	$	1,521	$	-	$	-	$	1,521
	Supplemental Condensed Consolidating Statement of Cash Flows
	Year Ended December 31, 2011
		Parent
		Company		Guarantor
		Only		Subsidiaries		Eliminations		Consolidated
		(In thousands)
	Net cash provided by operating activities	$	136,245	$	35,007	$	-	$	171,252
	Cash flows provided by (used in) investing activities:
	Decrease in restricted cash		2,466		-		-		2,466
	Property acquisitions		-235,486		-		-		-235,486
	Exploration and development expenditures		-40,996		-35,007		-		-76,003
	Other property and equipment additions		-1,568		-		-		-1,568
	Net cash used in investing activities		-275,584		-35,007		-		-310,591
	Cash flows provided by (used in) financing activities:
	Proceeds from indebtedness		203,794		-		-		203,794
	Deferred financing costs		-6,646		-		-		-6,646
	Purchase of shares into treasury		-11,353		-		-		-11,353
	Exercise of stock options		119		-		-		119
Net cash provided by financing activities		185,914		-		-		185,914
Net increase in cash and cash equivalents		46,575		-		-		46,575
Cash and cash equivalents at beginning of period		33,553		-		-		33,553
Cash and cash equivalents at end of period	$	80,128	$	-	$	-	$	80,128

Organization_and_Summary_of_Si2

Organization and Summary of Significant Accounting Policies (Narrative) (Details) (USD $)

0 Months Ended

In Millions, unless otherwise specified

Jan. 15, 2014

Sep. 26, 2013

15-May-12

Oct. 31, 2012

Oct. 31, 2012

Feb. 14, 2011

Nov. 17, 2011

Apr. 02, 2013

Jan. 17, 2014

Nov. 26, 2013

Oct. 31, 2012

1-May-12

Nexen Acquisition [Member]

West Delta 29 Acquisition [Member]

South Timbalier Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

ASOP Acquisition [Member]

Main Pass Acquisition [Member]

Non-Operated Bay Marchand Field Disposition [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility, Current Borrowing Capacity

'

'

'

'

'

'

'

'

$475

$425

$425

$200

Line Of Credit Facility Increase To Current Borrowing Capacity

'

'

'

'

'

'

'

'

50

'

'

'

Acquired certain interests in producing oil and natural gas assets

70.4

21.8

32.4

550

550

200.7

38.6

'

'

'

'

'

Significant Acquisitions and Disposals, Acquisition Costs or Sale Proceeds

'

$16.50

'

'

'

'

'

$62.80

'

'

'

'

Organization_and_Summary_of_Si3

Organization and Summary of Significant Accounting Policies (Revenue Recognition) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Organization and Summary of Significant Accounting Policies [Abstract]	'	'
Gas Imbalance Asset	$1.90	$0.80
Gas Imbalance liability	$2	$1.70

Organization_and_Summary_of_Si4

Organization and Summary of Significant Accounting Policies (Cash and Cash Equivalents) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Organization and Summary of Significant Accounting Policies [Abstract]	'	'
Overnight Interest-bearing deposits	$7.30	$2.30

Organization_and_Summary_of_Si5

Organization and Summary of Significant Accounting Policies (Share-Based Compensation) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Organization and Summary of Significant Accounting Policies [Abstract]	'	'
Excess Tax Benefit From the Exercise of Stock Options	$0	$0

Organization_and_Summary_of_Si6

Organization and Summary of Significant Accounting Policies (Allowance for Doubtful Accounts) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Organization and Summary of Significant Accounting Policies [Abstract]	'	'
Allowance for Doubtful Accounts Receivable	$0.70	$0.70
Allowance for Doubtful Accounts Receivable, Recoveries	$0.10	$0.10

Organization_and_Summary_of_Si7

Organization and Summary of Significant Accounting Policies (Accrued Expenses) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Organization and Summary of Significant Accounting Policies [Abstract]	'	'
Accrued Exploration Costs, Development Costs and Lease Operating Costs	$107.80	$84.90
Other Accrued Expenses	7.5	16.3
Accrued Interest on Indebtedness	$15.80	$16.20

Acquisitions_and_Dispositions_1

Acquisitions and Dispositions (Narrative) (Details) (USD $)

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Sep. 26, 2013

Dec. 31, 2013

Oct. 31, 2012

Oct. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Oct. 31, 2012

Oct. 25, 2011

Oct. 25, 2012

15-May-12

Mar. 31, 2012

Dec. 31, 2013

Dec. 31, 2012

Feb. 14, 2011

Dec. 31, 2010

Dec. 31, 2012

Dec. 31, 2011

Feb. 14, 2011

Nov. 17, 2011

Nov. 01, 2011

Dec. 31, 2012

Dec. 31, 2011

Apr. 02, 2013

Dec. 31, 2013

Jan. 15, 2014

Sep. 01, 2013

Jan. 17, 2014

Nov. 26, 2013

Oct. 31, 2012

1-May-12

Parent Company [Member]

West Delta 29 Acquisition [Member]

West Delta 29 Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

South Timbalier Acquisition [Member]

South Timbalier Acquisition [Member]

South Timbalier Acquisition [Member]

South Timbalier Acquisition [Member]

ASOP Acquisition [Member]

ASOP Acquisition [Member]

ASOP Acquisition [Member]

ASOP Acquisition [Member]

ASOP Acquisition [Member]

Main Pass Acquisition [Member]

Main Pass Acquisition [Member]

Main Pass Acquisition [Member]

Main Pass Acquisition [Member]

Non-Operated Bay Marchand Field Disposition [Member]

Non-Operated Bay Marchand Field Disposition [Member]

Nexen Acquisition [Member]

Nexen Acquisition [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

MMBoe

MMBoe

Senior Notes Due 2018 [Member]

Senior Notes Due 2018 [Member]

Senior Notes Due 2018 [Member]

MMBoe

MMBoe

2011 Senior Notes [Member]

MMBoe

MMBoe

Business Acquisition [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquired certain interests in producing oil and natural gas assets

'

'

'

$21,800,000

'

$550,000,000

$550,000,000

'

'

'

'

'

$32,400,000

'

'

'

$200,700,000

'

'

'

$200,700,000

$38,600,000

'

'

'

'

'

$70,400,000

'

'

'

'

'

Proved Reserves BOE

'

'

'

'

0.7

'

'

37.2

'

'

'

'

'

1

'

'

'

8.1

'

'

'

'

1.3

'

'

'

'

'

2.6

'

'

'

'

Percentage of Oil Reserves

'

'

'

'

95.00%

'

'

49.00%

'

'

'

'

'

51.00%

'

'

'

84.00%

'

'

'

'

96.00%

'

'

'

'

'

91.00%

'

'

'

'

Percentage of proved developed reserves

'

'

'

'

58.00%

'

'

58.00%

'

'

'

'

'

84.00%

'

'

'

76.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Working interest by acquirer prior to acquisition

'

'

'

'

'

'

'

'

'

'

'

'

60.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Working interest by acquiree prior to acquisition

'

'

'

'

'

'

'

'

'

'

'

'

40.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior Notes, face amount

'

'

'

'

'

'

'

'

'

300,000,000

'

300

'

'

'

'

'

'

'

'

210,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds from offering of Notes

'

'

'

'

'

'

'

'

'

289,500,000

289,500,000

'

'

'

'

'

'

'

'

'

202,000,000

'

'

'

'

'

'

'

'

'

'

'

'

Economic effective date

'

'

'

'

1-Jan-13

'

'

1-Jul-12

'

'

'

'

'

'

1-Apr-12

'

'

'

1-Jan-11

'

'

'

'

1-Nov-11

'

'

1-Jan-13

'

'

'

'

'

'

Purchase Price Adjustments

'

'

'

'

7,100,000

'

'

5,700,000

'

'

'

'

'

'

400,000

'

'

'

3,800,000

'

'

'

'

700,000

'

'

700,000

'

'

'

'

'

'

Incurred fees

'

'

'

'

'

'

'

'

500,000

'

'

'

'

'

'

100,000

'

'

'

500,000

'

'

'

'

100,000

'

'

'

'

'

'

'

'

Buyers Assumption of Certain Associated Liabilities

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

11,300,000

'

'

'

'

'

'

'

Cash consideration from sale of proptery

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

51,500,000

'

'

'

'

'

'

'

Total consideration from sale of property

'

'

'

16,500,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

62,800,000

'

'

'

'

'

'

'

Pre-tax gain on sale of assets

28,681,000

'

28,219,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28,100,000

'

'

'

'

'

'

Line Of Credit Facility Increase To Current Borrowing Capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

Line of Credit Facility, Current Borrowing Capacity

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

475,000,000

425,000,000

425,000,000

200,000,000

Asset Retirement Obligation, Revision of Estimate

$24,586,000

$22,308,000

'

'

'

'

'

$22,100,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Acquisitions_and_Dispositions_2

Acquisitions and Dispositions (Schedule of Carry Amount of Net Assets Sold) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Thousands, unless otherwise specified
Asset retirement obligations	($255,450)	($235,110)	($99,347)
Non-Operated Bay Marchand Field Disposition [Member]	'	'	'
Net property and equipment	35,298	'	'
Asset retirement obligations	-3,959	'	'
Other Liabilities	-7,311	'	'
Net assets sold	$24,028	'	'

Acquisitions_and_Dispositions_3

Acquisitions and Dispositions (Schedule of Assets Acquired and Liabilities Assumed) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
In Thousands, unless otherwise specified
Acquired Indefinite-lived Intangible Assets [Line Items]	'	'	'
Asset retirement obligations	($255,450)	($235,110)	($99,347)
Hilcorp Acquisition [Member]	'	'	'
Acquired Indefinite-lived Intangible Assets [Line Items]	'	'	'
Oil and natural gas properties	698,660	'	'
Asset retirement obligations	-150,959	'	'
Net assets acquired	547,701	'	'
South Timbalier Acquisition [Member]	'	'	'
Acquired Indefinite-lived Intangible Assets [Line Items]	'	'	'
Oil and natural gas properties	33,206	'	'
Asset retirement obligations	-1,878	'	'
Net assets acquired	31,328	'	'
ASOP Acquisition [Member]	'	'	'
Acquired Indefinite-lived Intangible Assets [Line Items]	'	'	'
Oil and natural gas properties	'	221,751	'
Asset retirement obligations	'	-24,858	'
Net assets acquired	'	196,893	'
Main Pass Acquisition [Member]	'	'	'
Acquired Indefinite-lived Intangible Assets [Line Items]	'	'	'
Oil and natural gas properties	'	40,826	'
Asset retirement obligations	'	-2,991	'
Net assets acquired	'	37,835	'
Nexen Acquisition [Member]	'	'	'
Acquired Indefinite-lived Intangible Assets [Line Items]	'	'	'
Oil and natural gas properties	93,932	'	'
Asset retirement obligations	-27,133	'	'
Net assets acquired	66,799	'	'
West Delta 29 Acquisition [Member]	'	'	'
Acquired Indefinite-lived Intangible Assets [Line Items]	'	'	'
Oil and natural gas properties	16,696	'	'
Asset retirement obligations	-1,398	'	'
Net assets acquired	$15,298	'	'

Acquisitions_Schedule_of_Reven

Acquisitions (Schedule of Revenues and Lease Operating Expenses Attributable to the ST 41 Interests, the ASOP Properties and the Main Pass Interests) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Hilcorp Properties Acquisition [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Revenue	$208,241	$37,978	'
Lease operating expenses	74,404	10,982	'
South Timbalier Acquisition [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Revenue	11,189	9,262	'
Lease operating expenses	2,468	1,760	'
ASOP and Main Pass Acquisition [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Revenue	328,070	175,538	125,975
Lease operating expenses	33,978	26,467	17,161
West Delta 29 Acquisition [Member]	'	'	'
Business Acquisition [Line Items]	'	'	'
Revenue	3,011	'	'
Lease operating expenses	$44	'	'

Acquisitions_Schedule_of_Conso

Acquisitions (Schedule of Consolidated Results of Operations) (Details) (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2012
Acquisitions and Dispositions [Abstract]	'
Revenue	$594,510
Net income	$59,324
Basic earnings (loss) per share	$1.51
Diluted earnings (loss) per share	$1.51

Common_Stock_Narrative_Details

Common Stock (Narrative) (Details) (USD $)	0 Months Ended			12 Months Ended
	Jul. 30, 2013	2-May-12	Aug. 29, 2011	Dec. 31, 2013	Apr. 30, 2013	26-May-11
Common Stock [Abstract]	'	'	'	'	'	'
Stock Repurchase Program, Authorized Amount	$80,000,000	$40,000,000	$20,000,000	'	'	'
Treasury Stock, Value, Acquired, Cost Method, Authorized Repurchase Program	'	'	'	29,700,000	'	'
Treasury Stock Shares, Acquired, Authorized Repurchase Program	'	'	'	$1,799,000	'	'
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized	'	'	'	3,574,000	3,574,000	2,474,000
Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant	'	'	'	1,184,322	'	'

Earnings_Per_Share_Basic_and_D

Earnings Per Share (Basic and Diluted Weighted Average Shares Outstanding and Earnings per Share) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Net income	($12,058)	($1,284)	$69,579	$29,037	$24,153	($2,247)	$35,401	$1,503	$85,274	$58,810	$26,611
Net income attributable to participating securities	'	'	'	'	'	'	'	'	-943	-455	-77
Net income attributed to common shares	'	'	'	'	'	'	'	'	84,331	58,355	26,534
Weighted average shares - basic	'	'	'	'	'	'	'	'	38,730	38,885	39,946
Dilutive effect of stock options	'	'	'	'	'	'	'	'	506	149	104
Weighted average shares - diluted	'	'	'	'	'	'	'	'	39,236	39,034	40,050
Basic earnings per share	($0.31)	($0.03)	$1.77	$0.74	$0.62	($0.06)	$0.90	$0.04	$2.18	$1.50	$0.66
Diluted earnings per share	($0.31)	($0.03)	$1.75	$0.73	$0.61	($0.06)	$0.90	$0.04	$2.15	$1.50	$0.66
Parent Company [Member]	'	'	'	'	'	'	'	'	'	'	'
Net income	'	'	'	'	'	'	'	'	$85,274	$58,810	$26,611

Earnings_Per_Share_Number_of_A

Earnings Per Share (Number of Antidilutive Shares Excluded from the Computation of Dilutive Weighted Average Shares) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Earnings per Share [Abstract]	'	'	'
Weighted average shares	273	687	442

Property_and_Equipment_Narrati

Property and Equipment (Narrative) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Impairment of Oil and Gas Properties	$2,937	$8,883	$32,466
Parent Company [Member]	'	'	'
Impairment of Oil and Gas Properties	$2,937	$8,883	$32,532

Property_and_Equipment_Schedul

Property and Equipment (Schedule of Property and Equipment) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Property and Equipment [Abstract]	'	'
Proved oil and natural gas properties	$2,307,891	$1,982,657
Unproved oil and natural gas properties	39,191	36,992
Other	8,137	5,998
Net property and equipment	$2,355,219	$2,025,647

Asset_Retirement_Obligations_N

Asset Retirement Obligations (Narrative) (Details) (USD $)	3 Months Ended	12 Months Ended
In Millions, unless otherwise specified	Sep. 30, 2013	Dec. 31, 2013
Asset Retirement Obligations [Abstract]	'	'
Revision to Asset Retirement Obligation of Non Operated Interests	'	$20.80
Loss on Abandonment Activities of Non Operated Interests	$22.60	$20.80

Asset_Retirement_Obligations_S

Asset Retirement Obligations (Schedule of Changes in Asset Retirement Obligations) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Beginning of period total	$235,110	$99,347	'
Accretion expense	28,299	15,565	15,942
Liabilities assumed in acquisition	23,541	132,109	'
Liabilities incurred	1,187	1,210	'
Revisions	24,586	22,308	'
Liabilities associated with assets sold	-3,965	'	'
Liabilities settled	-53,308	-35,429	'
End of period total	255,450	235,110	99,347
Less: End of period, current portion	51,601	30,179	'
End of period, noncurrent portion	203,849	204,931	'
Parent Company [Member]	'	'	'
Accretion expense	23,196	10,551	9,013
Less: End of period, current portion	51,601	23,982	'
End of period, noncurrent portion	$160,466	$187,790	'

Indebtedness_Narrative_Details

Indebtedness (Narrative) (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2013

Jan. 17, 2014

Nov. 26, 2013

Dec. 31, 2012

Oct. 31, 2012

1-May-12

Feb. 14, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Feb. 14, 2011

Feb. 14, 2011

Oct. 31, 2012

Oct. 31, 2012

Oct. 31, 2012

Oct. 25, 2011

Oct. 25, 2012

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Dec. 31, 2013

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Minimum [Member]

Maximum [Member]

Parent Company [Member]

8.25% Senior Notes [Member]

8.25% Senior Notes [Member]

8.25% Senior Notes [Member]

ASOP Acquisition [Member]

ASOP Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Hilcorp Acquisition [Member]

Base Rate plus margin [Member]

Base Rate plus margin [Member]

LIBOR plus margin [Member]

LIBOR plus margin [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Minimum [Member]

Maximum [Member]

2011 Senior Notes [Member]

Senior Notes Due 2018 [Member]

Senior Notes Due 2018 [Member]

Senior Notes Due 2018 [Member]

Minimum [Member]

Maximum [Member]

Minimum [Member]

Maximum [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Revolving Credit Facility [Member]

Debt Instrument [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior Notes, face amount

'

'

'

'

'

'

'

'

'

'

'

'

'

$510,000,000

'

'

'

$210,000,000

'

'

$300,000,000

'

$300

'

'

'

'

Senior Notes, stated percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

8.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

Maturity date

'

'

'

31-Oct-16

'

'

'

'

'

'

'

'

'

15-Feb-18

'

'

'

'

'

'

'

'

'

'

'

'

'

Net proceeds from offering of Notes

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

202,000,000

'

'

289,500,000

289,500,000

'

'

'

'

'

Loss on early extinguishment of debt

2,377,000

'

'

'

'

'

'

'

'

'

'

'

2,377,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Purchase price of properties

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,700,000

200,700,000

550,000,000

550,000,000

'

'

'

'

'

'

'

Acquired certain interests in producing oil and natural gas assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

200,700,000

200,700,000

550,000,000

550,000,000

'

'

'

'

'

'

'

Line of Credit Facility, Maximum Borrowing Capacity

'

'

'

750,000,000

'

'

'

750,000,000

'

250,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Borrowing base under the expanded credit facility

'

'

'

'

475,000,000

425,000,000

'

425,000,000

200,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line Of Credit Facility Increase To Current Borrowing Capacity

'

'

'

'

50,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt Instrument, Basis Spread on Variable Rate

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0.75%

1.75%

1.75%

2.75%

Amounts drawn under Senior Credit Facility

'

'

'

130,000,000

'

'

195,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Senior credit facility condition

'

'

'

'Our obligations under our Senior Credit Facility, as well as any hedging contracts and treasury management agreements with the lenders or affiliates of lenders, are secured by substantially all of our assets, including a) mortgages on at least 80% of the total value of our oil and gas properties evaluated in the most recently completed reserve report, after giving effect to exploration and production activities, acquisitions and dispositions, and b) the stock of certain wholly-owned subsidiaries.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Debt redemption notice

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'30 days

'60 days

'

'

'

'

'

'

'

'

'

'

'

Redeemable debt, redemption percentage of principal prior to 2014

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

35.00%

'

'

'

'

'

'

'

'

'

'

'

Early debt redemption notice

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'30 days

'60 days

'

'

'

'

'

'

'

'

'

'

'

Redeemable debt, redemption percentage prior to 2014

'

'

'

'

'

'

'

'

'

'

'

'

'

108.25%

'

'

'

'

'

'

'

'

'

'

'

'

'

Redeemable debt, percentage of principal outstanding prior to 2014

'

'

'

'

'

'

'

'

'

'

'

'

'

'

65.00%

'

'

'

'

'

'

'

'

'

'

'

'

Redeemable debt, redemption period after equity offering

'

'

'

'

'

'

'

'

'

'

'

'

'

'90 days

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum debt owned for repurchase right

'

'

'

'

'

'

'

'

'

'

'

'

'

2,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum debt owned for repurchase right, additional increments

'

'

'

'

'

'

'

'

'

'

'

'

'

1,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchase right, redemption percentage

'

'

'

'

'

'

'

'

'

'

'

'

'

101.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchase period after sale of assets

'

'

'

'

'

'

'

'

'

'

'

'

'

'360 days

'

'

'

'

'

'

'

'

'

'

'

'

'

Minimum proceeds from sale of assets that must be applied to senior notes

'

'

'

'

'

'

'

'

'

'

'

'

'

20,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Repurchase Percentage of Senior Notes

'

'

'

'

'

'

'

'

'

'

'

'

'

100.00%

'

'

'

'

'

'

'

'

'

'

'

'

'

Commitment fees

'

'

'

'

'

'

'

'

'

'

0.38%

0.50%

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Line of Credit Facility Maximum Letter of Credit Capacity

'

'

'

20,000,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Covenant certification requirements

'

'

'

'Our Senior Credit Facility contains customary covenants, default provisions and collateral requirements. As described in the agreement underlying our Senior Credit Facility, we must maintain, for each period for which a covenant certification is required, (a)B a minimum current ratio (as defined in the agreement for our Senior Credit Facility) of 1.0 to 1.0 and (b)B a maximum total debt to EBITDAX ratio of 3.5 to 1.0. We are also required to maintain a commodities hedging program that is in compliance with the requirements set forth in our Senior Credit Facility. Our Senior Credit Facility also places restrictions on the maximum estimated future production volumes that can be subject to commodity derivative instruments.

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Effective interest rate

'

'

'

'

'

'

'

'

'

'

'

'

'

9.10%

'

'

'

'

'

'

'

'

'

'

'

'

'

Accrued interest included in purchase price

'

$15,800,000

$16,200,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$4,800,000

'

'

'

'

Indebtedness_Schedule_of_Indeb

Indebtedness (Schedule of Indebtedness) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
8.25% senior notes, face amount of $510.0 million, interest rate of 8.25% payable semi-annually, in arrears on February 15 and August 15 of each year, maturity date February 15, 2018	$497,355,000	$494,911,000
Senior Credit Facility, interest rate based on base rate or LIBOR plus a floating spread, maturity date October 31, 2016	130,000,000	195,000,000
Total indebtedness	627,355,000	689,911,000
Current portion of indebtedness	0	0
Noncurrent portion of indebtedness	627,355,000	689,911,000
8.25% Senior Notes [Member]	'	'
Noncurrent portion of indebtedness	497,355,000	494,911,000
Senior Notes, face amount	510,000,000	'
Senior Notes, stated percentage	8.25%	'
Maturity date	15-Feb-18	'
Parent Company [Member]	'	'
Noncurrent portion of indebtedness	627,355,000	689,911,000
Revolving Credit Facility [Member]	'	'
Noncurrent portion of indebtedness	$130,000,000	$195,000,000
Maturity date	31-Oct-16	'

Indebtedness_Schedule_of_Redee

Indebtedness (Schedule of Redeemable Debt) (Details)	12 Months Ended
	Dec. 31, 2013
Indebtedness [Abstract]	'
2015	104.13%
2016	102.06%
2017 and thereafter	100.00%

Concentrations_Narrative_Detai

Concentrations (Narrative) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Customer 1 Concentration Risk	'	'	'
Percentage of total oil and natural gas revenues	63.00%	45.00%	51.00%
Customer 2 Concentration Risk	'	'	'
Percentage of total oil and natural gas revenues	24.00%	31.00%	17.00%
Customer 3 Concentration Risk	'	'	'
Percentage of total oil and natural gas revenues	6.00%	11.00%	12.00%

Derivative_Instruments_and_Hed1

Derivative Instruments and Hedging Activities (Schedule of Derivative Instruments Outstanding) (Details) (Fixed Price Swaps [Member])	Dec. 31, 2013
January 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	16,350
Volume	506,850
Average Swap Price	93.11
February 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	16,350
Volume	457,800
Average Swap Price	93.11
March 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	16,350
Volume	506,850
Average Swap Price	93.11
April 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	15,350
Volume	460,500
Average Swap Price	94.27
May 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	15,350
Volume	475,850
Average Swap Price	94.27
June 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	15,350
Volume	460,500
Average Swap Price	94.27
July 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	14,350
Volume	444,850
Average Swap Price	93.56
August 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	8,750
Volume	271,250
Average Swap Price	94.28
September 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	8,750
Volume	262,500
Average Swap Price	94.28
October 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	8,750
Volume	271,250
Average Swap Price	94.28
November 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	8,750
Volume	262,500
Average Swap Price	94.28
December 2014 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	11,700
Volume	362,700
Average Swap Price	91.9
2014 Totals [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	12,996
Volume	4,743,400
Average Swap Price	93.67
January 2014 To December 2014 [Member] | Gas Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	5,000
Volume	1,825,000
Average Swap Price	4.01
January 2015 To December 2015 [Member] | Oil Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	1,500
Volume	547,500
Average Swap Price	97.7
January 2015 To December 2015 [Member] | Gas Contract [Member]	'
Derivative [Line Items]	'
Daily Average Volume	4,300
Volume	1,569,500
Average Swap Price	4.31

Derivative_Instruments_and_Hed2

Derivative Instruments and Hedging Activities (Components of Gain (Loss) on Derivative Instruments) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Change in fair market value	($20,884)	($9,491)	$11,475
Loss on settlement	-11,477	-3,814	-17,345
Total loss on derivative instruments	-32,361	-13,305	-5,870
Parent Company [Member]	'	'	'
Total loss on derivative instruments	($32,361)	($13,305)	($5,870)

Fair_Value_Measurements_Schedu

Fair Value Measurements (Schedule of Fair Value Measurements of Assets and Liabilities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Current	$501	$3,302
Noncurrent	238	211
Total gross fair value	739	3,513
Less: counterparty set-off	-739	-3,513
Current	29,636	10,026
Noncurrent	2,136	3,637
Total gross fair value	31,772	13,663
Less: counterparty set-off	-739	-3,513
Total net fair value	31,033	10,150
Parent Company [Member]	'	'
Current	501	3,302
Noncurrent	238	211
Current	29,636	10,026
Noncurrent	$2,136	$3,637

Fair_Value_Measurements_Schedu1

Fair Value Measurements (Schedule of Carrying Values and Estimated Fair Values of Debt Instruments) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
Debt Instrument [Line Items]	'	'
Carrying Value	$627,355,000	$689,911,000
Estimated fair value	676,338,000	719,600,000
Parent Company [Member]	'	'
Debt Instrument [Line Items]	'	'
Carrying Value	627,355,000	689,911,000
8.25% Senior Notes [Member]	'	'
Debt Instrument [Line Items]	'	'
Senior Notes, stated percentage	8.25%	'
Face amount of 8.25% Notes	510,000,000	'
Carrying Value	497,355,000	494,911,000
Estimated fair value	546,338,000	524,600,000
Revolving Credit Facility [Member]	'	'
Debt Instrument [Line Items]	'	'
Carrying Value	130,000,000	195,000,000
Estimated fair value	$130,000,000	$195,000,000

Income_Taxes_Narrative_Details

Income Taxes (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Sep. 25, 2009
Income Taxes [Abstract]	'	'
Reduction in net operating loss carryforward	'	$97
Operating Loss Carryforwards	167	'
Unused annual limited net operating loss carryforward	'	137
Annual limitation net operating loss carryforward	21	'
Net operating loss carryforward available current year	121	'
Net operating loss carryforward Share Based Compensation	$3.80	'
Uncertain tax positions	'no	'

Income_Taxes_Schedule_of_Incom

Income Taxes (Schedule of Income Tax Benefit (Expense) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Deferred Federal Income Tax Expense (Benefit)	($47,723)	($28,719)	($14,468)
Deferred State Income Tax Expense (Benefit)	-1,964	-1,181	-354
Deferred Income Tax Expense (Benefit), Total	-49,687	-29,900	-14,822
Federal Income Tax Expense (Benefit)	-47,723	-28,719	-14,468
State Income Tax Expense (Benefit)	-1,964	-1,181	-354
Total provision for income taxes	-49,687	-29,900	-14,822
Parent Company [Member]	'	'	'
Deferred Income Tax Expense (Benefit), Total	($42,982)	($20,270)	($6,172)

Income_Taxes_Reconciliation_of

Income Taxes (Reconciliation of Effective Income Tax Rate) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Income Taxes [Abstract]	'	'	'
Expected Statutory Federal Income Tax Rate	35.00%	35.00%	35.00%
State Taxes	1.40%	1.40%	2.30%
State Tax Rate Change	'	2.70%	1.70%
Statutory Depletion	0.30%	0.40%	1.00%
Other	0.70%	0.40%	1.20%
Effective Income Tax Rate	36.80%	33.70%	35.80%

Income_Taxes_Schedule_of_Tax_E

Income Taxes (Schedule of Tax Effect of Temporary Differences) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Federal and state net operating loss carryforwards	$62,015	$62,130
Fair Value of Commodity Derivative Instruments	11,578	3,912
Restricted stock awards and options	3,843	2,313
Percentage depletion carryforward	5,003	4,575
Accruals and Other	1,130	2,613
Deferred Tax Assets	83,569	75,543
Property, plant and equipment, principally due to differences in depreciation	193,191	136,016
Deferred Tax Liabilities, Derivatives	182	214
Prepaid Assets	1,482	1,778
Deferred Tax Liabilities, Other	2,577	1,907
Deferred tax liabilities	197,432	139,915
Total deferred tax Liabilities	113,863	64,372
Deferred tax asset	8,949	3,322
Deferred tax liabilities	122,812	67,694
Parent Company [Member]	'	'
Deferred tax asset	8,949	3,322
Deferred tax liabilities	$106,910	$59,571

Employee_Benefit_Plans_Narrati

Employee Benefit Plans (Narrative) (Details) (USD $)

12 Months Ended

12 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

0 Months Ended

12 Months Ended

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 30, 2013

26-May-11

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Apr. 30, 2013

26-May-11

Dec. 31, 2013

Dec. 31, 2012

Dec. 31, 2011

Dec. 31, 2013

Dec. 31, 2013

Apr. 30, 2013

16-May-12

19-May-11

Dec. 31, 2013

Apr. 30, 2013

Dec. 31, 2013

Sep. 30, 2013

Sep. 30, 2009

Dec. 31, 2013

Employee Stock Option [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

401(K) Plans [Member]

Director [Member]

Director [Member]

Director [Member]

Director [Member]

Director [Member]

Director [Member]

Chief Executive Officer [Member]

Chief Executive Officer [Member]

Chief Executive Officer [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Restricted Stock [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

2009 Long Term Incentive Plan [Member]

Restricted Stock [Member]

Restricted Stock [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Employee Stock Option [Member]

Restricted Stock, Granted

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

264,383

'

15,305

31,095

31,405

'

'

'

68,116

'

'

Allocated Share-based Compensation Expense

'

'

'

'

'

$3,426,000

$2,621,000

$1,497,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$100,000

Modification of September 30, 2009 employment agreement

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'On May 1, 2012, the Compensation Committee modified the terms of the Option Agreement to extend the expiration of the stock options granted thereunder to September 30, 2019, resulting in additional compensation expense of $0.1 million in the year ended December 31, 2012. Upon a change in control as defined in the 2009 LTIP, all stock options under the Option Agreement remain exercisable for a period of not less than 30 months following the change in control. In November 2009, the Compensation Committee approved a compensation program for each of our non-employee directors which provides for the annual grant of a stock award with a market value of $100,000 (as measured on the date of grant and prorated from the date of grant, as applicable). Pursuant to the terms of the program,

Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Authorized

3,574,000

'

'

3,574,000

2,474,000

'

'

'

'

'

'

3,574,000

2,474,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Number of Shares Available for Grant

1,184,322

'

'

'

'

'

'

'

1,184,322

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Share-based Compensation Arrangement by Share-based Payment Award, Terms of Award

'

'

'

'

'

'

'

'

'

'

'

'

'

'10 Years

'

'

'

'

'

'

'

'

'one-half of each stock award vests immediately on the date of grant, and the remaining one-half vests immediately prior to the next annual meeting of stockholders held after the grant date.

'

'

'The terms of the Option Agreement provided for an exercise price equal to $10.00 per share. The closing price of our common stock on the NYSE on SeptemberB 30, 2009 was $7.46 per share. The option vested ratably on a monthly basis over a 36-month period from the date of grant; however, the vesting for the first six months of the vesting period (the "Initial Period") was deferred until the end of the Initial Period and any remaining unvested portion vested ratably on a monthly basis over the remainder of the 36-month vesting period, subject to the executive remaining continuously employed. Under the original terms of the award agreement, vested stock options under the Option Agreement were to expire 30 months following the applicable vesting date of such stock options.

'

Share-based Compensation Arrangement by Share-based Payment Award, Award Vesting Period

'

'

'

'

'

'

'

'

'

'

'

'

'

'3 years

'

'

'

'

'

'

'

'

'

'

'

'

'

Weighted-average grant-date fair value of stock options granted

'

'

'

'

'

'

'

'

'

'

'

'

'

$14.50

$8.84

$7.97

'

'

'

'

'

'

'

'

'

'

'

Weighted-average grant-date fair value nonvested share awards granted

'

'

'

'

'

'

'

'

$26.60

$16.33

$15.34

'

'

'

'

'

$26.60

'

'

'

'

'

'

'

'

'

'

Total fair value of nonvested share awards vested during period

'

'

'

'

'

'

'

'

4,100,000

2,000,000

600,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Aggregate instrinsic value of stock options exercised during period

'

'

'

'

'

'

'

'

'

'

'

'

'

'

500,000

100,000

'

'

'

'

'

'

'

'

'

'

'

Unrecognized compensation expense

'

'

'

'

'

'

'

'

'

'

'

'

'

5,600,000

'

'

6,100,000

'

'

'

'

'

'

'

'

'

'

Weighted average recognition period

'

'

'

'

'

'

'

'

'

'

'

'

'

'2 years

'

'

'2 years

'

'

'

'

'

'

'

'

'

'

Deferred Compensation Arrangement with Individual, Description

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'Pursuant to elections made by two directors applicable to certain of these awards, the receipt of such awards totaling 39,009 shares is deferred until such directors cease to serve on our Board of Directors. During the year ended December 31, 2013, one of our non-employee directors resigned, forfeiting 1,531 shares awarded under this program.

'

'

'

Deferred Compensation Arrangement with Individual, Shares Issued

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

39,009

'

'

'

'

'

Deferred Compensation Arrangement with Individual, Shares Forfeited

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,531

'

'

'

'

'

Description of 401(K) Plan

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'We also have a 401(k) Plan that covers all employees. We match 100% of each individual participant's contribution not to exceed 6% of the participant's compensation. Our matching contributions are made in cash.

'

'

'

'

'

'

'

'

'

Defined Contribution Plan, Employer Matching Contribution, Percent of Employees' Gross Pay

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

6.00%

'

'

'

'

'

'

'

'

'

Defined Contribution Plan, Employer Discretionary Contribution Amount

$900,000

$800,000

$700,000

'

'

'

'

'

'

'

'

'

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'

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'

'

'

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'

Employee_Benefit_Plans_Stock_O

Employee Benefit Plans (Stock Option Activity) (Details) (Employee Stock Option [Member], USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2013
Aggregate Intrinsic Value, Outstanding on December 31, 2013	$15,970
Aggregate Intrinsic Value, Exercisable on December 31, 2013	$10,624
2009 Long Term Incentive Plan [Member]	'
Options, Outstanding on December 31, 2012	1,192,158
Options, Granted	369,137
Options, Exercised	-108,122
Options, Outstanding on December 31. 2013	1,453,173
Options, Exercisable on December 31, 2013	705,814
Weighted Average Exercise Price per Share, Outstanding on December 31,2012	$14.30
Weighted Average Exercise Price per Share, Granted	$27.48
Weighted Average Exercise Price per Share, Exercised	$12.80
Weighted Average Exercise Price per Share, Outstanding on December 31, 2013	$17.76
Weighted Average Remaining Contractual Terms, Exercisable on December 31, 2013	$13.45
Weighted Average Remaining Contractual Terms, Outstanding on December 31, 2013	'7 years 9 months 18 days
Weighted Average Remaining Contractual Terms, Exercisable on December 31, 2013	'6 years 10 months 24 days

Employee_Benefit_Plans_Fair_Va

Employee Benefit Plans (Fair Value Stock Option Award) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Employee Benefit Plan [Abstract]	'	'	'
Risk-free interest rate	1.40%	1.00%	1.90%
Expected life (years)	'6 years	'6 years	'6 years
Expected Volatility	56.00%	56.00%	53.00%
Dividend yield	0.00%	0.00%	0.00%

Employee_Benefit_Plans_NonVest

Employee Benefit Plans (Non-Vested Share Awards Activity) (Details) (2009 Long Term Incentive Plan [Member], USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Weighted-average grant-date fair value nonvested share awards granted	$26.60	$16.33	$15.34
Restricted Stock [Member]	'	'	'
Non-vested restricted share awards outstanding at December 31, 2012	326,952	'	'
Restricted Stock, Granted	264,383	'	'
Restricted Stock, Vested	-145,309	'	'
Restricted Stock, Forfeited	-1,531	'	'
Non-vested restricted share awards outstanding at December 31, 2013	444,495	'	'
Weighted Average Grant Date Fair Value, Non-vested restricted share awards outstanding at December 31, 2012	$15.98	'	'
Weighted-average grant-date fair value nonvested share awards granted	$26.60	'	'
Weighted Average Grant Date Fair Value, Vested	$16.77	'	'
Weighted Average Grant Date Fair Value, Forfeited	$32.67	'	'
Weighted Average Grant Date Fair Value, Non-vested restricted share awards outstanding at December 31, 2013	$21.98	'	'

Employee_Benefit_Plans_ShareBa

Employee Benefit Plans (Share-Based Compensation Expense and Related Tax Benefits) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Deferred Income Tax Benefit	$2,704	$1,726	$936
Employee Stock Option [Member]	'	'	'
Compensation expense	3,426	2,621	1,497
Non-vested share award [Member]	'	'	'
Compensation expense	$3,918	$2,096	$1,012

Commitments_and_Contingencies_1

Commitments and Contingencies (Narrative) (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2009	Dec. 31, 2008
	bbl
Commitments and Contingencies [Abstract]	'	'	'	'	'
Operating Leases, Rent Expense	$7.50	$2.40	$1.80	'	'
Long-term Purchase Commitment, Amount	40.5	'	'	'	'
Long-term Purchase Commitment, Time Period	'four	'	'	'	'
Restricted escrow funds' trust	'	'	'	15	'
Misallocated oil volumes	74,000	'	'	'	'
Value of misallocated oil volumes	6.9	'	'	'	'
Restricted escrow trust funds including accumulated interest	'	'	'	'	16.7
Escrow Deposit	$6	'	'	'	'

Commitments_and_Contingencies_2

Commitments and Contingencies (Schedule of Future Minimum Commitments) (Details) (USD $)	Dec. 31, 2013
In Thousands, unless otherwise specified
Commitments and Contingencies [Abstract]	'
2014	$1,073
2015	1,222
2016	1,239
2017	661
2018	542
Thereafter	406
Future minimum commitments	$5,143

Interim_Financial_Information_2

Interim Financial Information (Unaudited) (Details) (USD $)	3 Months Ended								12 Months Ended
	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Revenues	$142,610,000	$183,992,000	$184,087,000	$182,349,000	$138,899,000	$86,668,000	$99,270,000	$98,796,000	$693,038,000	$423,633,000	$348,327,000
Costs and Expenses	122,077,000	143,178,000	98,535,000	109,657,000	86,235,000	67,379,000	68,071,000	71,501,000	473,447,000	293,186,000	281,201,000
Income from operations	20,533,000	40,814,000	85,552,000	72,692,000	52,664,000	19,289,000	31,199,000	27,295,000	219,591,000	130,447,000	67,126,000
Net income	-12,058,000	-1,284,000	69,579,000	29,037,000	24,153,000	-2,247,000	35,401,000	1,503,000	85,274,000	58,810,000	26,611,000
Basic earnings per share	($0.31)	($0.03)	$1.77	$0.74	$0.62	($0.06)	$0.90	$0.04	$2.18	$1.50	$0.66
Diluted earnings (loss) per share	($0.31)	($0.03)	$1.75	$0.73	$0.61	($0.06)	$0.90	$0.04	$2.15	$1.50	$0.66
Gains Losses On Extinguishment Of Debt	'	'	'	'	'	'	'	'	'	'	-2,377,000
Loss on Abandonment Activities of Non Operated Interests	'	22,600,000	'	'	'	'	'	'	20,800,000	'	'
Parent Company [Member]	'	'	'	'	'	'	'	'	'	'	'
Revenues	'	'	'	'	'	'	'	'	607,432,000	333,901,000	260,574,000
Costs and Expenses	'	'	'	'	'	'	'	'	406,052,000	232,029,000	217,630,000
Income from operations	'	'	'	'	'	'	'	'	201,380,000	101,872,000	42,944,000
Net income	'	'	'	'	'	'	'	'	85,274,000	58,810,000	26,611,000
Gains Losses On Extinguishment Of Debt	'	'	'	'	'	'	'	'	'	'	($2,377,000)

Supplementary_Oil_and_Natural_2

Supplementary Oil and Natural Gas Disclosures (Unaudited) (Narrative) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Supplementary Oil and Natural Gas Disclosures (Unaudited) [Abstract]	'	'
Significant Changes in Reserves	'Includes extensions and discoveries across 12 different fields, primarily within our Ship Shoal and West Delta areas. The Ship Shoal 208 field accounts for 46% of our total extensions and discoveries with 4,973 Mboe, consisting of 3,967 Mbbls of oil and 6,035 Mmcf of produced gas. The remaining 11 locations account for up to 16% each of total extensions and discoveries with reserves ranging from 10 Mboe to 1.6 Mmboe.	'Includes extensions and discoveries across 6 different fields, primarily within our West Delta and Ship Shoal areas. These extensions and discoveries added volumes ranging from 18 Mboe to 1.2 Mmboe each, with three exceeding 1.0 Mmboe each.

Supplementary_Oil_and_Natural_3

Supplementary Oil and Natural Gas Disclosures (Unaudited) (Schedule of Estimated Net Proved Reserves, Changes in Estimated Net Proved Reserves and Proved Developed Reserves) (Detail)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
	MMBbls	MMBbls	MMBbls
Crude Oil (Mbbls) [Member]	'	'	'
Estimated Proved Reserves, Beginning Balance	47,442	27,301	17,223
Acquisitions	366	16,430	7,987
Sales	-1,415	'	'
Extensions, discoveries and other additions	7,354	6,388	2,266
Revisions	3,952	1,128	2,778
Production	-6,182	-3,805	-2,953
Estimated Proved Reserves, Ending Balance	51,517	47,442	27,301
Proved Developed Reserves (Volume)	39,439	37,908	24,791
Proved Undeveloped Reserve (Volume)	12,078	9,534	2,510
Gas (Mmcf) [Member]	'	'	'
Estimated Proved Reserves, Beginning Balance	179,939	58,785	61,251
Acquisitions	209	115,876	8,640
Sales	-916	'	'
Extensions, discoveries and other additions	20,247	10,241	4,664
Revisions	-10,128	4,033	-6,678
Production	-15,767	-8,996	-9,092
Estimated Proved Reserves, Ending Balance	173,584	179,939	58,785
Proved Developed Reserves (Volume)	107,687	120,687	52,739
Proved Undeveloped Reserve (Volume)	65,897	59,252	6,046
Oil Equivalent (Mboe) [Member]	'	'	'
Estimated Proved Reserves, Beginning Balance	77,432	37,099	27,431
Acquisitions	401	35,742	9,427
Sales	-1,568	'	'
Extensions, discoveries and other additions	10,729	8,095	3,043
Revisions	2,264	1,800	1,666
Production	-8,810	-5,304	-4,468
Estimated Proved Reserves, Ending Balance	80,448	77,432	37,099
Proved Developed Reserves (Volume)	57,387	58,022	33,581
Proved Undeveloped Reserve (Volume)	23,061	19,409	3,518

Supplementary_Oil_and_Natural_4

Supplementary Oil and Natural Gas Disclosures (Unaudited) (Capitalized Cost for Oil and Natural Gas Producing Activities) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012
In Thousands, unless otherwise specified
Supplementary Oil and Natural Gas Disclosures (Unaudited) [Abstract]	'	'
Capitalized Costs, Proved properties	$2,307,891	$1,982,657
Capitalized Costs, Unproved properties	39,191	36,992
Capitalized costs, accumulated depreciation, depletion and amortization	-614,068	-424,520
Net capitalized costs	$1,733,014	$1,595,129

Supplementary_Oil_and_Natural_5

Supplementary Oil and Natural Gas Disclosures (Unaudited) (Costs Incurred Associated with Finding, Acquiring and Developing Proved Oil and Natural Gas Reserves) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Acquistions-Proved	$46,047,000	$706,322,000	$261,812,000
Acquisition - Unproved	2,200,000	7,496,000	14,000
Exploration	46,100,000	43,338,000	17,129,000
Development	303,245,000	180,938,000	83,577,000
Costs incurred	397,592,000	938,094,000	362,532,000
Liabilities assumed in acquisition	23,541,000	132,109,000	'
Asset retirement obligations incurred	1,200,000	1,200,000	200,000
Hilcorp Acquisition [Member]	'	'	'
Purchase Price Adjustments Associated with Acquiring Proved Reserves	29,700,000	'	'
West Delta 29 Acquisition [Member]	'	'	'
Purchase Price Adjustments Associated with Acquiring Proved Reserves	$16,700,000	'	'

Supplementary_Oil_and_Natural_6

Supplementary Oil and Natural Gas Disclosures (Unaudited) Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Natural Gas Reserves) (Details) (USD $)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Supplementary Oil and Natural Gas Disclosures (Unaudited) [Abstract]	'	'
Future cash inflows	$5,937,536,000	$5,401,290,000
Future production costs	-1,957,868,000	-1,823,303,000
Future development costs	-1,085,440,000	-936,580,000
Future income taxes	-641,536,000	-537,546,000
Future net cash flows after income taxes	2,252,692,000	2,103,861,000
10% annual discount for estimated timing of cash flows	-603,614,000	-529,579,000
Standardized measure of discounted future net cash flows	1,649,078,000	1,574,282,000
Future Abandonment and Decommissioning Costs	569,900,000	466,900,000
Future Salvage Values	$25,800,000	$32,600,000

Supplementary_Oil_and_Natural_7

Supplementary Oil and Natural Gas Disclosures (Unaudited) (Schedule of Changes in Standardized Measure of Discounted Future Net Cash Flows Applicable to Proved Oil and Natural Gas Reserves) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012
Supplementary Oil and Natural Gas Disclosures (Unaudited) [Abstract]	'	'
Beginning of the period	$1,574,282	$876,169
Sales and transfers of oil and natural gas produced, net of productuin costs	-513,906	-317,059
Net changes in prices and prooduction costs	96,751	-244,824
Purchase of mineral in place	26,708	797,085
Sales of minerals in place	-64,539	'
Extensions, discoveries and improved recoveries, net of future production costs	363,493	452,258
Revision of quantity estimates	84,490	55,133
Previously estimated development costs incurred during the period	33,920	39,321
Changes in estimated future development costs	18,229	746
Changes in production rates (timing) and other	-113,022	-14,157
Accretion of discount	197,927	110,070
Net change in income taxes	-55,255	-180,460
Net increase (decrease)	74,796	698,113
End of period	$1,649,078	$1,574,282

Supplementary_Oil_and_Natural_8

Supplementary Oil and Natural Gas Disclosures (Unaudited) (Oil and Natural Gas Computed Price Used in Computation of Discounted Future Net Cash Flows) (Details)	12 Months Ended
	Dec. 31, 2013	Dec. 31, 2012
Supplementary Oil and Natural Gas Disclosures (Unaudited) [Abstract]	'	'
Computed Price Per Barrel of Oil	105.3	105.13
Computed prices Per mcf for Natural Gas	3.73	2.92

Supplemental_Condensed_Consoli2

Supplemental Condensed Consolidating Financial Information (Supplemental Condensed Consolidating Balance Sheet) (Details) (USD $)	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2010
In Thousands, unless otherwise specified
Cash and cash equivalents	$8,812	$1,521	$80,128	$33,553
Trade accounts receivable - net	70,707	67,991	'	'
Fair value of commodity derivative instruments	501	3,302	'	'
Deferred tax asset	8,949	3,322	'	'
Prepaid expenses	6,868	9,873	'	'
Total current assets	95,837	86,009	'	'
Property and equipment	2,355,219	2,025,647	'	'
Less accumulated depreciation, depletion, amortization and impairments	-618,788	-427,580	'	'
Net property and equipment	1,736,431	1,598,067	'	'
Deposit for Nexen Acquisition	7,040	'	'	'
Restricted cash	6,023	6,023	'	'
Fair value of commodity derivative instruments	238	211	'	'
Deferred financing costs	10,106	12,386	'	'
Other assets	2,156	2,931	'	'
Total Assets	1,857,831	1,705,627	'	'
Accounts payable	59,431	34,772	'	'
Accrued expenses	131,125	117,372	'	'
Asset retirement obligations	51,601	30,179	'	'
Fair value of commodity derivative instruments	29,636	10,026	'	'
Total current liabilities	271,793	192,349	'	'
Long-term debt	627,355	689,911	'	'
Asset retirement obligations	203,849	204,931	'	'
Deferred tax liabilities	122,812	67,694	'	'
Fair value of commodity derivative instruments	2,136	3,637	'	'
Other	673	1,132	'	'
Total liabilities	1,228,618	1,159,654	'	'
Preferred stock	'	'	'	'
Common stock	41	40	'	'
Additional paid-in capital	519,114	510,469	'	'
Treasury stock, at cost	-31,157	-20,477	'	'
Retained earnings	141,215	55,941	'	'
Total stockholders' equity	629,213	545,973	491,045	473,116
Total liabilities and stockholders' equity	1,857,831	1,705,627	'	'
Parent Company [Member]	'	'	'	'
Cash and cash equivalents	8,812	1,521	80,128	33,553
Trade accounts receivable - net	70,520	66,994	'	'
Intercompany receivable	39,085	55,575	'	'
Fair value of commodity derivative instruments	501	3,302	'	'
Deferred tax asset	8,949	3,322	'	'
Prepaid expenses	6,868	9,873	'	'
Total current assets	134,735	140,587	'	'
Property and equipment	2,041,689	1,754,294	'	'
Less accumulated depreciation, depletion, amortization and impairments	-526,736	-353,526	'	'
Net property and equipment	1,514,953	1,400,768	'	'
Investment in affiliates	122,697	111,191	'	'
Deposit for Nexen Acquisition	7,040	'	'	'
Restricted cash	6,023	6,023	'	'
Fair value of commodity derivative instruments	238	211	'	'
Deferred financing costs	10,106	12,386	'	'
Other assets	2,067	2,841	'	'
Total Assets	1,797,859	1,674,007	'	'
Accounts payable	58,758	34,740	'	'
Accrued expenses	131,111	117,245	'	'
Asset retirement obligations	51,601	23,982	'	'
Fair value of commodity derivative instruments	29,636	10,026	'	'
Total current liabilities	271,106	185,993	'	'
Long-term debt	627,355	689,911	'	'
Asset retirement obligations	160,466	187,790	'	'
Deferred tax liabilities	106,910	59,571	'	'
Fair value of commodity derivative instruments	2,136	3,637	'	'
Other	673	1,132	'	'
Total liabilities	1,168,646	1,128,034	'	'
Common stock	41	40	'	'
Additional paid-in capital	519,114	510,469	'	'
Treasury stock, at cost	-31,157	-20,477	'	'
Retained earnings	141,215	55,941	'	'
Total stockholders' equity	629,213	545,973	'	'
Total liabilities and stockholders' equity	1,797,859	1,674,007	'	'
Guarantor Subsidiaries [Member]	'	'	'	'
Trade accounts receivable - net	187	997	'	'
Total current assets	187	997	'	'
Property and equipment	313,530	271,353	'	'
Less accumulated depreciation, depletion, amortization and impairments	-92,052	-74,054	'	'
Net property and equipment	221,478	197,299	'	'
Other assets	89	90	'	'
Total Assets	221,754	198,386	'	'
Accounts payable	673	32	'	'
Intercompany payable	39,085	55,575	'	'
Accrued expenses	14	127	'	'
Asset retirement obligations	'	6,197	'	'
Total current liabilities	39,772	61,931	'	'
Asset retirement obligations	43,383	17,141	'	'
Deferred tax liabilities	15,902	8,123	'	'
Total liabilities	99,057	87,195	'	'
Additional paid-in capital	85,479	85,479	'	'
Retained earnings	37,218	25,712	'	'
Total stockholders' equity	122,697	111,191	'	'
Total liabilities and stockholders' equity	221,754	198,386	'	'
Consolidation, Eliminations [Member]	'	'	'	'
Intercompany receivable	-39,085	-55,575	'	'
Total current assets	-39,085	-55,575	'	'
Investment in affiliates	-122,697	-111,191	'	'
Total Assets	-161,782	-166,766	'	'
Intercompany payable	-39,085	-55,575	'	'
Total current liabilities	-39,085	-55,575	'	'
Total liabilities	-39,085	-55,575	'	'
Additional paid-in capital	-85,479	-85,479	'	'
Retained earnings	-37,218	-25,712	'	'
Total stockholders' equity	-122,697	-111,191	'	'
Total liabilities and stockholders' equity	($161,782)	($166,766)	'	'

Supplemental_Condensed_Consoli3

Supplemental Condensed Consolidating Financial Information (Supplemental Condensed Consolidating Statement of Operations) (Details) (USD $)	3 Months Ended								12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Sep. 30, 2013	Jun. 30, 2013	Mar. 31, 2013	Dec. 31, 2012	Sep. 30, 2012	Jun. 30, 2012	Mar. 31, 2012	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Oil and natural gas	'	'	'	'	'	'	'	'	$688,743	$422,529	$348,207
Other	'	'	'	'	'	'	'	'	4,295	1,104	120
Total Revenue	142,610	183,992	184,087	182,349	138,899	86,668	99,270	98,796	693,038	423,633	348,327
Lease operating	'	'	'	'	'	'	'	'	165,841	94,850	70,281
Transportation	'	'	'	'	'	'	'	'	3,568	615	779
Exploration expenditures and dry hole costs	'	'	'	'	'	'	'	'	26,555	18,799	14,268
Impairments	'	'	'	'	'	'	'	'	2,937	8,883	32,466
Depreciation, depletion and amortization	'	'	'	'	'	'	'	'	200,359	113,581	104,624
Accretion of liability for asset retirement obligations	'	'	'	'	'	'	'	'	28,299	15,565	15,942
General and administrative	'	'	'	'	'	'	'	'	28,137	23,208	18,741
Taxes, other than on earnings	'	'	'	'	'	'	'	'	11,490	13,007	14,365
Gain on sale of assets	'	'	'	'	'	'	'	'	-28,681	'	'
Gain on sale of assets	'	'	'	'	'	'	'	'	-28,681	'	'
Other	'	'	'	'	'	'	'	'	34,942	4,678	9,735
Total costs and expenses	122,077	143,178	98,535	109,657	86,235	67,379	68,071	71,501	473,447	293,186	281,201
Income from operations	20,533	40,814	85,552	72,692	52,664	19,289	31,199	27,295	219,591	130,447	67,126
Interest income	'	'	'	'	'	'	'	'	99	136	102
Interest expense	'	'	'	'	'	'	'	'	-52,368	-28,568	-17,548
Loss on derivative instruments	'	'	'	'	'	'	'	'	-32,361	-13,305	-5,870
Total other income (expense)	'	'	'	'	'	'	'	'	-84,630	-41,737	-25,693
Income (loss) before provision for income taxes	'	'	'	'	'	'	'	'	134,961	88,710	41,433
Deferred income tax expense	'	'	'	'	'	'	'	'	-49,687	-29,900	-14,822
Total provision for income taxes	'	'	'	'	'	'	'	'	-49,687	-29,900	-14,822
Net income	-12,058	-1,284	69,579	29,037	24,153	-2,247	35,401	1,503	85,274	58,810	26,611
Parent Company [Member]	'	'	'	'	'	'	'	'	'	'	'
Oil and natural gas	'	'	'	'	'	'	'	'	606,743	318,749	245,567
Other	'	'	'	'	'	'	'	'	689	15,152	15,007
Total Revenue	'	'	'	'	'	'	'	'	607,432	333,901	260,574
Lease operating	'	'	'	'	'	'	'	'	140,605	71,002	51,618
Transportation	'	'	'	'	'	'	'	'	3,548	611	766
Exploration expenditures and dry hole costs	'	'	'	'	'	'	'	'	22,265	18,790	14,045
Impairments	'	'	'	'	'	'	'	'	2,937	8,883	32,532
Depreciation, depletion and amortization	'	'	'	'	'	'	'	'	178,427	92,689	82,168
Accretion of liability for asset retirement obligations	'	'	'	'	'	'	'	'	23,196	10,551	9,013
General and administrative	'	'	'	'	'	'	'	'	28,137	22,845	18,281
Taxes, other than on earnings	'	'	'	'	'	'	'	'	1,084	1,162	-733
Gain on sale of assets	'	'	'	'	'	'	'	'	-28,219	'	'
Other	'	'	'	'	'	'	'	'	34,072	5,496	9,940
Total costs and expenses	'	'	'	'	'	'	'	'	406,052	232,029	217,630
Income from operations	'	'	'	'	'	'	'	'	201,380	101,872	42,944
Interest income	'	'	'	'	'	'	'	'	99	136	102
Interest expense	'	'	'	'	'	'	'	'	-52,368	-28,568	-17,548
Loss on derivative instruments	'	'	'	'	'	'	'	'	-32,361	-13,305	-5,870
Income (loss) from equity investments	'	'	'	'	'	'	'	'	11,506	18,945	15,532
Total other income (expense)	'	'	'	'	'	'	'	'	-73,124	-22,792	-10,161
Income (loss) before provision for income taxes	'	'	'	'	'	'	'	'	128,256	79,080	32,783
Deferred income tax expense	'	'	'	'	'	'	'	'	-42,982	-20,270	-6,172
Net income	'	'	'	'	'	'	'	'	85,274	58,810	26,611
Guarantor Subsidiaries [Member]	'	'	'	'	'	'	'	'	'	'	'
Oil and natural gas	'	'	'	'	'	'	'	'	82,000	103,780	102,640
Other	'	'	'	'	'	'	'	'	3,606	952	113
Total Revenue	'	'	'	'	'	'	'	'	85,606	104,732	102,753
Lease operating	'	'	'	'	'	'	'	'	25,236	23,848	18,663
Transportation	'	'	'	'	'	'	'	'	20	4	13
Exploration expenditures and dry hole costs	'	'	'	'	'	'	'	'	4,290	9	223
Impairments	'	'	'	'	'	'	'	'	'	'	-66
Depreciation, depletion and amortization	'	'	'	'	'	'	'	'	21,932	20,892	22,456
Accretion of liability for asset retirement obligations	'	'	'	'	'	'	'	'	5,103	5,014	6,929
General and administrative	'	'	'	'	'	'	'	'	'	15,363	15,460
Taxes, other than on earnings	'	'	'	'	'	'	'	'	10,406	11,845	15,098
Gain on sale of assets	'	'	'	'	'	'	'	'	-462	'	'
Other	'	'	'	'	'	'	'	'	870	-818	-205
Total costs and expenses	'	'	'	'	'	'	'	'	67,395	76,157	78,571
Income from operations	'	'	'	'	'	'	'	'	18,211	28,575	24,182
Income (loss) before provision for income taxes	'	'	'	'	'	'	'	'	18,211	28,575	24,182
Deferred income tax expense	'	'	'	'	'	'	'	'	-6,705	-9,630	-8,650
Net income	'	'	'	'	'	'	'	'	11,506	18,945	15,532
Consolidation, Eliminations [Member]	'	'	'	'	'	'	'	'	'	'	'
Other	'	'	'	'	'	'	'	'	'	-15,000	-15,000
Total Revenue	'	'	'	'	'	'	'	'	'	-15,000	-15,000
General and administrative	'	'	'	'	'	'	'	'	'	-15,000	-15,000
Total costs and expenses	'	'	'	'	'	'	'	'	'	-15,000	-15,000
Income (loss) from equity investments	'	'	'	'	'	'	'	'	-11,506	-18,945	-15,532
Total other income (expense)	'	'	'	'	'	'	'	'	-11,506	-18,945	-15,532
Income (loss) before provision for income taxes	'	'	'	'	'	'	'	'	-11,506	-18,945	-15,532
Net income	'	'	'	'	'	'	'	'	($11,506)	($18,945)	($15,532)

Supplemental_Condensed_Consoli4

Supplemental Condensed Consolidating Financial Information (Supplemental Condensed Consolidating Statement of Cash Flows) (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2010
				Parent Company [Member]	Parent Company [Member]	Parent Company [Member]	Guarantor Subsidiaries [Member]	Guarantor Subsidiaries [Member]	Guarantor Subsidiaries [Member]
Net cash provided by operating activities	$387,559	$213,871	$171,252	$356,597	$190,851	$136,245	$30,962	$23,020	$35,007
Decrease in restricted cash	'	'	2,466	'	'	2,466	'	'	'
Property acquisitions	-27,560	-578,372	-235,486	-27,560	-575,372	-235,486	'	-3,000	'
Exploration and development expenditures	-322,040	-184,850	-76,003	-284,073	-165,308	-40,996	-37,967	-19,542	-35,007
Deposit for Nexen Acquisition	-7,040	'	'	-7,040	'	'	'	'	'
Other property and equipment additions	-2,016	-1,743	-1,568	-2,016	-1,265	-1,568	'	-478	'
Proceeds from sale of assets	52,317	'	'	45,312	'	'	7,005	'	'
Net cash used in investing activities	-306,339	-764,965	-310,591	-275,377	-741,945	-275,584	-30,962	-23,020	-35,007
Proceeds from indebtedness	'	509,313	203,794	'	509,313	203,794	'	'	'
Repayments of indebtedness	-65,000	-20,000	'	-65,000	-20,000	'	'	'	'
Deferred financing costs	-674	-8,469	-6,646	-674	-8,469	-6,646	'	'	'
Purchase of shares into treasury	-9,640	-8,798	-11,353	-9,640	-8,798	-11,353	'	'	'
Exercise of stock options	1,385	441	119	1,385	441	119	'	'	'
Net cash provided by (used) in financing activities	-73,929	472,487	185,914	-73,929	472,487	185,914	'	'	'
Net increase in cash and cash equivalents	7,291	-78,607	46,575	7,291	-78,607	46,575	'	'	'
Cash and cash equivalents at beginning of period	1,521	80,128	33,553	1,521	80,128	33,553	'	'	'
Cash and cash equivalents at end of period	$8,812	$1,521	$80,128	$8,812	$1,521	$80,128	'	'	'