SilverBow Resources (SBOW) 10-K 2 Mar 15 2014 FY Annual report Financial data

Document_and_Entity_Informatio

Document and Entity Information (USD $)	12 Months Ended
	Dec. 31, 2014	Jan. 31, 2015	Jun. 30, 2014
Document and Entity Information [Abstract]
Entity Registrant Name	SWIFT ENERGY CO
Entity Central Index Key	351817
Document Type	10-K
Current Fiscal Year End Date	-19
Document Period End Date	31-Dec-14
Amendment Flag	FALSE
Document Fiscal Year Focus	2014
Document Fiscal Period Focus	FY
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		44,006,995
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$551,832,992

Condensed_Consolidated_Balance

Condensed Consolidated Balance Sheets (USD $)	Dec. 31, 2014		Dec. 31, 2013
In Thousands, unless otherwise specified
Current Assets:
Cash and cash equivalents	$406		$3,277
Accounts receivable	48,451		70,897
Deferred tax asset	6,243		10,715
Other current assets	9,569		7,600
Total Current Assets	64,669		92,489
Property and Equipment:
Property and Equipment, including $64,903 and $71,452 of unproved property costs not being amortized, respectively	5,934,155		5,714,099
Less - Accumulated depreciation, depletion, and amortization	-3,839,118		-3,125,282
Property and Equipment, Net	2,095,037		2,588,817
Other Long-Term Assets	13,641		17,199
Total Assets	2,173,347		2,698,505
Current Liabilities:
Accounts payable and accrued liabilities	68,244		82,318
Accrued capital costs	41,461		61,164
Accrued interest	21,389		21,561
Undistributed oil and gas revenues	17,825		10,990
Total Current Liabilities	148,919		176,033
Long-Term Debt	1,074,534	[1]	1,142,368	[1]
Deferred Tax Liabilities	86,376		241,205
Asset Retirement Obligation	62,122		63,225
Other Long-Term Liabilities	7,018		10,324
Commitments and Contingencies	0		0
Stockholders' Equity:
Preferred stock, $.01 par value, 5,000,000 shares authorized, none outstanding	0		0
Common stock, $.01 par value, 150,000,000 shares authorized, 44,379,463 and 43,915,346 shares issued, and 43,918,029 and 43,401,920 shares outstanding, respectively	444		439
Additional paid-in capital	771,972		762,242
Treasury stock held, at cost, 461,434 and 513,426 shares, respectively	-9,855		-12,575
Retained earnings	31,817		315,244
Total Stockholders' Equity	794,378		1,065,350
Total Liabilities and Stockholders' Equity	$2,173,347		$2,698,505
[1]	Amounts are shown net of any debt discount or premium

Condensed_Consolidated_Balance1

Condensed Consolidated Balance Sheets (Parenthetical) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified
Statement of Financial Position [Abstract]
Unproved Properties	$64,903	$71,452
Preferred stock, par value (in dollars per share)	$0.01	$0.01
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, shares outstanding	0	0
Common stock, par value per share (in dollars per share)	$0.01	$0.01
Common stock, shares authorized	150,000,000	150,000,000
Common stock, shares issued	44,379,463	43,915,346
Common stock, shares outstanding	43,918,029	43,401,920
Treasury stock shares held, at cost	461,434	513,426

Condensed_Consolidated_Stateme

Condensed Consolidated Statements of Operations (USD $)	12 Months Ended
In Thousands, except Per Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Revenues:
Oil and gas sales	$547,790	$585,229	$558,390
Price-risk management and other, net	1,666	-828	3,096
Total Revenues	549,456	584,401	561,486
Costs and Expenses:
General and administrative, net	39,629	45,423	47,097
Depreciation, depletion, and amortization	267,590	252,769	249,344
Accretion of asset retirement obligation	5,712	6,181	5,121
Lease operating cost	93,214	99,731	97,835
Transportation and gas processing	21,140	21,044	19,467
Severance and other taxes	37,038	42,725	47,546
Interest expense, net	73,207	69,382	57,303
Write-down of oil and gas properties	445,396	46,948	0
Total Costs and Expenses	982,926	584,203	523,713
Income from Continuing Operations Before Income Taxes	-433,470	198	37,773
Provision (Benefit) for Income Taxes	-150,043	2,640	16,072
Net Income (Loss)	($283,427)	($2,442)	$21,701
Per Share Amounts-
Earnings Per Share, Basic	($6.47)	($0.06)	$0.51
Earnings Per Share, Diluted	($6.47)	($0.06)	$0.50
Weighted Average Shares Outstanding - Basic	43,795	43,331	42,840
Weighted Average Shares Outstanding - Diluted	43,795	43,331	43,174

Condensed_Consolidated_Stateme1

Condensed Consolidated Statements of Comprehensive Income (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Statement of Comprehensive Income [Abstract]
Net Income (Loss)	($283,427)	($2,442)	$21,701
Other Comprehensive Income:
Unrealized gains (losses) related to price risk management transactions, before taxes	0	0	1,210
Provision (benefits) for income taxes	0	0	440
Unrealized gains (losses) related to price risk management transactions, net of taxes	0	0	770
Less: reclassification of (gains) losses on price risk management transactions to net income, before taxes	0	0	-1,210
(Provision) benefit for income taxes	0	0	-440
Reclassification of (gains) losses on price risk management transactions to net income, net of taxes	0	0	-770
Comprehensive Income	($283,427)	($2,442)	$21,701

Condensed_Consolidated_Stateme2

Condensed Consolidated Statements of Stockholders' Equity (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2011
Beginning Balance	$794,378	$1,065,350	$1,052,783	$1,011,351
Stock issued for benefit plans	1,909	1,622	1,654
Stock options exercised		4	636
Purchase of treasury shares	-1,065	-1,513	-2,805
Tax benefits from stock-based compensation		-1,607	175
Employee stock purchase plan	824	946	1,076
Issuance of restricted stock	0	0	0
Amortization of share-based compensation	10,787	15,557	18,995
Net Income (Loss)	-283,427	-2,442	21,701
Common Stock
Beginning Balance	444	439	435	430
Stock issued for benefit plans	0	0	0
Stock options exercised		0	1
Purchase of treasury shares	0	0	0
Tax benefits from stock-based compensation		0	0
Employee stock purchase plan	1	1	0
Issuance of restricted stock	4	3	4
Amortization of share-based compensation	0	0	0
Net Income (Loss)	0	0	0
Additional Paid-in Capital
Beginning Balance	771,972	762,242	748,517	727,286
Stock issued for benefit plans	-1,876	-1,171	354
Stock options exercised		4	635
Purchase of treasury shares	0	0	0
Tax benefits from stock-based compensation		-1,607	175
Employee stock purchase plan	823	945	1,076
Issuance of restricted stock	-4	-3	-4
Amortization of share-based compensation	10,787	15,557	18,995
Net Income (Loss)	0	0	0
Treasury Stock
Beginning Balance	-9,855	-12,575	-13,855	-12,350
Stock issued for benefit plans	3,785	2,793	1,300
Stock options exercised		0	0
Purchase of treasury shares	-1,065	-1,513	-2,805
Tax benefits from stock-based compensation		0	0
Employee stock purchase plan	0	0	0
Issuance of restricted stock	0	0	0
Amortization of share-based compensation	0	0	0
Net Income (Loss)	0	0	0
Retained Earnings
Beginning Balance	31,817	315,244	317,686	295,985
Stock issued for benefit plans	0	0	0
Stock options exercised		0	0
Purchase of treasury shares	0	0	0
Tax benefits from stock-based compensation		0	0
Employee stock purchase plan	0	0	0
Issuance of restricted stock	0	0	0
Amortization of share-based compensation	0	0	0
Net Income (Loss)	($283,427)	($2,442)	$21,701

Condensed_Consolidated_Stateme3

Condensed Consolidated Statements of Stockholders' Equity (Parenthetical)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Statement of Stockholders' Equity [Abstract]
Stock issued for benefit plans (shares)	154,665	104,890	50,987
Shares issued from stock option exercises	0	1,125	63,040
Purchase of treasury shares (shares)	102,673	98,020	86,812
Employee stock purchase plan (shares)	71,825	72,273	42,624
Issuance of restricted stock (shares)	392,292	391,581	375,157

Condensed_Consolidated_Stateme4

Condensed Consolidated Statements of Cash Flows (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Cash Flows from Operating Activities:
Net Income (Loss)	($283,427)	($2,442)	$21,701
Adjustments to reconcile net income to net cash provided by operation activities -
Write-down of oil and gas properties	445,396	46,948	0
Depreciation, depletion, and amortization	267,590	252,769	249,344
Accretion of asset retirement obligation	5,712	6,181	5,121
Deferred income taxes	-150,357	2,647	17,231
Stock-based compensation expenses	7,309	10,099	13,795
Other	-8,910	-5,443	976
Change in assets and liabilities-
(Increase) decrease in accounts receivable and other current assets	21,411	-1,894	-1,534
Increase (decrease) in accounts payable and accrued liabilities	1,505	2,607	-1,013
Increase (decrease) in income taxes payable	314	-224	82
Increase (decrease) in accrued interest	-172	199	8,903
Net Cash Provided by Operating Activities	306,371	311,447	314,606
Cash Flows from Investing Activities:
Additions to property and equipment	-386,336	-540,368	-757,755
Proceeds from the sale of property and equipment	145,035	6,991	528
Funds withdrawn from restricted cash account	25,994	0	0
Funds deposited into restricted cash account	-25,994	0	0
Net Cash Used in Investing Activities	-241,301	-533,377	-757,227
Cash Flows from Financing Activities:
Proceeds from long-term debt	0	0	157,500
Proceeds from bank borrowings	487,400	622,500	371,300
Payments of bank borrowings	-555,100	-396,900	-331,900
Net proceeds from issuances of common stock	824	950	1,712
Purchase of treasury shares	-1,065	-1,513	-2,805
Payments of debt issuance costs	0	0	-4,712
Net Cash Provided by (Used in) Financing Activities	-67,941	225,037	191,095
Net Increase (decrease) in Cash and Cash Equivalents	-2,871	3,107	-251,526
Cash and Cash Equivalents at Beginning of Period	3,277	170	251,696
Cash and Cash Equivalents at End of Period	406	3,277	170
Supplemental Disclosures of Cash Flows Information:
Cash paid during period for interest, net of amounts capitalized	70,933	67,070	46,911
Cash paid during period for income taxes	$150	$217	$248

Summary_of_Significant_Account

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies
	Principles of Consolidation. The accompanying consolidated financial statements include the accounts of Swift Energy and its wholly owned subsidiaries, which are engaged in the exploration, development, acquisition, and operation of oil and gas properties, with a focus on inland waters and onshore oil and natural gas reserves in Louisiana and Texas. Our undivided interests in oil and gas properties are accounted for using the proportionate consolidation method, whereby our proportionate share of each entity’s assets, liabilities, revenues, and expenses are included in the appropriate classifications in the accompanying consolidated financial statements. Intercompany balances and transactions have been eliminated in preparing the accompanying consolidated financial statements.
	Subsequent Events. We have evaluated subsequent events of our consolidated financial statements. In January of 2015 the company entered into a new lease agreement for office space in Houston, Texas. For additional discussion regarding the term and obligations of this lease refer to Note 5 of these consolidated financial statements. There were no other material subsequent events requiring additional disclosure in these financial statements.
	Use of Estimates. The preparation of financial statements in conformity with accounting principles generally accepted in the United States (“GAAP”) requires us to make estimates and assumptions that affect the reported amounts of certain assets and liabilities and the reported amounts of certain revenues and expenses during each reporting period. We believe our estimates and assumptions are reasonable; however, such estimates and assumptions are subject to a number of risks and uncertainties that may cause actual results to differ materially from such estimates. Significant estimates and assumptions underlying these financial statements include:
	•	the estimated quantities of proved oil and natural gas reserves used to compute depletion of oil and natural gas properties and the related present value of estimated future net cash flows there-from,
	•	estimates related to the collectability of accounts receivable and the credit worthiness of our customers,
	•	estimates of the counterparty bank risk related to letters of credit that our customers may have issued on our behalf,
	•	estimates of future costs to develop and produce reserves,
	•	accruals related to oil and gas sales, capital expenditures and lease operating expenses,
	•	estimates of insurance recoveries related to property damage, and the solvency of insurance providers,
	•	estimates in the calculation of share-based compensation expense,
	•	estimates of our ownership in properties prior to final division of interest determination,
	•	the estimated future cost and timing of asset retirement obligations,
	•	estimates made in our income tax calculations,
	•	estimates in the calculation of the fair value of hedging assets and liabilities, and
	•	estimates in the assessment of current litigation claims against the company.
	While we are not aware of any material revisions to any of our estimates, there will likely be future revisions to our estimates resulting from matters such as new accounting pronouncements, changes in ownership interests, payouts, joint venture audits, re-allocations by purchasers or pipelines, or other corrections and adjustments common in the oil and gas industry, many of which require retroactive application. These types of adjustments cannot be currently estimated and will be recorded in the period during which the adjustments occur.
	We are subject to legal proceedings, claims, liabilities and environmental matters that arise in the ordinary course of business. We accrue for losses when such losses are considered probable and the amounts can be reasonably estimated.
	Property and Equipment. We follow the “full-cost” method of accounting for oil and natural gas property and equipment costs. Under this method of accounting, all productive and nonproductive costs incurred in the exploration, development, and acquisition of oil and natural gas reserves are capitalized. Such costs may be incurred both prior to and after the acquisition of a property and include lease acquisitions, geological and geophysical services, drilling, completion, and equipment. Internal costs incurred that are directly identified with exploration, development, and acquisition activities undertaken by us for our own account, and which are not related to production, general corporate overhead, or similar activities, are also capitalized. For the years ended December 31, 2014, 2013 and 2012, such internal costs capitalized totaled $26.3 million, $31.8 million and $31.1 million, respectively. Interest costs are also capitalized to unproved oil and natural gas properties (refer to Note 4 of these consolidated financial statements for further discussion on capitalized interest costs).
	The “Property and Equipment” balances on the accompanying consolidated balance sheets are summarized for presentation purposes. The following is a detailed breakout of our “Property and Equipment” balances.
	(in thousands)	December 31,				December 31,
		2014				2013
	Property and Equipment
	Proved oil and gas properties	$	5,826,995			$	5,600,279
	Unproved oil and gas properties	64,903				71,452
	Furniture, fixtures, and other equipment	42,257				42,368
	Less – Accumulated depreciation, depletion, and amortization	(3,839,118		)		(3,125,282		)
	Property and Equipment, Net	$	2,095,037			$	2,588,817
	No gains or losses are recognized upon the sale or disposition of oil and natural gas properties, except in transactions involving a significant amount of reserves or where the proceeds from the sale of oil and natural gas properties would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a cost center. Internal costs associated with selling properties are expensed as incurred.
	Future development costs are estimated property-by-property based on current economic conditions and are amortized to expense as our capitalized oil and gas property costs are amortized.
	We compute the provision for depreciation, depletion, and amortization (“DD&A”) of oil and natural gas properties using the unit-of-production method. Under this method, we compute the provision by multiplying the total unamortized costs of oil and gas properties—including future development costs, gas processing facilities, and both capitalized asset retirement obligations and undiscounted abandonment costs of wells to be drilled, net of salvage values, but excluding costs of unproved properties—by an overall rate determined by dividing the physical units of oil and natural gas produced (which excludes natural gas consumed in operations) during the period by the total estimated units of proved oil and natural gas reserves (which excludes natural gas consumed in operations) at the beginning of the period. This calculation is done on a country-by-country basis and the period over which we will amortize these properties is dependent on our production from these properties in future years. Furniture, fixtures, and other equipment are recorded at cost and are depreciated by the straight-line method at rates based on the estimated useful lives of the property, which range between two and 20 years. Repairs and maintenance are charged to expense as incurred. Renewals and betterments are capitalized.
	Geological and geophysical (“G&G”) costs incurred on developed properties are recorded in “Proved properties” and therefore subject to amortization. G&G costs incurred that are directly associated with specific unproved properties are capitalized in “Unproved properties” and evaluated as part of the total capitalized costs associated with a prospect. The cost of unproved properties not being amortized is assessed quarterly, on a property-by-property basis, to determine whether such properties have been impaired. In determining whether such costs should be impaired, we evaluate current drilling results, lease expiration dates, current oil and gas industry conditions, international economic conditions, capital availability, and available geological and geophysical information. Any impairment assessed is added to the cost of proved properties being amortized.
	Full-Cost Ceiling Test. At the end of each quarterly reporting period, the unamortized cost of oil and natural gas properties (including natural gas processing facilities, capitalized asset retirement obligations, net of related salvage values and deferred income taxes, and excluding the recognized asset retirement obligation liability) is limited to the sum of the estimated future net revenues from proved properties (excluding cash outflows from recognized asset retirement obligations, including future development and abandonment costs of wells to be drilled, using the preceding 12-months’ average price based on closing prices on the first day of each month, adjusted for price differentials, discounted at 10%, and the lower of cost or fair value of unproved properties) adjusted for related income tax effects (“Ceiling Test”). This calculation is done on a country-by-country basis.
	The calculations of the Ceiling Test and provision for DD&A are based on estimates of proved reserves. There are numerous uncertainties inherent in estimating quantities of proved reserves and in projecting the future rates of production, timing, and plan of development. The accuracy of any reserves estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing, and production subsequent to the date of the estimate may justify revision of such estimates. Accordingly, reserves estimates are often different from the quantities of oil and natural gas that are ultimately recovered.
	Due to the effects of pricing, timing of projects and changes in our reserves product mix, in 2014 and 2013 we reported non-cash write-downs on a before-tax basis of $445.4 million and $46.9 million, respectively, on our oil and natural gas properties.
	If future capital expenditures out pace future discounted net cash flows in our reserve calculations, if we have significant declines in our oil and natural gas reserves volumes (which also reduces our estimate of discounted future net cash flows from proved oil and natural gas reserves) or if oil or natural gas prices decline, non-cash write-downs of our oil and natural gas properties could occur in the future. We cannot control and cannot predict what future prices for oil and natural gas will be, thus we cannot estimate the amount or timing of any potential future non-cash write-down of our oil and natural gas properties due to decreases in oil or natural gas prices.
	Revenue Recognition. Oil and gas revenues are recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectability of the revenue is probable. Swift Energy uses the entitlement method of accounting in which we recognize our ownership interest in production as revenue. If our sales exceed our ownership share of production, the natural gas balancing payables are reported in “Accounts payable and accrued liabilities” on the accompanying consolidated balance sheets. Natural gas balancing receivables are reported in “Other current assets” on the accompanying consolidated balance sheets when our ownership share of production exceeds sales. As of December 31, 2014 and 2013, we did not have any material natural gas imbalances.
	Reclassification of Prior Period Balances. Certain reclassifications have been made to prior period amounts to conform to the current-year presentation.
	Accounts Receivable. We assess the collectability of accounts receivable, and based on our judgment, we accrue a reserve when we believe a receivable may not be collected. At December 31, 2014 and 2013, we had an allowance for doubtful accounts of approximately $0.1 million, respectively. The allowance for doubtful accounts has been deducted from the total “Accounts receivable” balance on the accompanying consolidated balance sheets.
	At December 31, 2014, our “Accounts receivable” balance included $34.8 million for oil and gas sales, $8.4 million for joint interest owners, $3.1 million for severance tax credit receivables and $2.2 million for other receivables. At December 31, 2013, our “Accounts receivable” balance included $56.9 million for oil and gas sales, $1.6 million for joint interest owners, $11.6 million for severance tax credit receivables and $0.8 million for other receivables.
	Debt Issuance Costs. Legal fees, accounting fees, underwriting fees, printing costs, and other direct expenses associated with extensions of our senior notes were capitalized and are amortized on an effective interest basis over the life of each of the respective senior note offerings.
	The 7.125% senior notes due in 2017 mature on June 1, 2017, and the remaining balance of their issuance costs at December 31, 2014, was $1.3 million. The 8.875% senior notes due in 2020 mature on January 15, 2020, and the remaining balance of their issuance costs at December 31, 2014, was $3.1 million. The 7.875% senior notes due in 2022 mature on March 1, 2022, and the balance of their remaining issuance costs at December 31, 2014, was $5.9 million. The remaining balance of revolving credit facility issuance costs at December 31, 2014, was $2.3 million.
	Price-Risk Management Activities. The Company follows FASB ASC 815-10, which requires that changes in the derivative’s fair value are recognized currently in earnings unless specific hedge accounting criteria are met. The guidance also establishes accounting and reporting standards requiring that every derivative instrument (including certain derivative instruments embedded in other contracts) is recorded in the consolidated balance sheets as either an asset or a liability measured at its fair value. Hedge accounting for a qualifying hedge allows the gains and losses on derivatives to offset related results on the hedged item in the statement of operations and requires that a company formally document, designate, and assess the effectiveness of transactions that receive hedge accounting.
	Prior to January 1, 2013, the Company had elected hedge accounting on all qualifying derivative instruments. As of December 31, 2012, the Company did not have any outstanding derivatives. For all derivatives entered into after January 1, 2013, the Company elected not to apply hedge accounting. The changes in the fair value of our derivatives initiated after January 1, 2013 are recognized in "Price-risk management and other, net” on the accompanying consolidated statements of operations.
	We have a price-risk management policy to use derivative instruments to protect against declines in oil and natural gas prices, mainly through the purchase of price floors, calls, swaps, collars and participating collars. Prior to January 1, 2013, all hedges were designated as a hedge of the variability in cash flows associated with the forecasted sale of oil and natural gas production. Changes in the fair value of a hedge that was highly effective and was designated, documented and qualified as a cash flow hedge, to the extent that the hedge was effective, were recorded in “Accumulated other comprehensive income, net of income tax” on the balance sheet. When the hedged transactions were recorded upon the actual sale of the oil and natural gas, those gains or losses were reclassified from “Accumulated other comprehensive income, net of income tax” and were recorded in “Price-risk management and other, net” on the accompanying consolidated statements of operations. Changes in the fair value of derivatives that did not meet the criteria for hedge accounting, and the ineffective portion of the hedge for which hedge accounting was elected, were recognized in "Price-risk management and other, net."
	For the years ended December 31, 2014, 2013 and 2012, we recognized net gains (losses) of $1.3 million, ($0.9) million and $2.3 million, respectively, relating to our derivative activities. The ineffectiveness for the year ended December 31, 2012, was not material. The effects of our derivatives are included in the "Other" section of our Cash Flows from Operating Activities on the accompanying consolidated statements of cash flows.
	The fair values of our derivatives are computed using commonly accepted industry-standard models and are periodically verified against quotes from brokers. The fair value of our unsettled derivative assets at December 31, 2014 was $2.5 million which was recognized on the accompanying consolidated balance sheet in “Other current assets.” The fair value of our unsettled derivative liabilities at December 31, 2014 was $0.1 million which was recognized on the accompanying consolidated balance sheet in “Accounts payable and accrued liabilities.”
	The Company uses an International Swap and Derivatives Association "ISDA" master agreement for all derivative contracts. This is an industry standardized contract containing the general conditions of our derivative transactions including provisions relating to netting derivative settlement payments under certain circumstances (such as default). For reporting purposes, the Company has elected to not offset the asset and liability fair value amounts of its derivatives on the accompanying balance sheets. If all counterparties were in a default situation, the Company, under the right of set-off, would show a net derivative fair value asset of $2.4 million at December 31, 2014. For further discussion related to the fair value of the Company's derivatives, refer to Note 9 of these consolidated financial statements.
	At December 31, 2014, we had $1.0 million in receivables for settled derivatives which were recognized on the accompanying balance sheet in “Accounts receivable” and were subsequently collected in January of 2015.
	The following tables summarize the weighted average prices and future production volumes for our unsettled derivative contracts in place as of December 31, 2014.
								Collars
	Natural Gas Derivatives	Total Volumes (MMBtu)		Swap Fixed Price				Floor		Ceiling Price
	(NYMEX Henry Hub Settlements)							Price
	2015 Contracts
	Swaps	600,000		$	4.42
	Collars	1,280,000						$	4.05	$	4.88
	Natural Gas Basis Derivatives	Total Volumes (MMBtu)		Swap Fixed Price
	(East Texas Houston Ship Channel Settlements)
	2015 Contracts
	Swaps	7,280,000		$	(0.02	)
	Supervision Fees. Consistent with industry practice, we charge a supervision fee to the wells we operate including our wells in which we own up to a 100% working interest. Supervision fees are recorded as a reduction to “General and administrative, net”, on the accompanying consolidated statements of operations. Our supervision fees are based on COPAS industry guidelines. The amount of supervision fees charged for the years ended December 31, 2014, 2013 and 2012, respectively, did not exceed our actual costs incurred. The total amount of supervision fees charged to the wells we operated was $12.7 million, $11.6 million and $11.3 million for the years ended December 31, 2014, 2013 and 2012, respectively.
	Other Current Assets. Included in "Other current assets" on the accompanying consolidated balance sheets are inventories which consist primarily of tubulars and other equipment and supplies that we expect to place in service in production operations. Our inventories are recorded at cost (weighted average method) and totaled $3.1 million and $3.5 million at December 31, 2014 and 2013, respectively.
	Included in "Other current assets" on the accompanying consolidated balance sheets are prepaid expenses totaling $3.9 million and $3.3 million at December 31, 2014 and 2013. These prepaid amounts cover well insurance, drilling contracts and various other prepaid expenses.
	Income Taxes. Under guidance contained in FASB ASC 740-10, deferred taxes are determined based on the estimated future tax effects of differences between the financial statement and tax basis of assets and liabilities, given the provisions of the enacted tax laws.
We follow the recognition and disclosure provisions under guidance contained in FASB ASC 740-10-25. Under this guidance, tax positions are evaluated for recognition using a more-likely-than-not threshold, and those tax positions requiring recognition are measured as the largest amount of tax benefit that is greater than fifty percent likely of being realized upon ultimate settlement with a taxing authority that has full knowledge of all relevant information. Our policy is to record interest and penalties relating to uncertain tax positions in income tax expense.
Accounts Payable and Accrued Liabilities. The “Accounts payable and accrued liabilities” balances on the accompanying consolidated balance sheets are summarized below (in thousands):
	December 31,				December 31,
	2014				2013
Trade accounts payable (1)	$	31,153			$	30,769
Accrued operating expenses	10,784				16,016
Accrued payroll costs	8,100				10,938
Asset retirement obligations – current portion	10,709				15,859
Accrued taxes	2,957				5,845
Other payables	4,541				2,891
Total accounts payable and accrued liabilities	$	68,244			$	82,318
(1) Included in “trade accounts payable” are liabilities of approximately $13.7 million and $26.1 million at December 31, 2014 and 2013, respectively, for outstanding checks.
Cash and Cash Equivalents. We consider all highly liquid instruments with an initial maturity of three months or less to be cash equivalents.
Credit Risk Due to Certain Concentrations. We extend credit, primarily in the form of uncollateralized oil and gas sales and joint interest owners' receivables, to various companies in the oil and gas industry, which results in a concentration of credit risk. The concentration of credit risk may be affected by changes in economic or other conditions within our industry and may accordingly impact our overall credit risk. However, we believe that the risk of these unsecured receivables is mitigated by the size, reputation, and nature of the companies to which we extend credit. From certain customers we also obtain letters of credit or parent company guarantees, if applicable, to reduce risk of loss. For the years ended December 31, 2014, 2013 and 2012, Shell Oil Company and affiliates accounted for 21%, 33% and 46% of our total oil and gas gross receipts, respectively. Kinder Morgan and Plains Marketing accounted for approximately 20% and 11% of our total oil and gas gross receipts in 2014, respectively. BP America accounted for approximately 21% of our total oil and gas gross receipts in 2013 while Southcross Energy accounted for approximately 11% of our total oil and gas gross receipts in 2012. Credit losses in each of the last three years were immaterial.
Short-Term Restricted Cash (Saka Energi Transaction). On July 15, 2014, we closed our transaction with PT Saka Energi Indonesia ("Saka Energi") to fully develop 8,300 acres of Fasken area Eagle Ford shale properties owned by Swift Energy in Webb County, Texas. Swift Energy sold a 36% full participating interest in the Fasken properties to Saka Energi.
Subject to the terms of the transaction, Swift Energy and Saka Energi were depositing cash on a monthly basis into a separate Swift Energy-owned bank account to fund their respective portions of the on-going Fasken development program for the following month. All cash deposited in the account was contractually restricted for use in the Fasken development program and therefore was recorded as restricted cash until the Company performed the related development activities. During the fourth quarter of 2014 this cash requirement process was discontinued and all unused amounts were refunded.
During the year Saka Energi deposited $29.8 million into the account, from which $7.1 million was withdrawn from the account in order to fund on-going development operations in the Fasken area, while the remainder was refunded to Saka upon discontinuance of the cash requirement process noted above. The cash changes from the account relating to Saka Energi’s contributions are shown in the operating activities section of the accompanying consolidated statements of cash flows. The cash changes from the account relating to Swift Energy’s contributions are reported in the investing activities section on the accompanying consolidated statements of cash flows.
Long-Term Restricted Cash. These balances primarily include amounts held in escrow accounts to satisfy plugging and abandonment obligations. As of December 31, 2014 and 2013, these assets were approximately $1.0 million. These amounts are restricted as to their current use, and will be released when we have satisfied all plugging and abandonment obligations in certain fields. Restricted cash balances are reported in “Other Long-Term Assets” on the accompanying consolidated balance sheets.
Asset Retirement Obligations. We record these obligations in accordance with the guidance contained in FASB ASC 410-20. This guidance requires entities to record the fair value of a liability for legal obligations associated with the retirement obligations of tangible long-lived assets in the period in which it is incurred. When the liability is initially recorded, the carrying amount of the related long-lived asset is increased. The liability is discounted from the expected date of abandonment. Over time, accretion of the liability is recognized each period, and the capitalized cost is depreciated on a unit-of-production basis as part of depreciation, depletion, and amortization expense for our oil and gas properties. Upon settlement of the liability, the Company either settles the obligation for its recorded amount or incurs a gain or loss upon settlement which is included in the “Property and Equipment” balance on our accompanying consolidated balance sheets. This guidance requires us to record a liability for the fair value of our dismantlement and abandonment costs, excluding salvage values.
The following provides a roll-forward of our asset retirement obligations (in thousands):
Asset Retirement Obligations as of December 31, 2012	$	86,777
Accretion expense	6,181
Liabilities incurred for new wells and facilities construction	1,588
Reductions due to sold and abandoned wells and facilities	(16,394		)
Revisions in estimates	932
Asset Retirement Obligations as of December 31, 2013	$	79,084
Accretion expense	5,712
Liabilities incurred for new wells and facilities construction	469
Reductions due to sold and abandoned wells and facilities	(8,253		)
Revisions in estimates	(4,181		)
Asset Retirement Obligations as of December 31, 2014	$	72,831
At December 31, 2014 and 2013, approximately $10.7 million and $15.9 million, respectively, of our asset retirement obligation was classified as a current liability in “Accounts payable and accrued liabilities” on the accompanying consolidated balance sheets.
New Accounting Pronouncements. In May 2014, the FASB issued ASU 2014-09, providing a comprehensive revenue recognition standard for contracts with customers that supersedes current revenue recognition guidance. The guidance is effective for annual and interim reporting periods beginning after December 15, 2016 and upon adoption, entities are required to recognize revenue using the following five-step model: identify the contract with a customer, identify the performance obligations in the contract, determine the transaction price, allocate the transaction price to the performance obligations in the contract, and recognize revenue as the entity satisfies each performance obligation. Adoption of this standard could result in retrospective application, either in the form of recasting all prior periods presented or a cumulative adjustment to equity in the period of adoption. We are currently reviewing the new requirements to determine the impact of this guidance on our financial statements.

Earnings_Per_Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Earnings Per Share	Earnings Per Share
	The Company computes earnings per share in accordance with FASB ASC 260-10. Basic earnings per share (“Basic EPS”) has been computed using the weighted average number of common shares outstanding during each period. Diluted earnings per share ("Diluted EPS") assumes, as of the beginning of the period, exercise of stock options and restricted stock grants using the treasury stock method. Diluted EPS also assumes conversion of performance-based restricted stock units to common shares based on the number of shares (if any) that would be issuable, according to predetermined performance and market goals, if the end of the reporting period was the end of the performance period. As we recognized a net loss for the years ended December 31, 2014 and 2013, the unvested share-based payments and stock options were not recognized in diluted earnings per share (“Diluted EPS”) calculations as they would be antidilutive. Certain of our stock options and restricted stock grants that would potentially dilute Basic EPS in the future were also antidilutive for the year ended December 31, 2012, and are discussed below.
	The following is a reconciliation of the numerators and denominators used in the calculation of Basic and Diluted EPS for the years ended December 31, 2014, 2013 and 2012 (in thousands, except per share amounts):
		2014							2013							2012
		Net Income (Loss)			Shares	Per Share			Net Income (Loss)			Shares	Per Share			Net Income (Loss)		Shares	Per Share
						Amount							Amount						Amount
	Basic EPS:
	Net Income (Loss) and Share Amounts	$	(283,427	)	43,795	$	(6.47	)	$	(2,442	)	43,331	$	(0.06	)	$	21,701	42,840	$	0.51
	Dilutive Securities:
	Stock Options				—							—						90
	Restricted Stock Awards				—							—						244
	Diluted EPS:
	Net Income (Loss) and Assumed Share Conversions	$	(283,427	)	43,795	$	(6.47	)	$	(2,442	)	43,331	$	(0.06	)	$	21,701	43,174	$	0.5
	Options to purchase approximately 1.3 million shares at an average exercise price of $34.02 were outstanding at December 31, 2014, while options to purchase approximately 1.5 million shares at an average exercise price of $33.38 were outstanding at December 31, 2013 and options to purchase approximately 1.6 million shares at an average exercise price of $33.13 were outstanding at December 31, 2012.
	All of the 1.4 million, 1.6 million and 1.3 million stock options to purchase shares were not included in the computation of Diluted EPS for the years ended December 31, 2014, 2013 and 2012, respectively, as they were antidilutive.
	For the years ended December 31, 2014 and 2013, 0.5 million and 0.3 million restricted stock awards were not included in the computation of Diluted EPS, as they would be antidilutive given the net loss. Approximately 0.3 million of restricted stock awards were not included in the computation of Diluted EPS for the year ended December 31, 2012 because they were antidilutive.
	Approximately 0.4 million and 0.3 million shares related to performance-based restricted stock units that could be converted to common shares based on predetermined performance and market goals were not included in the computation of Diluted EPS for years ended December 31, 2014 and 2013, respectively, primarily because the performance and market conditions had not been met, assuming the end of the reporting period was the end of the performance period.

Provision_Benefit_for_Income_T

Provision (Benefit) for Income Taxes	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Provision (Benefit) for Income Taxes	Provision (Benefit) for Income Taxes
	Income (Loss) before taxes is as follows (in thousands):
		Year Ended December 31,
		2014			2013			2012
	Income (Loss) Before Income Taxes	$	(433,470	)	$	198		$	37,773
	The following is an analysis of the consolidated income tax provision (benefit) (in thousands):
		Year Ended December 31,
		2014			2013			2012
	Current	$	314		$	(12	)	$	(1,144	)
	Deferred	(150,357		)	2,652			17,216
	Total	$	(150,043	)	$	2,640		$	16,072
	Reconciliations of income taxes computed using the U.S. Federal statutory rate (35%) to the effective income tax rates are as follows (in thousands):
		Year Ended December 31,
		2014			2013			2012
	Income taxes computed at U.S. statutory rate	$	(151,714	)	$	69		$	13,221
	State tax provisions (benefits), net of federal benefits	(5,935		)	(184		)	(950		)
	Non-deductible equity compensation	666			1,127			1,911
	Stock-based compensation tax shortfall	2,409			558			—
	Valuation allowances	4,635			385			2,370
	Expiration of carryover items	288			400			—
	Uncertain Tax Positions	—			—			(977		)
	Other, net	(392		)	285			497
	Provision (benefit) for income taxes	$	(150,043	)	$	2,640		$	16,072
	Effective rate	34.6		%	1,333.40		%	42.5		%
	The Company’s operations are concentrated in Texas and Louisiana. The Company’s state tax provision varies in proportion to the overall statutory rate due to differences in deductions allowed for U.S. Federal and state income taxes.
	In 2014 and 2013, the Company recorded tax expense of $2.4 million and $0.6 million, respectively, for stock-based compensation shortfalls. These shortfalls are for stock compensation grants on which the realized tax deduction was less than expense booked for these grants. Historically, the Company recorded excess tax benefits and shortfalls to paid-in-capital. However, during 2013 the Company exhausted its APIC Pool. The total tax effect of the shortfall for 2013 was $2.2 million, with $1.6 million being recorded as a reduction in paid-in-capital, and the remainder to tax expense. The entire shortfall for 2014 was recorded as tax expense.
	The valuation allowances are primarily attributable to Louisiana net operating loss carryovers.
	The tax effects of temporary differences representing the net deferred tax asset (liability) at December 31, 2014 and 2013 were as follows (in thousands):
		Year Ended December 31,
		2014			2013
	Deferred tax assets:
	Federal net operating loss (“NOL”) carryovers	$	141,896		$	117,713
	NOLs for excess stock-based compensation	(9,606		)	(9,615		)
	State NOL carryovers	15,525			14,626
	Alternative minimum tax credits	2,092			2,092
	Other Carryover Items	1,294			1,295
	Asset Retirement Obligations	26,388			28,628
	Unrealized share-based compensation	9,471			9,957
	Valuation allowance	(11,327		)	(6,703		)
	Other	4,056			6,042
	Total deferred tax assets	$	179,789		$	164,035
	Deferred tax liabilities:
	Oil and gas exploration and development costs	$	(258,326	)	$	(393,606	)
	Other	(1,596		)	(919		)
	Total deferred tax liabilities	$	(259,922	)	$	(394,525	)
	Net deferred tax liabilities	$	(80,133	)	$	(230,490	)
	Net current deferred tax assets	6,243			10,715
	Net non-current deferred tax liabilities	$	(86,376	)	$	(241,205	)
	The federal NOL carryovers totaling $405.4 million will expire between 2027 and 2034 if not utilized in earlier periods. Deferred tax benefits for excess stock-based compensation deductions represent stock-based compensation that have generated tax deductions that have not yet resulted in a cash tax benefit because the Company has NOL carryovers. The Company plans to recognize the federal NOL net deferred tax assets associated with excess stock-based compensation tax deductions only when all other components of the federal NOL carryover tax assets have been fully utilized. If and when the excess stock-based compensation related NOL carryover tax assets are realized, the benefit will be credited directly to equity. The state NOL carryovers are for Louisiana. The Louisiana loss carryovers are scheduled to expire between 2015 and 2029. The valuation allowances include $10.9 million and $6.6 million for 2014 and 2013, respectively for the Louisiana NOL carryovers.
	U.S. Federal income tax returns for 2007 forward, Louisiana income tax returns from 1999 forward, New Zealand income tax returns after 2007, and Texas franchise tax returns after 2009 remain open to possible examination by the taxing authorities. There are no material unresolved items related to periods previously audited by these taxing authorities. No other jurisdiction returns are significant to our financial position.
	As of December 31, 2014, we do not have any accrued liability for uncertain tax positions. We do not believe the total of unrecognized tax positions will significantly increase or decrease during the next 12 months.

LongTerm_Debt

Long-Term Debt	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt
	Our long-term debt as of December 31, 2014 and 2013, was as follows (in thousands):
		December 31, 2014		December 31, 2013
	7.125% senior notes due in 2017	$	250,000	$	250,000
	8.875% senior notes due in 2020 (1)	222,775		222,446
	7.875% senior notes due in 2022 (1)	404,459		404,922
	Bank Borrowings	197,300		265,000
	Long-Term Debt (1)	$	1,074,534	$	1,142,368
	(1) Amounts are shown net of any debt discount or premium
	As of December 31, 2014, our bank borrowings of $197.3 million mature in 2017. The maturities on our senior notes were $250.0 million in 2017, $225.0 million in 2020 and $400.0 million in 2022.
	We have capitalized interest on our unproved properties in the amount of $5.0 million, $7.2 million and $7.9 million for the years ended December 31, 2014, 2013 and 2012, respectively.
	Bank Borrowings. On October 27, 2014, our syndicate of 11 banks reaffirmed the borrowing base of $417.6 million on our $500.0 million credit facility. The commitment amount of $417.6 million and maturity date of November 1, 2017 remained unchanged. Our next scheduled borrowing base redetermination is May 1, 2015.
	The borrowing base may be affected by the performance of our oil and gas properties and changes in oil and natural gas prices. The pricing used by the banks to determine the borrowing base in future periods may be lower than the pricing used in October 2014, during our previous redetermination. The determination of the borrowing base is at the sole discretion of the administrative agent and the bank syndicate.
	At December 31, 2014 and 2013, we had $197.3 million and $265.0 million in outstanding borrowings under our credit facility, respectively. The interest rate on our credit facility is either (a) the lead bank’s prime rate plus an applicable margin or (b) the Eurodollar rate plus an applicable margin. However with respect to (a), if the lead bank’s prime rate is not higher than each of the federal funds rate plus 0.5%, and the adjusted London Interbank Offered Rate (“LIBOR”) plus 1%, the greatest of these three rates will then apply. The applicable margins vary depending on the level of outstanding debt with escalating rates of 50 to 150 basis points above the Alternative Base Rate and escalating rates of 150 to 250 basis points for Eurodollar rate loans. During 2014, the lead bank’s prime rate was 3.25% and the commitment fee associated with the credit facility fluctuated between 0.38% and 0.50%.
	The terms of our credit facility include, among other restrictions, a limitation on the level of cash dividends (not to exceed $15.0 million in any fiscal year), a remaining aggregate limitation on purchases of our stock of $50.0 million, and limitations on incurring other debt. In addition, our bank credit agreement contains financial covenants detailing certain minimum financial ratios that must be maintained. The first is an adjusted working capital ratio of adjusted current assets to current liabilities (as defined in the Credit Agreement) of not less than 1.0 to 1.0, which is below the Company's December 31, 2014 ratio of 1.9 to 1.0. There is also an interest coverage ratio, calculated on a trailing twelve month basis of EBITDAX to interest expense (as defined in the Credit Agreement), of no less than 2.75 to 1.0, which is below the Company's December 31, 2014 ratio of 4.9 to 1.0. Since inception, no cash dividends have been declared on our common stock. The terms of the credit facility also require us to secure at least 75% of our oil and natural gas properties. Under the terms of the credit facility, the commitment amount can be less than or equal to the total amount of the borrowing base with unanimous consent of the bank group as it might change from time to time. As of December 31, 2014, we were in compliance with the provisions of this agreement, and expect to remain in compliance throughout 2015.
	Interest expense on the credit facility, including commitment fees and amortization of debt issuance costs, totaled $7.5 million, $6.0 million and $3.7 million for the years ended December 31, 2014, 2013 and 2012, respectively. The amount of commitment fees included in interest expense, net was $0.8 million, $1.1 million and $1.4 million for the years ended December 31, 2014, 2013 and 2012, respectively.
	In prior periods, the Company presented the net change in its bank borrowings credit as a single line item within the financing activities section of the accompanying consolidated statements of cash flows. Beginning in 2014, the Company chose to correct this immaterial presentation error and began presenting bank borrowings and repayments on a gross basis. The financing activities section of the accompanying consolidated statements of cash flows for the 2013 and 2012 periods have been corrected for this immaterial error in presentation, which did not affect cash balances, total financing cash flows or any other subtotal on the accompanying consolidated statements of cash flows.
	Senior Notes Due In 2022. These notes consist of $400.0 million of 7.875% senior notes that will mature on March 1, 2022. On November 30, 2011, we issued $250.0 million of these senior notes at a discount of $2.1 million or 99.156% of par, which equates to an effective yield to maturity of 8%. The original discount of $2.1 million is recorded in “Long-Term Debt” on our consolidated balance sheets and will be amortized over the life of the notes using the effective interest method. On October 3, 2012, we issued an additional $150.0 million of these senior notes at 105% of par, which equates to a yield to worst of 6.993%. The premium of $7.5 million is recorded in “Long-Term Debt” on our consolidated balance sheets and will be amortized over the life of the notes using the effective interest method. The notes are senior unsecured obligations that rank equally with all of our existing and future senior unsecured indebtedness, are effectively subordinated to all our existing and future secured indebtedness to the extent of the value of the collateral securing such indebtedness, including borrowing under our bank credit facility, and will rank senior to any future subordinated indebtedness of Swift Energy. Interest on these notes is payable semi-annually on March 1 and September 1 and commenced on March 1, 2012. On or after March 1, 2017, we may redeem some or all of these notes, with certain restrictions, at a redemption price, plus accrued and unpaid interest, of 103.938% of principal, declining in annual intervals to 100% in 2020 and thereafter. In addition, prior to March 1, 2015, we may redeem up to 35% of the principal amount of the notes with the net proceeds of qualified offerings of our equity at a redemption price of 107.875% of the principal amount of the notes, plus accrued and unpaid interest. We incurred approximately $7.5 million of debt issuance costs related to these notes, which is included in “Other Long–Term Assets” on the accompanying consolidated balance sheets and will be amortized to interest expense, net over the life of the notes using the effective interest method. In the event of certain changes in control of Swift Energy, each holder of notes will have the right to require us to repurchase all or any part of the notes at a purchase price in cash equal to 101% of the principal amount, plus accrued and unpaid interest to the date of purchase. The terms of these notes include, among other restrictions, limitations on our ability to repurchase shares, incur debt, create liens, make investments, transfer or sell assets, enter into transactions with affiliates and consolidate, merge or transfer all or substantially all of our assets. We were in compliance with the provisions of the indenture governing these senior notes as of December 31, 2014.
	Interest expense on the senior notes due in 2022, including amortization of debt issuance costs and debt premium, totaled $31.6 million for the years ended December 31, 2014 and 2013, and $22.4 million for the year ended December 31, 2012.
	Senior Notes Due In 2020. These notes consist of $225.0 million of 8.875% senior notes issued at 98.389% of par, which equates to an effective yield to maturity of 9.125%. The notes were issued on November 25, 2009 with an original discount of $3.6 million and will mature on January 15, 2020. The original discount of $3.6 million is recorded in “Long-Term Debt” on our consolidated balance sheets and will be amortized over the life of the notes using the effective interest method. The notes are senior unsecured obligations that rank equally with all of our existing and future senior unsecured indebtedness, are effectively subordinated to all our existing and future secured indebtedness to the extent of the value of the collateral securing such indebtedness, including borrowing under our bank credit facility, and will rank senior to any future subordinated indebtedness of Swift Energy. Interest on these notes is payable semi-annually on January 15 and July 15 and commenced on January 15, 2010. On or after January 15, 2015, we may redeem some or all of these notes, with certain restrictions, at a redemption price, plus accrued and unpaid interest, of 104.438% of principal, declining in annual intervals to 100% in 2018 and thereafter. We incurred approximately $5.0 million of debt issuance costs related to these notes, which is included in “Other Long–Term Assets” on the accompanying consolidated balance sheets and will be amortized to interest expense, net over the life of the notes using the effective interest method. In the event of certain changes in control of Swift Energy, each holder of notes will have the right to require us to repurchase all or any part of the notes at a purchase price in cash equal to 101% of the principal amount, plus accrued and unpaid interest to the date of purchase. The terms of these notes include, among other restrictions, limitations on our ability to repurchase shares, incur debt, create liens, make investments, transfer or sell assets, enter into transactions with affiliates and consolidate, merge or transfer all or substantially all of our assets. We were in compliance with the provisions of the indenture governing these senior notes as of December 31, 2014.
	Interest expense on the senior notes due in 2020, including amortization of debt issuance costs and debt discount, totaled $20.8 million, $20.7 million and $20.6 million for the years ended December 31, 2014, 2013 and 2012, respectively.
	Senior Notes Due In 2017. These notes consist of $250.0 million of 7.125% senior notes due in 2017, which were issued on June 1, 2007 at 100% of the principal amount and will mature on June 1, 2017. The notes are senior unsecured obligations that rank equally with all of our existing and future senior unsecured indebtedness, are effectively subordinated to all our existing and future secured indebtedness to the extent of the value of the collateral securing such indebtedness, including borrowing under our bank credit facility, and will rank senior to any future subordinated indebtedness of Swift Energy. Interest on these notes is payable semi-annually on June 1 and December 1, and commenced on December 1, 2007. As of December 31, 2014, we may redeem some or all of these notes, with certain restrictions, at a redemption price of 101.188% of the principal, plus accrued and unpaid interest, declining to 100% at June 1, 2015. We incurred approximately $4.2 million of debt issuance costs related to these notes, which is included in “Other Long-Term Assets” on the accompanying consolidated balance sheets and will be amortized to interest expense, net over the life of the notes using the effective interest method. In the event of certain changes in control of Swift Energy, each holder of notes will have the right to require us to repurchase all or any part of the notes at a purchase price in cash equal to 101% of the principal amount, plus accrued and unpaid interest to the date of purchase. The terms of these notes include, among other restrictions, limitations on our ability to repurchase shares, incur debt, create liens, make investments, transfer or sell assets, enter into transactions with affiliates and consolidate, merge or transfer all or substantially all of our assets. We were in compliance with the provisions of the indenture governing these senior notes as of December 31, 2014.
	Interest expense on the senior notes due in 2017, including amortization of debt issuance costs, totaled $18.3 million for the years ended December 31, 2014 and 2013, and $18.2 million for the year ended December 31, 2012.

Commitments_and_Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies
	Rental and lease expenses were $21.0 million, $20.5 million and $19.9 million for the years ended December 31, 2014, 2013 and 2012, respectively. The rental and lease expenses primarily relate to compressor rentals during the year and the lease of our office space in Houston, Texas, which was set to expire in February 2015. In January of 2015 the Company entered into a new eleven year lease agreement for office space in Houston, Texas. The operating lease commences on March 1, 2015 and may be terminated after seven years. The minimum contractual obligations are approximately $25 million in the aggregate. We will amortize the total payments under the lease agreement on a straight-line basis over the term of the lease.
	Our remaining minimum annual obligations under non-cancelable operating lease commitments were $12.6 million for 2015, less than $0.1 million for 2016 and approximately $12.6 million in total. The remaining minimum annual obligations under non-cancelable operating lease commitments primarily relate to short-term compressor rental agreements.
	Our employment agreement liabilities for certain named executive officers, as detailed in our most recent proxy statement, constitute the majority of other long-term liabilities on the balance sheet at both December 31, 2014 and 2013.
	Our remaining gas transportation and processing minimum obligations were $12.7 million for 2015, $12.5 million for 2016, $10.1 million for 2017, $10.2 million for 2018, $8.7 million for 2019 and $61.6 million in the aggregate.
	In the ordinary course of business, we have been party to various legal actions, which arise primarily from our activities as operator of oil and natural gas wells. In management's opinion, the outcome of any such currently pending legal actions will not have a material adverse effect on our financial position or results of operations.

ShareBased_Compensation_ShareB

Share-Based Compensation Share-Based Compensation (Notes)	12 Months Ended
	Dec. 31, 2014
Share-based Compensation [Abstract]
Share-Based Compensation	Share-Based Compensation
	Share-Based Compensation Plans
	We have multiple share-based compensation plans with outstanding awards including the 2005 Stock Compensation Plan, most recently amended by our Board of Directors in May 2013, which was approved by shareholders at the 2005 annual meeting of shareholders; the 2001 Omnibus Stock Compensation Plan, which was adopted by our Board of Directors in February 2001 and was approved by shareholders at the 2001 annual meeting of shareholders; the 1990 Non-Qualified Stock Option Plan solely for our independent directors. No further grants will be made under the 2001 Omnibus Stock Compensation Plan or the 1990 Non-Qualified Stock Option Plan, both of which were replaced by the 2005 Stock Compensation Plan, although stock option awards remain outstanding under the plans and are accordingly included in the tables below. In addition, we have an employee stock purchase plan and an employee stock ownership plan. We follow guidance contained in FASB ASC 718 to account for share-based compensation.
	Under the 2005 plan, stock option awards and other equity based awards may be granted to employees, directors, and consultants, with directors only eligible to receive restricted awards. Under the 2001 plan, stock option awards and other equity based awards were granted to employees. Under the 1990 non-qualified plan, non-employee members of our Board of Directors were automatically granted stock option awards to purchase shares of common stock on a formula basis. All three plans provide that the exercise prices for stock option awards equal 100% of the fair value of the common stock on the date of grant. Restricted stock grants become vested over a three year period, and stock option awards become exercisable in various terms ranging from one year to five years. Stock option awards granted typically expire ten years after the date of grant or earlier in the event of the optionee's separation from employment. At the time the stock option awards are exercised, the cash received is credited to common stock and additional paid-in capital. The 2005 plan allows for the use of a “stock swap” in lieu of a cash exercise for stock option awards, under certain circumstances. The delivery of Swift Energy common stock, held by the optionee for a minimum of six months, which are considered mature shares, with a fair market value equal to the required purchase price of the shares to which the exercise relates, constitutes a valid “stock swap.” Stock option awards issued under a “stock swap” also previously included a reload feature that was discontinued during 2012. There were no mature shares that were delivered in “stock swap” transactions during 2014 while there were 10,752 and 20,692 for the years ended December 31, 2013 and 2012, respectively.
	The employee stock purchase plan, which began in 1993, provides eligible employees the opportunity to acquire shares of Swift Energy common stock at a discount through payroll deductions. To date, employees have been allowed to authorize payroll deductions of up to 10% of their base salary, within IRS limitations and plan rules, during the plan year by making an election to participate prior to the start of a plan year. The purchase price for stock acquired under the plan is 85% of the lower of the closing price of our common stock as quoted on the New York Stock Exchange at the beginning or end of the plan year. Under this plan for the last three years, we have issued 71,825 shares at a price of $11.47 in 2014, 72,273 shares at a price of $13.08 in 2013 and 42,624 shares at a price of $25.26 in 2012. The contributions for the years ended December 31, 2014, 2013 and 2012 were all made in common stock. As of December 31, 2014, 318,027 shares remained available for issuance under this plan.
	We receive a tax deduction for certain stock option exercises during the period the stock option awards are exercised, generally for the excess of the market value on the exercise date over the exercise price of the stock option awards. We receive an additional tax deduction when restricted stock awards vest at a higher value than the value used to recognize compensation expense at the date of grant. We are required to report excess tax benefits from the award of equity instruments as financing cash flows. We recognized an excess tax shortfall for the years ended December 31, 2014 and 2013, as referenced in Note 3 of these consolidated financial statements. We did not recognize any material excess tax benefit or shortfall in earnings for the year ended December 31, 2012.
	There were no stock option exercises for the year ended December 31, 2014. Net cash proceeds from the exercise of stock option awards were not material for the year ended December 31, 2013 and were $0.6 million for the year ended December 31, 2012. The actual income tax benefit from stock option exercises was $0.3 million for the year ended December 31, 2012.
	Share-based compensation expense awards to both employees and non-employees, which was recorded in “General and administrative, net” in the accompanying consolidated statements of operations, was $6.7 million, $9.3 million and $12.9 million for the years ended December 31, 2014, 2013 and 2012, respectively. Share-based compensation recorded in lease operating cost was $0.2 million for the year ended December 31, 2014 and $0.3 million for the years ended December 31, 2013 and 2012, respectively. We also capitalized $3.5 million, $5.5 million and $5.2 million of share-based compensation for the years ended December 31, 2014, 2013 and 2012, respectively. We view stock option awards and restricted stock awards with graded vesting as single awards with an expected life equal to the average expected life of component awards and amortize the awards on a straight-line basis over the life of the awards.
	Our shares available for future grant under our Share-Based Compensation plans were 1,814,928 at December 31, 2014. Each stock option award granted reduces the aforementioned total by 1.0 share, while each restricted stock award and restricted stock unit granted reduces the shares available for future grant by 1.44 shares.
	Stock Option Awards
	We use the Black-Scholes-Merton option pricing model to estimate the fair value of stock option awards with the following weighted-average assumptions for stock option awards issued during the indicated periods:
		Twelve Months Ended
		December 31,
		2012
	Dividend yield	0%
	Expected volatility	61.20%
	Risk-free interest rate	0.80%
	Expected life of stock option awards (in years)	4.3
	Weighted-average grant-date fair value	$15.71
	During the years ended December 31, 2014 and 2013, we did not grant any stock option awards. The expected term for grants issued considers all relevant factors including historical and expected future employee exercise behavior. We have analyzed historical volatility and, based on an analysis of all relevant factors, we have used a 5.5 year look-back period to estimate expected volatility of our stock option awards.
	At December 31, 2014, we had $0.1 million of unrecognized compensation cost related to stock option awards, which is expected to be recognized over a weighted-average period of 0.1 years. The following table represents stock option award activity for the year ended December 31, 2014:
		2014
		Shares		Wtd. Avg.
				Exer. Price
	Options outstanding, beginning of period	1,488,314		$	33.38
	Options granted	—		$	—
	Options canceled	(156,124	)	$	27.68
	Options exercised	—		$	—
	Options outstanding, end of period	1,332,190		$	34.02
	Options exercisable, end of period	1,230,019		$	34.14
	Our outstanding and exercisable stock option awards at December 31, 2014 had no intrinsic value since all outstanding stock option awards were out of the money. The weighted average remaining contract life of stock option awards outstanding and exercisable at December 31, 2014 was 4.7 years and 4.5 years, respectively. The total intrinsic value of stock option awards exercised for the years ended December 31, 2014 and 2013 was not material and was $0.9 million for the year ended December 31, 2012.
	The following table summarizes information about stock option awards outstanding at December 31, 2014:
			Options Outstanding					Options Exercisable
	Range of Exercise Prices		Number Outstanding at 12/31/14		Wtd. Avg. Remaining Contractual Life	Wtd. Avg. Exercise Price		Number Exercisable at 12/31/14	Wtd. Avg. Exercise Price
	$8.00 to $24.99		380,080		4.6	$	19.91	380,080	$	19.91
	$25.00 to $45.00		952,110		4.8	$	39.66	849,939	$	40.5
	$8.00 to $45.00		1,332,190		4.7	$	34.02	1,230,019	$	34.14
	Restricted Stock Awards
	For the years ended December 31, 2014, 2013 and 2012, the Company issued 747,400, 869,430 and 543,800 shares, respectively, of restricted stock to employees, consultants, and directors. These shares vest over three years and remain subject to forfeiture if vesting conditions are not met. The weighted average fair values of these shares when issued, for the years ended December 31, 2014, 2013 and 2012 were $11.55, $14.86 and $31.12 per share, respectively.
	The compensation expense for these awards was determined based on the closing market price of our stock at the date of grant applied to the total number of shares that were anticipated to fully vest. As of December 31, 2014, we had unrecognized compensation expense of $9.6 million related to restricted stock awards which is expected to be recognized over a weighted-average period of 1.5 years. The grant date fair values of shares vested for the years ended December 31, 2014, 2013 and 2012 were $11.8 million, $12.8 million and $10.0 million, respectively.
	The following table represents restricted stock award activity for the year ended December 31, 2014:
		2014
		Shares		Wtd. Avg.
				Grant Price
	Restricted shares outstanding, beginning of period	1,267,110		$	21.54
	Restricted shares granted	747,400		$	11.55
	Restricted shares canceled	(208,206	)	$	15.3
	Restricted shares vested	(392,292	)	$	30.09
	Restricted shares outstanding, end of period	1,414,012		$	14.81
	Performance-Based Restricted Stock Units
	For the years ended December 31, 2014 and 2013, the Company granted 185,250 and 189,700 of performance-based restricted stock units, respectively. These units contained predetermined market and performance conditions set by our compensation committee with a performance period of 3 years and a cliff vesting period of 3.1 years. The Target payout is 100% of the units granted while the conditions of the grants allow for a payout ranging between no payout and 200% of target.
	The compensation expense for the market condition is based on the per unit grant date valuation using a Monte-Carlo simulation. The performance condition is remeasured quarterly and compensation expense is recorded based on the closing market price of our stock per unit on the grant date multiplied by the expected payout level. The payout level is calculated based on actual performance achieved during the performance period compared to a defined peer group.
	As of December 31, 2014, we had unrecognized compensation expense of $2.2 million related to our restricted stock units which is expected to be recognized over a weighted-average period of 1.8 years. No shares vested during the years ended December 31, 2014 and 2013. The weighted average grant date fair value for the restricted stock units granted during the years ended December 31, 2014 and 2013 was $11.68 and $15.01 per unit, respectively.
	The following table represents restricted stock unit activity for the year ended December 31, 2014:
		Shares		Wtd. Avg.
				Grant Price
	Restricted stock units outstanding, beginning of period	189,700		$	15.01
	Restricted stock units granted	185,250		$	11.68
	Restricted stock units canceled	—		$	—
	Restricted stock units vested	—		$	—
	Restricted stock units outstanding, end of period	374,950		$	13.36
	Employee Stock Ownership Plan
	We established an Employee Stock Ownership Plan (“ESOP”) effective January 1, 1996. All employees over the age of 21 with one year of service are participants. This plan has a three-year cliff vesting requirement. The ESOP is designed to enable our employees to accumulate stock ownership. While employees do not contribute to the plan, contributions made by Swift energy provide participants with an allocation of stock within the plan. The plan may also acquire Swift Energy common stock, purchased at fair market value. The ESOP can borrow money from Swift Energy to buy Swift Energy common stock. ESOP payouts will be paid in a lump sum or installments, and the participants generally have the choice of receiving cash or stock. No contributions will be made by Swift Energy for the year ended December 31, 2014. Our contribution to the ESOP plan totaled $0.2 million for the years ended December 31, 2013 and 2012, were all made in common stock, from treasury shares, and are recorded as “General and administrative, net” on the accompanying consolidated statements of operations. The shares of common stock contributed to the ESOP plan, from treasury shares, totaled 14,815 and 12,995 for the years ended December 31, 2013 and 2012, respectively.
	Employee Savings Plan
We have a savings plan under Section 401(k) of the Internal Revenue Code. In 2013 this plan was updated so that eligible employees may make voluntary contributions into the 401(k) savings plan with Swift Energy contributing on behalf of the eligible employee an amount equal to 100% of the first 6% of compensation based on the contributions made by the eligible employees. Our contributions to the 401(k) savings plan were $1.8 million for the years ended December 31, 2014 and 2013, respectively, and were $1.5 million for the year ended December 31, 2012. These amounts were recorded as “General and administrative, net” on the accompanying consolidated statements of operations. The 2014 plan contributions were made with a combination of $0.9 million of cash and 352,476 shares of common stock, from treasury shares, while the 2013 and 2012 plan contributions were all made in common stock, from treasury shares. The shares of common stock contributed to the 401(k) savings plan totaled 139,850 and 91,895 for the years ended December 31, 2013 and 2012, respectively.

Related_Party_Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2014
Related Party Transactions [Abstract]
Related Party Transactions	Related-Party Transactions
	We receive research, technical writing, publishing, and website-related services from Tec-Com Inc., a corporation located in Knoxville, Tennessee and controlled and majority owned by the aunt of the Company's Chairman of the Board and Chief Executive Officer. We paid Tec-Com, for services pursuant to the terms of the contract, approximately $0.6 million in 2014, 2013 and 2012. The contract was renewed on July 1, 2014 on substantially the same terms as the previous contract and expires June 30, 2015.
	As a matter of corporate governance policy and practice, related party transactions are annually presented and considered by the Corporate Governance Committee of our Board of Directors in accordance with the Committee's charter.

Acquisitions_and_Dispositions

Acquisitions and Dispositions	12 Months Ended
	Dec. 31, 2014
Business Combinations [Abstract]
Acquisitions and Dispositions	Acquisitions and Dispositions
	On July 15, 2014, we closed our transaction with Saka Energi to fully develop 8,300 acres of Fasken area Eagle Ford shale properties owned by Swift Energy in Webb County, Texas, with an effective date of January 1, 2014. Swift Energy sold a 36% full participating interest in the Fasken properties to Saka Energi for $175 million in total cash consideration, with $125 million paid at closing (subject to adjustments for the interim period between the effective date and the closing date) and $50 million in cash to be paid by Saka Energi over time to carry a portion of Swift Energy's field development costs incurred after the effective date. As of December 31, 2014, approximately $29 million remained of Saka Energi's original $50 million carry obligation. At closing, the company received approximately $147 million in proceeds, including a $12.5 million deposit received during the prior quarter which was held in an escrow account until the closing date, as well as adjustments for the interim period between the effective date and the closing date. The proceeds initially were used to reduce our outstanding borrowings on our credit facility which were partially offset by additional borrowings against the credit facility during the second half of the year to fund development expenditures. No gain or loss was recognized for the transaction as the proceeds were applied to the full cost pool.
	There were no material acquisitions in 2014, 2013 or 2012.

Fair_Value_Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements
	FASB ASC 820-10 defines fair value, establishes guidelines for measuring fair value and expands disclosure about fair value measurements. It does not create or modify any current GAAP requirements to apply fair value accounting. However, it provides a single definition for fair value that is to be applied consistently for all prior accounting pronouncements.
	Our financial instruments consist of cash and cash equivalents, accounts receivable, accounts payable, bank borrowings, and senior notes. The carrying amounts of cash and cash equivalents, accounts receivable, and accounts payable approximate fair value due to the highly liquid or short-term nature of these instruments.
	Based upon quoted market prices as of December 31, 2014, 2013 and 2012, the fair value and carrying value of our senior notes was as follows (in millions):
		December 31, 2014				December 31, 2013				December 31, 2012
		Fair Value		Carrying Value		Fair Value		Carrying Value		Fair Value		Carrying Value
	7.125% senior notes due in 2017	$	153	$	250	$	256.7	$	250	$	258.1	$	250
	8.875% senior notes due in 2020	$	133.1	$	222.8	$	239.1	$	222.4	$	244.4	$	221.1
	7.875% senior notes due in 2022	$	198	$	404.5	$	409	$	404.9	$	424	$	405.4
	Our senior notes due in 2017, 2020 and 2022 are stated at carrying value on our financial statements, net of any discount or premium. If we recorded these notes at fair value they would be Level 1 in our fair value hierarchy as they are traded in an active market with quoted prices for identical instruments.
	The following table presents our assets that are measured at fair value as of December 31, 2014 and 2013, and are categorized using the fair value hierarchy. For additional discussion related to the fair value of the Company's derivatives, refer to Note 1 of these consolidated financial statements. The fair value hierarchy has three levels based on the reliability of the inputs used to determine the fair value (in millions):
		Fair Value Measurements at
		Total		Quoted Prices in		Significant Other		Significant
				Active markets for		Observable Inputs		Unobservable
				Identical Assets		(Level 2)		Inputs
				(Level 1)				(Level 3)
	December 31, 2014
	Assets
	Natural Gas Derivatives	$	2.4	$	—	$	2.4	$	—
	Natural Gas Basis Derivatives	$	0.1	$	—	$	0.1	$	—
	Liabilities
	Natural Gas Basis Derivatives	$	0.1	$	—	$	0.1	$	—
	31-Dec-13
	Assets
	Natural Gas Derivatives	$	0.5	$	—	$	0.5	$	—
	Oil Derivatives	$	0.3	$	—	$	0.3	$	—
	Liabilities
	Natural Gas Derivatives	$	0.7	$	—	$	0.7	$	—
	Oil Derivatives	$	0.2	$	—	$	0.2	$	—
	Our derivative assets and liabilities in the table above are measured at gross fair value and are shown on the accompanying consolidated balance sheets in “Other current assets” and "Accounts payable and accrued liabilities", respectively.
	Level 1 – Uses quoted prices in active markets for identical, unrestricted assets or liabilities. Instruments in this category have comparable fair values for identical instruments in active markets.
	Level 2 – Uses quoted prices for similar assets or liabilities in active markets or observable inputs for assets or liabilities in non-active markets. Instruments in this category are periodically verified against quotes from brokers and include our commodity derivatives that we value using commonly accepted industry-standard models which contain inputs such as contract prices, risk-free rates, volatility measurements and other observable market data that are obtained from independent third-party sources.
	Level 3 – Uses unobservable inputs for assets or liabilities that are in non-active markets. We do not have any assets or liabilities in this category.

Condensed_Consolidating_Financ

Condensed Consolidating Financial Information (Notes)	12 Months Ended
	Dec. 31, 2014
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed Financial Information of Parent Company Only Disclosure	Condensed Consolidating Financial Information
	Swift Energy Company (the parent) is the issuer and Swift Energy Operating, LLC (a wholly owned indirect subsidiary of Swift Energy Company) is the sole guarantor of our senior notes due in 2017, 2020 and 2022. Swift Energy Company does not have any independent assets or operations. The guarantees on our senior notes due in 2017, 2020 and 2022 are full and unconditional. All subsidiaries of Swift Energy Company, other than Swift Energy Operating, LLC, are minor.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation. The accompanying consolidated financial statements include the accounts of Swift Energy and its wholly owned subsidiaries, which are engaged in the exploration, development, acquisition, and operation of oil and gas properties, with a focus on inland waters and onshore oil and natural gas reserves in Louisiana and Texas. Our undivided interests in oil and gas properties are accounted for using the proportionate consolidation method, whereby our proportionate share of each entity’s assets, liabilities, revenues, and expenses are included in the appropriate classifications in the accompanying consolidated financial statements. Intercompany balances and transactions have been eliminated in preparing the accompanying consolidated financial statements.
Subsequent Events	Subsequent Events. We have evaluated subsequent events of our consolidated financial statements. In January of 2015 the company entered into a new lease agreement for office space in Houston, Texas. For additional discussion regarding the term and obligations of this lease refer to Note 5 of these consolidated financial statements. There were no other material subsequent events requiring additional disclosure in these financial statements.
Use of Estimates	Use of Estimates. The preparation of financial statements in conformity with accounting principles generally accepted in the United States (“GAAP”) requires us to make estimates and assumptions that affect the reported amounts of certain assets and liabilities and the reported amounts of certain revenues and expenses during each reporting period. We believe our estimates and assumptions are reasonable; however, such estimates and assumptions are subject to a number of risks and uncertainties that may cause actual results to differ materially from such estimates. Significant estimates and assumptions underlying these financial statements include:
	•	the estimated quantities of proved oil and natural gas reserves used to compute depletion of oil and natural gas properties and the related present value of estimated future net cash flows there-from,
	•	estimates related to the collectability of accounts receivable and the credit worthiness of our customers,
	•	estimates of the counterparty bank risk related to letters of credit that our customers may have issued on our behalf,
	•	estimates of future costs to develop and produce reserves,
	•	accruals related to oil and gas sales, capital expenditures and lease operating expenses,
	•	estimates of insurance recoveries related to property damage, and the solvency of insurance providers,
	•	estimates in the calculation of share-based compensation expense,
	•	estimates of our ownership in properties prior to final division of interest determination,
	•	the estimated future cost and timing of asset retirement obligations,
	•	estimates made in our income tax calculations,
	•	estimates in the calculation of the fair value of hedging assets and liabilities, and
	•	estimates in the assessment of current litigation claims against the company.
	While we are not aware of any material revisions to any of our estimates, there will likely be future revisions to our estimates resulting from matters such as new accounting pronouncements, changes in ownership interests, payouts, joint venture audits, re-allocations by purchasers or pipelines, or other corrections and adjustments common in the oil and gas industry, many of which require retroactive application. These types of adjustments cannot be currently estimated and will be recorded in the period during which the adjustments occur.
Property and Equipment	Property and Equipment. We follow the “full-cost” method of accounting for oil and natural gas property and equipment costs. Under this method of accounting, all productive and nonproductive costs incurred in the exploration, development, and acquisition of oil and natural gas reserves are capitalized. Such costs may be incurred both prior to and after the acquisition of a property and include lease acquisitions, geological and geophysical services, drilling, completion, and equipment. Internal costs incurred that are directly identified with exploration, development, and acquisition activities undertaken by us for our own account, and which are not related to production, general corporate overhead, or similar activities, are also capitalized. For the years ended December 31, 2014, 2013 and 2012, such internal costs capitalized totaled $26.3 million, $31.8 million and $31.1 million, respectively. Interest costs are also capitalized to unproved oil and natural gas properties (refer to Note 4 of these consolidated financial statements for further discussion on capitalized interest costs).
	The “Property and Equipment” balances on the accompanying consolidated balance sheets are summarized for presentation purposes. The following is a detailed breakout of our “Property and Equipment” balances.
	(in thousands)	December 31,			December 31,
		2014			2013
	Property and Equipment
	Proved oil and gas properties	$	5,826,995		$	5,600,279
	Unproved oil and gas properties	64,903			71,452
	Furniture, fixtures, and other equipment	42,257			42,368
	Less – Accumulated depreciation, depletion, and amortization	(3,839,118		)	(3,125,282		)
	Property and Equipment, Net	$	2,095,037		$	2,588,817
	No gains or losses are recognized upon the sale or disposition of oil and natural gas properties, except in transactions involving a significant amount of reserves or where the proceeds from the sale of oil and natural gas properties would significantly alter the relationship between capitalized costs and proved reserves of oil and natural gas attributable to a cost center. Internal costs associated with selling properties are expensed as incurred.
	Future development costs are estimated property-by-property based on current economic conditions and are amortized to expense as our capitalized oil and gas property costs are amortized.
	We compute the provision for depreciation, depletion, and amortization (“DD&A”) of oil and natural gas properties using the unit-of-production method. Under this method, we compute the provision by multiplying the total unamortized costs of oil and gas properties—including future development costs, gas processing facilities, and both capitalized asset retirement obligations and undiscounted abandonment costs of wells to be drilled, net of salvage values, but excluding costs of unproved properties—by an overall rate determined by dividing the physical units of oil and natural gas produced (which excludes natural gas consumed in operations) during the period by the total estimated units of proved oil and natural gas reserves (which excludes natural gas consumed in operations) at the beginning of the period. This calculation is done on a country-by-country basis and the period over which we will amortize these properties is dependent on our production from these properties in future years. Furniture, fixtures, and other equipment are recorded at cost and are depreciated by the straight-line method at rates based on the estimated useful lives of the property, which range between two and 20 years. Repairs and maintenance are charged to expense as incurred. Renewals and betterments are capitalized.
	Geological and geophysical (“G&G”) costs incurred on developed properties are recorded in “Proved properties” and therefore subject to amortization. G&G costs incurred that are directly associated with specific unproved properties are capitalized in “Unproved properties” and evaluated as part of the total capitalized costs associated with a prospect. The cost of unproved properties not being amortized is assessed quarterly, on a property-by-property basis, to determine whether such properties have been impaired. In determining whether such costs should be impaired, we evaluate current drilling results, lease expiration dates, current oil and gas industry conditions, international economic conditions, capital availability, and available geological and geophysical information. Any impairment assessed is added to the cost of proved properties being amortized.
Full-Cost Ceiling Test	Full-Cost Ceiling Test. At the end of each quarterly reporting period, the unamortized cost of oil and natural gas properties (including natural gas processing facilities, capitalized asset retirement obligations, net of related salvage values and deferred income taxes, and excluding the recognized asset retirement obligation liability) is limited to the sum of the estimated future net revenues from proved properties (excluding cash outflows from recognized asset retirement obligations, including future development and abandonment costs of wells to be drilled, using the preceding 12-months’ average price based on closing prices on the first day of each month, adjusted for price differentials, discounted at 10%, and the lower of cost or fair value of unproved properties) adjusted for related income tax effects (“Ceiling Test”). This calculation is done on a country-by-country basis.
	The calculations of the Ceiling Test and provision for DD&A are based on estimates of proved reserves. There are numerous uncertainties inherent in estimating quantities of proved reserves and in projecting the future rates of production, timing, and plan of development. The accuracy of any reserves estimate is a function of the quality of available data and of engineering and geological interpretation and judgment. Results of drilling, testing, and production subsequent to the date of the estimate may justify revision of such estimates. Accordingly, reserves estimates are often different from the quantities of oil and natural gas that are ultimately recovered.
	Due to the effects of pricing, timing of projects and changes in our reserves product mix, in 2014 and 2013 we reported non-cash write-downs on a before-tax basis of $445.4 million and $46.9 million, respectively, on our oil and natural gas properties.
	If future capital expenditures out pace future discounted net cash flows in our reserve calculations, if we have significant declines in our oil and natural gas reserves volumes (which also reduces our estimate of discounted future net cash flows from proved oil and natural gas reserves) or if oil or natural gas prices decline, non-cash write-downs of our oil and natural gas properties could occur in the future. We cannot control and cannot predict what future prices for oil and natural gas will be, thus we cannot estimate the amount or timing of any potential future non-cash write-down of our oil and natural gas properties due to decreases in oil or natural gas prices.
Revenue Recognition	Revenue Recognition. Oil and gas revenues are recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred, and if collectability of the revenue is probable. Swift Energy uses the entitlement method of accounting in which we recognize our ownership interest in production as revenue. If our sales exceed our ownership share of production, the natural gas balancing payables are reported in “Accounts payable and accrued liabilities” on the accompanying consolidated balance sheets. Natural gas balancing receivables are reported in “Other current assets” on the accompanying consolidated balance sheets when our ownership share of production exceeds sales. As of December 31, 2014 and 2013, we did not have any material natural gas imbalances.
Reclassification of Prior Period Balances	Reclassification of Prior Period Balances. Certain reclassifications have been made to prior period amounts to conform to the current-year presentation.
Accounts Receivable	Accounts Receivable. We assess the collectability of accounts receivable, and based on our judgment, we accrue a reserve when we believe a receivable may not be collected. At December 31, 2014 and 2013, we had an allowance for doubtful accounts of approximately $0.1 million, respectively. The allowance for doubtful accounts has been deducted from the total “Accounts receivable” balance on the accompanying consolidated balance sheets.
	At December 31, 2014, our “Accounts receivable” balance included $34.8 million for oil and gas sales, $8.4 million for joint interest owners, $3.1 million for severance tax credit receivables and $2.2 million for other receivables. At December 31, 2013, our “Accounts receivable” balance included $56.9 million for oil and gas sales, $1.6 million for joint interest owners, $11.6 million for severance tax credit receivables and $0.8 million for other receivables.
Debt Issuance Costs	Debt Issuance Costs. Legal fees, accounting fees, underwriting fees, printing costs, and other direct expenses associated with extensions of our senior notes were capitalized and are amortized on an effective interest basis over the life of each of the respective senior note offerings.
	The 7.125% senior notes due in 2017 mature on June 1, 2017, and the remaining balance of their issuance costs at December 31, 2014, was $1.3 million. The 8.875% senior notes due in 2020 mature on January 15, 2020, and the remaining balance of their issuance costs at December 31, 2014, was $3.1 million. The 7.875% senior notes due in 2022 mature on March 1, 2022, and the balance of their remaining issuance costs at December 31, 2014, was $5.9 million. The remaining balance of revolving credit facility issuance costs at December 31, 2014, was $2.3 million.
Price-Risk Management Activities	Price-Risk Management Activities. The Company follows FASB ASC 815-10, which requires that changes in the derivative’s fair value are recognized currently in earnings unless specific hedge accounting criteria are met. The guidance also establishes accounting and reporting standards requiring that every derivative instrument (including certain derivative instruments embedded in other contracts) is recorded in the consolidated balance sheets as either an asset or a liability measured at its fair value. Hedge accounting for a qualifying hedge allows the gains and losses on derivatives to offset related results on the hedged item in the statement of operations and requires that a company formally document, designate, and assess the effectiveness of transactions that receive hedge accounting.
	Prior to January 1, 2013, the Company had elected hedge accounting on all qualifying derivative instruments. As of December 31, 2012, the Company did not have any outstanding derivatives. For all derivatives entered into after January 1, 2013, the Company elected not to apply hedge accounting. The changes in the fair value of our derivatives initiated after January 1, 2013 are recognized in "Price-risk management and other, net” on the accompanying consolidated statements of operations.
	We have a price-risk management policy to use derivative instruments to protect against declines in oil and natural gas prices, mainly through the purchase of price floors, calls, swaps, collars and participating collars. Prior to January 1, 2013, all hedges were designated as a hedge of the variability in cash flows associated with the forecasted sale of oil and natural gas production. Changes in the fair value of a hedge that was highly effective and was designated, documented and qualified as a cash flow hedge, to the extent that the hedge was effective, were recorded in “Accumulated other comprehensive income, net of income tax” on the balance sheet. When the hedged transactions were recorded upon the actual sale of the oil and natural gas, those gains or losses were reclassified from “Accumulated other comprehensive income, net of income tax” and were recorded in “Price-risk management and other, net” on the accompanying consolidated statements of operations. Changes in the fair value of derivatives that did not meet the criteria for hedge accounting, and the ineffective portion of the hedge for which hedge accounting was elected, were recognized in "Price-risk management and other, net."
Supervision Fees	Supervision Fees. Consistent with industry practice, we charge a supervision fee to the wells we operate including our wells in which we own up to a 100% working interest. Supervision fees are recorded as a reduction to “General and administrative, net”, on the accompanying consolidated statements of operations. Our supervision fees are based on COPAS industry guidelines. The amount of supervision fees charged for the years ended December 31, 2014, 2013 and 2012, respectively, did not exceed our actual costs incurred. The total amount of supervision fees charged to the wells we operated was $12.7 million, $11.6 million and $11.3 million for the years ended December 31, 2014, 2013 and 2012, respectively.
Inventories	Other Current Assets. Included in "Other current assets" on the accompanying consolidated balance sheets are inventories which consist primarily of tubulars and other equipment and supplies that we expect to place in service in production operations. Our inventories are recorded at cost (weighted average method) and totaled $3.1 million and $3.5 million at December 31, 2014 and 2013, respectively.
Income Taxes	Income Taxes. Under guidance contained in FASB ASC 740-10, deferred taxes are determined based on the estimated future tax effects of differences between the financial statement and tax basis of assets and liabilities, given the provisions of the enacted tax laws.
	We follow the recognition and disclosure provisions under guidance contained in FASB ASC 740-10-25. Under this guidance, tax positions are evaluated for recognition using a more-likely-than-not threshold, and those tax positions requiring recognition are measured as the largest amount of tax benefit that is greater than fifty percent likely of being realized upon ultimate settlement with a taxing authority that has full knowledge of all relevant information. Our policy is to record interest and penalties relating to uncertain tax positions in income tax expense.
Accounts Payable and Accrued Liabilities	Accounts Payable and Accrued Liabilities. The “Accounts payable and accrued liabilities” balances on the accompanying consolidated balance sheets are summarized below (in thousands):
		December 31,			December 31,
		2014			2013
	Trade accounts payable (1)	$	31,153		$	30,769
	Accrued operating expenses	10,784			16,016
	Accrued payroll costs	8,100			10,938
	Asset retirement obligations – current portion	10,709			15,859
	Accrued taxes	2,957			5,845
	Other payables	4,541			2,891
	Total accounts payable and accrued liabilities	$	68,244		$	82,318
	(1) Included in “trade accounts payable” are liabilities of approximately $13.7 million and $26.1 million at December 31, 2014 and 2013, respectively, for outstanding checks.
Cash and Cash Equivalents	Cash and Cash Equivalents. We consider all highly liquid instruments with an initial maturity of three months or less to be cash equivalents.
Credit Risk Due To Certain Concentrations	Credit Risk Due to Certain Concentrations. We extend credit, primarily in the form of uncollateralized oil and gas sales and joint interest owners' receivables, to various companies in the oil and gas industry, which results in a concentration of credit risk. The concentration of credit risk may be affected by changes in economic or other conditions within our industry and may accordingly impact our overall credit risk. However, we believe that the risk of these unsecured receivables is mitigated by the size, reputation, and nature of the companies to which we extend credit. From certain customers we also obtain letters of credit or parent company guarantees, if applicable, to reduce risk of loss. For the years ended December 31, 2014, 2013 and 2012, Shell Oil Company and affiliates accounted for 21%, 33% and 46% of our total oil and gas gross receipts, respectively. Kinder Morgan and Plains Marketing accounted for approximately 20% and 11% of our total oil and gas gross receipts in 2014, respectively. BP America accounted for approximately 21% of our total oil and gas gross receipts in 2013 while Southcross Energy accounted for approximately 11% of our total oil and gas gross receipts in 2012. Credit losses in each of the last three years were immaterial.
Restricted Cash	Short-Term Restricted Cash (Saka Energi Transaction). On July 15, 2014, we closed our transaction with PT Saka Energi Indonesia ("Saka Energi") to fully develop 8,300 acres of Fasken area Eagle Ford shale properties owned by Swift Energy in Webb County, Texas. Swift Energy sold a 36% full participating interest in the Fasken properties to Saka Energi.
	Subject to the terms of the transaction, Swift Energy and Saka Energi were depositing cash on a monthly basis into a separate Swift Energy-owned bank account to fund their respective portions of the on-going Fasken development program for the following month. All cash deposited in the account was contractually restricted for use in the Fasken development program and therefore was recorded as restricted cash until the Company performed the related development activities. During the fourth quarter of 2014 this cash requirement process was discontinued and all unused amounts were refunded.
	During the year Saka Energi deposited $29.8 million into the account, from which $7.1 million was withdrawn from the account in order to fund on-going development operations in the Fasken area, while the remainder was refunded to Saka upon discontinuance of the cash requirement process noted above. The cash changes from the account relating to Saka Energi’s contributions are shown in the operating activities section of the accompanying consolidated statements of cash flows. The cash changes from the account relating to Swift Energy’s contributions are reported in the investing activities section on the accompanying consolidated statements of cash flows.
	Long-Term Restricted Cash. These balances primarily include amounts held in escrow accounts to satisfy plugging and abandonment obligations. As of December 31, 2014 and 2013, these assets were approximately $1.0 million. These amounts are restricted as to their current use, and will be released when we have satisfied all plugging and abandonment obligations in certain fields. Restricted cash balances are reported in “Other Long-Term Assets” on the accompanying consolidated balance sheets.
Asset Retirement Obligation	Asset Retirement Obligations. We record these obligations in accordance with the guidance contained in FASB ASC 410-20. This guidance requires entities to record the fair value of a liability for legal obligations associated with the retirement obligations of tangible long-lived assets in the period in which it is incurred. When the liability is initially recorded, the carrying amount of the related long-lived asset is increased. The liability is discounted from the expected date of abandonment. Over time, accretion of the liability is recognized each period, and the capitalized cost is depreciated on a unit-of-production basis as part of depreciation, depletion, and amortization expense for our oil and gas properties. Upon settlement of the liability, the Company either settles the obligation for its recorded amount or incurs a gain or loss upon settlement which is included in the “Property and Equipment” balance on our accompanying consolidated balance sheets. This guidance requires us to record a liability for the fair value of our dismantlement and abandonment costs, excluding salvage values.
New Accounting Pronouncements	New Accounting Pronouncements. In May 2014, the FASB issued ASU 2014-09, providing a comprehensive revenue recognition standard for contracts with customers that supersedes current revenue recognition guidance. The guidance is effective for annual and interim reporting periods beginning after December 15, 2016 and upon adoption, entities are required to recognize revenue using the following five-step model: identify the contract with a customer, identify the performance obligations in the contract, determine the transaction price, allocate the transaction price to the performance obligations in the contract, and recognize revenue as the entity satisfies each performance obligation. Adoption of this standard could result in retrospective application, either in the form of recasting all prior periods presented or a cumulative adjustment to equity in the period of adoption. We are currently reviewing the new requirements to determine the impact of this guidance on our financial statements.

Earnings_Per_Share_Earning_Per

Earnings Per Share Earning Per Share (Policies)	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Earnings Per Share	Earnings Per Share
	The Company computes earnings per share in accordance with FASB ASC 260-10. Basic earnings per share (“Basic EPS”) has been computed using the weighted average number of common shares outstanding during each period. Diluted earnings per share ("Diluted EPS") assumes, as of the beginning of the period, exercise of stock options and restricted stock grants using the treasury stock method. Diluted EPS also assumes conversion of performance-based restricted stock units to common shares based on the number of shares (if any) that would be issuable, according to predetermined performance and market goals, if the end of the reporting period was the end of the performance period. As we recognized a net loss for the years ended December 31, 2014 and 2013, the unvested share-based payments and stock options were not recognized in diluted earnings per share (“Diluted EPS”) calculations as they would be antidilutive. Certain of our stock options and restricted stock grants that would potentially dilute Basic EPS in the future were also antidilutive for the year ended December 31, 2012, and are discussed below.

Commitments_and_Contingencies_

Commitments and Contingencies Commitments and Contingencies (Policies)	12 Months Ended
	Dec. 31, 2014
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies
	Rental and lease expenses were $21.0 million, $20.5 million and $19.9 million for the years ended December 31, 2014, 2013 and 2012, respectively. The rental and lease expenses primarily relate to compressor rentals during the year and the lease of our office space in Houston, Texas, which was set to expire in February 2015. In January of 2015 the Company entered into a new eleven year lease agreement for office space in Houston, Texas. The operating lease commences on March 1, 2015 and may be terminated after seven years. The minimum contractual obligations are approximately $25 million in the aggregate. We will amortize the total payments under the lease agreement on a straight-line basis over the term of the lease.
	Our remaining minimum annual obligations under non-cancelable operating lease commitments were $12.6 million for 2015, less than $0.1 million for 2016 and approximately $12.6 million in total. The remaining minimum annual obligations under non-cancelable operating lease commitments primarily relate to short-term compressor rental agreements.
	Our employment agreement liabilities for certain named executive officers, as detailed in our most recent proxy statement, constitute the majority of other long-term liabilities on the balance sheet at both December 31, 2014 and 2013.
	Our remaining gas transportation and processing minimum obligations were $12.7 million for 2015, $12.5 million for 2016, $10.1 million for 2017, $10.2 million for 2018, $8.7 million for 2019 and $61.6 million in the aggregate.
	In the ordinary course of business, we have been party to various legal actions, which arise primarily from our activities as operator of oil and natural gas wells. In management's opinion, the outcome of any such currently pending legal actions will not have a material adverse effect on our financial position or results of operations.

ShareBased_Compensation_ShareB1

Share-Based Compensation Share-Based Compensation (Policies)	12 Months Ended
	Dec. 31, 2014
Share-based Compensation [Abstract]
Share-based Compensation	Share-Based Compensation
	Share-Based Compensation Plans
	We have multiple share-based compensation plans with outstanding awards including the 2005 Stock Compensation Plan, most recently amended by our Board of Directors in May 2013, which was approved by shareholders at the 2005 annual meeting of shareholders; the 2001 Omnibus Stock Compensation Plan, which was adopted by our Board of Directors in February 2001 and was approved by shareholders at the 2001 annual meeting of shareholders; the 1990 Non-Qualified Stock Option Plan solely for our independent directors. No further grants will be made under the 2001 Omnibus Stock Compensation Plan or the 1990 Non-Qualified Stock Option Plan, both of which were replaced by the 2005 Stock Compensation Plan, although stock option awards remain outstanding under the plans and are accordingly included in the tables below. In addition, we have an employee stock purchase plan and an employee stock ownership plan. We follow guidance contained in FASB ASC 718 to account for share-based compensation.
	Under the 2005 plan, stock option awards and other equity based awards may be granted to employees, directors, and consultants, with directors only eligible to receive restricted awards. Under the 2001 plan, stock option awards and other equity based awards were granted to employees. Under the 1990 non-qualified plan, non-employee members of our Board of Directors were automatically granted stock option awards to purchase shares of common stock on a formula basis. All three plans provide that the exercise prices for stock option awards equal 100% of the fair value of the common stock on the date of grant. Restricted stock grants become vested over a three year period, and stock option awards become exercisable in various terms ranging from one year to five years. Stock option awards granted typically expire ten years after the date of grant or earlier in the event of the optionee's separation from employment. At the time the stock option awards are exercised, the cash received is credited to common stock and additional paid-in capital. The 2005 plan allows for the use of a “stock swap” in lieu of a cash exercise for stock option awards, under certain circumstances. The delivery of Swift Energy common stock, held by the optionee for a minimum of six months, which are considered mature shares, with a fair market value equal to the required purchase price of the shares to which the exercise relates, constitutes a valid “stock swap.” Stock option awards issued under a “stock swap” also previously included a reload feature that was discontinued during 2012. There were no mature shares that were delivered in “stock swap” transactions during 2014 while there were 10,752 and 20,692 for the years ended December 31, 2013 and 2012, respectively.
	The employee stock purchase plan, which began in 1993, provides eligible employees the opportunity to acquire shares of Swift Energy common stock at a discount through payroll deductions. To date, employees have been allowed to authorize payroll deductions of up to 10% of their base salary, within IRS limitations and plan rules, during the plan year by making an election to participate prior to the start of a plan year. The purchase price for stock acquired under the plan is 85% of the lower of the closing price of our common stock as quoted on the New York Stock Exchange at the beginning or end of the plan year. Under this plan for the last three years, we have issued 71,825 shares at a price of $11.47 in 2014, 72,273 shares at a price of $13.08 in 2013 and 42,624 shares at a price of $25.26 in 2012. The contributions for the years ended December 31, 2014, 2013 and 2012 were all made in common stock. As of December 31, 2014, 318,027 shares remained available for issuance under this plan.
	We receive a tax deduction for certain stock option exercises during the period the stock option awards are exercised, generally for the excess of the market value on the exercise date over the exercise price of the stock option awards. We receive an additional tax deduction when restricted stock awards vest at a higher value than the value used to recognize compensation expense at the date of grant. We are required to report excess tax benefits from the award of equity instruments as financing cash flows. We recognized an excess tax shortfall for the years ended December 31, 2014 and 2013, as referenced in Note 3 of these consolidated financial statements. We did not recognize any material excess tax benefit or shortfall in earnings for the year ended December 31, 2012.

Fair_Value_Measurements_Fair_V

Fair Value Measurements Fair Value Measurements (Policies)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments	Fair Value Measurements
	FASB ASC 820-10 defines fair value, establishes guidelines for measuring fair value and expands disclosure about fair value measurements. It does not create or modify any current GAAP requirements to apply fair value accounting. However, it provides a single definition for fair value that is to be applied consistently for all prior accounting pronouncements.
	Our financial instruments consist of cash and cash equivalents, accounts receivable, accounts payable, bank borrowings, and senior notes. The carrying amounts of cash and cash equivalents, accounts receivable, and accounts payable approximate fair value due to the highly liquid or short-term nature of these instruments.

Summary_of_Signigicant_Account

Summary of Signigicant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2014
Accounting Policies [Abstract]
Property and Equipment	The following is a detailed breakout of our “Property and Equipment” balances.
	(in thousands)	December 31,				December 31,
		2014				2013
	Property and Equipment
	Proved oil and gas properties	$	5,826,995			$	5,600,279
	Unproved oil and gas properties	64,903				71,452
	Furniture, fixtures, and other equipment	42,257				42,368
	Less – Accumulated depreciation, depletion, and amortization	(3,839,118		)		(3,125,282		)
	Property and Equipment, Net	$	2,095,037			$	2,588,817
Schedule of Derivative Instruments	The following tables summarize the weighted average prices and future production volumes for our unsettled derivative contracts in place as of December 31, 2014.
								Collars
	Natural Gas Derivatives	Total Volumes (MMBtu)		Swap Fixed Price				Floor		Ceiling Price
	(NYMEX Henry Hub Settlements)							Price
	2015 Contracts
	Swaps	600,000		$	4.42
	Collars	1,280,000						$	4.05	$	4.88
	Natural Gas Basis Derivatives	Total Volumes (MMBtu)		Swap Fixed Price
	(East Texas Houston Ship Channel Settlements)
	2015 Contracts
	Swaps	7,280,000		$	(0.02	)
Accounts Payable and Accrued Liabilities	The “Accounts payable and accrued liabilities” balances on the accompanying consolidated balance sheets are summarized below (in thousands):
		December 31,				December 31,
		2014				2013
	Trade accounts payable (1)	$	31,153			$	30,769
	Accrued operating expenses	10,784				16,016
	Accrued payroll costs	8,100				10,938
	Asset retirement obligations – current portion	10,709				15,859
	Accrued taxes	2,957				5,845
	Other payables	4,541				2,891
	Total accounts payable and accrued liabilities	$	68,244			$	82,318
	(1) Included in “trade accounts payable” are liabilities of approximately $13.7 million and $26.1 million at December 31, 2014 and 2013, respectively, for outstanding checks.
Roll-forward of our asset retirement obligations	The following provides a roll-forward of our asset retirement obligations (in thousands):
	Asset Retirement Obligations as of December 31, 2012	$	86,777
	Accretion expense	6,181
	Liabilities incurred for new wells and facilities construction	1,588
	Reductions due to sold and abandoned wells and facilities	(16,394		)
	Revisions in estimates	932
	Asset Retirement Obligations as of December 31, 2013	$	79,084
	Accretion expense	5,712
	Liabilities incurred for new wells and facilities construction	469
	Reductions due to sold and abandoned wells and facilities	(8,253		)
	Revisions in estimates	(4,181		)
	Asset Retirement Obligations as of December 31, 2014	$	72,831

Earnings_Per_Share_Tables

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2014
Earnings Per Share [Abstract]
Reconciliation of the numerators and denominators used in the calculation of Basic and Diluted EPS	The following is a reconciliation of the numerators and denominators used in the calculation of Basic and Diluted EPS for the years ended December 31, 2014, 2013 and 2012 (in thousands, except per share amounts):
		2014							2013							2012
		Net Income (Loss)			Shares	Per Share			Net Income (Loss)			Shares	Per Share			Net Income (Loss)		Shares	Per Share
						Amount							Amount						Amount
	Basic EPS:
	Net Income (Loss) and Share Amounts	$	(283,427	)	43,795	$	(6.47	)	$	(2,442	)	43,331	$	(0.06	)	$	21,701	42,840	$	0.51
	Dilutive Securities:
	Stock Options				—							—						90
	Restricted Stock Awards				—							—						244
	Diluted EPS:
	Net Income (Loss) and Assumed Share Conversions	$	(283,427	)	43,795	$	(6.47	)	$	(2,442	)	43,331	$	(0.06	)	$	21,701	43,174	$	0.5

Provision_Benefit_for_Income_T1

Provision (Benefit) for Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Summary of income (Loss) from continuing operations before taxes	Income (Loss) before taxes is as follows (in thousands):
		Year Ended December 31,
		2014			2013			2012
	Income (Loss) Before Income Taxes	$	(433,470	)	$	198		$	37,773
Summary of consolidated income tax provision (benefit)	The following is an analysis of the consolidated income tax provision (benefit) (in thousands):
		Year Ended December 31,
		2014			2013			2012
	Current	$	314		$	(12	)	$	(1,144	)
	Deferred	(150,357		)	2,652			17,216
	Total	$	(150,043	)	$	2,640		$	16,072
Reconciliations of income taxes computed using the U.S. Federal statutory rate to the effective income tax rates	Reconciliations of income taxes computed using the U.S. Federal statutory rate (35%) to the effective income tax rates are as follows (in thousands):
		Year Ended December 31,
		2014			2013			2012
	Income taxes computed at U.S. statutory rate	$	(151,714	)	$	69		$	13,221
	State tax provisions (benefits), net of federal benefits	(5,935		)	(184		)	(950		)
	Non-deductible equity compensation	666			1,127			1,911
	Stock-based compensation tax shortfall	2,409			558			—
	Valuation allowances	4,635			385			2,370
	Expiration of carryover items	288			400			—
	Uncertain Tax Positions	—			—			(977		)
	Other, net	(392		)	285			497
	Provision (benefit) for income taxes	$	(150,043	)	$	2,640		$	16,072
	Effective rate	34.6		%	1,333.40		%	42.5		%
Tax effects of temporary differences representing the net deferred tax asset (liability)	The tax effects of temporary differences representing the net deferred tax asset (liability) at December 31, 2014 and 2013 were as follows (in thousands):
		Year Ended December 31,
		2014			2013
	Deferred tax assets:
	Federal net operating loss (“NOL”) carryovers	$	141,896		$	117,713
	NOLs for excess stock-based compensation	(9,606		)	(9,615		)
	State NOL carryovers	15,525			14,626
	Alternative minimum tax credits	2,092			2,092
	Other Carryover Items	1,294			1,295
	Asset Retirement Obligations	26,388			28,628
	Unrealized share-based compensation	9,471			9,957
	Valuation allowance	(11,327		)	(6,703		)
	Other	4,056			6,042
	Total deferred tax assets	$	179,789		$	164,035
	Deferred tax liabilities:
	Oil and gas exploration and development costs	$	(258,326	)	$	(393,606	)
	Other	(1,596		)	(919		)
	Total deferred tax liabilities	$	(259,922	)	$	(394,525	)
	Net deferred tax liabilities	$	(80,133	)	$	(230,490	)
	Net current deferred tax assets	6,243			10,715
	Net non-current deferred tax liabilities	$	(86,376	)	$	(241,205	)

LongTerm_Debt_Tables

Long-Term Debt (Tables)	12 Months Ended
	Dec. 31, 2014
Debt Disclosure [Abstract]
Long-term debt	Our long-term debt as of December 31, 2014 and 2013, was as follows (in thousands):
		December 31, 2014		December 31, 2013
	7.125% senior notes due in 2017	$	250,000	$	250,000
	8.875% senior notes due in 2020 (1)	222,775		222,446
	7.875% senior notes due in 2022 (1)	404,459		404,922
	Bank Borrowings	197,300		265,000
	Long-Term Debt (1)	$	1,074,534	$	1,142,368
	(1) Amounts are shown net of any debt discount or premium

ShareBased_Compensation_Tables

Share-Based Compensation (Tables)	12 Months Ended
	Dec. 31, 2014
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Stock Option Assumptions
		Twelve Months Ended
		December 31,
		2012
	Dividend yield	0%
	Expected volatility	61.20%
	Risk-free interest rate	0.80%
	Expected life of stock option awards (in years)	4.3
	Weighted-average grant-date fair value	$15.71
Stock option activity	The following table represents stock option award activity for the year ended December 31, 2014:
		2014
		Shares		Wtd. Avg.
				Exer. Price
	Options outstanding, beginning of period	1,488,314		$	33.38
	Options granted	—		$	—
	Options canceled	(156,124	)	$	27.68
	Options exercised	—		$	—
	Options outstanding, end of period	1,332,190		$	34.02
	Options exercisable, end of period	1,230,019		$	34.14
Stock options outstanding	The following table summarizes information about stock option awards outstanding at December 31, 2014:
			Options Outstanding					Options Exercisable
	Range of Exercise Prices		Number Outstanding at 12/31/14		Wtd. Avg. Remaining Contractual Life	Wtd. Avg. Exercise Price		Number Exercisable at 12/31/14	Wtd. Avg. Exercise Price
	$8.00 to $24.99		380,080		4.6	$	19.91	380,080	$	19.91
	$25.00 to $45.00		952,110		4.8	$	39.66	849,939	$	40.5
	$8.00 to $45.00		1,332,190		4.7	$	34.02	1,230,019	$	34.14
Schedule of RSA Activity	The following table represents restricted stock award activity for the year ended December 31, 2014:
		2014
		Shares		Wtd. Avg.
				Grant Price
	Restricted shares outstanding, beginning of period	1,267,110		$	21.54
	Restricted shares granted	747,400		$	11.55
	Restricted shares canceled	(208,206	)	$	15.3
	Restricted shares vested	(392,292	)	$	30.09
	Restricted shares outstanding, end of period	1,414,012		$	14.81
Schedule of Nonvested Restricted Stock Units Activity	The following table represents restricted stock unit activity for the year ended December 31, 2014:
		Shares		Wtd. Avg.
				Grant Price
	Restricted stock units outstanding, beginning of period	189,700		$	15.01
	Restricted stock units granted	185,250		$	11.68
	Restricted stock units canceled	—		$	—
	Restricted stock units vested	—		$	—
	Restricted stock units outstanding, end of period	374,950		$	13.36

Fair_Value_Measurements_Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2014
Fair Value Disclosures [Abstract]
Fair value of senior notes	Based upon quoted market prices as of December 31, 2014, 2013 and 2012, the fair value and carrying value of our senior notes was as follows (in millions):
		December 31, 2014				December 31, 2013				December 31, 2012
		Fair Value		Carrying Value		Fair Value		Carrying Value		Fair Value		Carrying Value
	7.125% senior notes due in 2017	$	153	$	250	$	256.7	$	250	$	258.1	$	250
	8.875% senior notes due in 2020	$	133.1	$	222.8	$	239.1	$	222.4	$	244.4	$	221.1
	7.875% senior notes due in 2022	$	198	$	404.5	$	409	$	404.9	$	424	$	405.4
Fair value of plan assets	The following table presents our assets that are measured at fair value as of December 31, 2014 and 2013, and are categorized using the fair value hierarchy. For additional discussion related to the fair value of the Company's derivatives, refer to Note 1 of these consolidated financial statements. The fair value hierarchy has three levels based on the reliability of the inputs used to determine the fair value (in millions):
		Fair Value Measurements at
		Total		Quoted Prices in		Significant Other		Significant
				Active markets for		Observable Inputs		Unobservable
				Identical Assets		(Level 2)		Inputs
				(Level 1)				(Level 3)
	December 31, 2014
	Assets
	Natural Gas Derivatives	$	2.4	$	—	$	2.4	$	—
	Natural Gas Basis Derivatives	$	0.1	$	—	$	0.1	$	—
	Liabilities
	Natural Gas Basis Derivatives	$	0.1	$	—	$	0.1	$	—
	31-Dec-13
	Assets
	Natural Gas Derivatives	$	0.5	$	—	$	0.5	$	—
	Oil Derivatives	$	0.3	$	—	$	0.3	$	—
	Liabilities
	Natural Gas Derivatives	$	0.7	$	—	$	0.7	$	—
	Oil Derivatives	$	0.2	$	—	$	0.2	$	—

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012
Property, Plant and Equipment [Abstract]
Proved oil and gas properties	$5,826,995		$5,600,279
Unproved oil and gas properties	64,903		71,452
Furniture, fixtures, and other equipment	42,257		42,368
Less - Accumulated depreciation, depletion, and amortization	-3,839,118		-3,125,282
Property and Equipment, Net	2,095,037		2,588,817
Accounts Payable and Accrued Liabilities [Abstract]
Trade accounts payable	31,153	[1]	30,769	[1]
Accrued operating expenses	10,784		16,016
Accrued payroll costs	8,100		10,938
Asset retirement obligation - current portion	10,709		15,859
Accrued taxes	2,957		5,845
Other payables	4,541		2,891
Total accounts payable and accrued liabilities	68,244		82,318
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset Retirement Obligation recorded as of January 1	79,084		86,777
Accretion expense	5,712		6,181		5,121
Liabilities incurred for new wells and facilities construction	469		1,588
Reductions due to sold and abandoned wells	-8,253		-16,394
Revisions in estimates	-4,181		932
Asset Retirement Obligation recorded as of December 31	$72,831		$79,084		$86,777
Year 2015 [Member] | Energy Related Derivative [Member] | Swap [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Future Gas Production Hedged in MMBTU (Energy Item Type)	600,000
Derivative, Swap Type, Average Fixed Price	4.42
Year 2015 [Member] | Energy Related Derivative [Member] | Future [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Future Gas Production Hedged in MMBTU (Energy Item Type)	1,280,000
Derivative, Average Floor Price	4.05
Derivative, Average Cap Price	4.88
Year 2015 [Member] | Other Contract [Member] | Forward Contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Future Gas Production Hedged in MMBTU (Energy Item Type)	7,280,000
Derivative, Swap Type, Average Fixed Price	-0.02
[1]	Included in btrade accounts payableb are liabilities of approximately $13.7 million and $26.1 million at December 31, 2014 and 2013, respectively, for outstanding checks.

Summary_of_Significant_Account3

Summary of Significant Accounting Policies (Details Textual) (USD $)	12 Months Ended			0 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Dec. 31, 2014	Jun. 01, 2007	Nov. 25, 2009	Oct. 03, 2012	Jul. 15, 2014
								acre
Summary of Significant Accounting Policies (Textual) [Abstract]
Total capitalized internal costs	$26,300,000	$31,800,000	$31,100,000
Discount rate for estimated future net revenues from proved properties	10.00%
Write-down of oil and gas properties	445,396,000	46,948,000	0
Allowance for doubtful accounts receivable, current	100,000	100,000		100,000
Trade Accounts Receivable, Gross	34,800,000	56,900,000		34,800,000
Accounts receivable related to joint interest owners	8,400,000	1,600,000		8,400,000
Severance Tax Receivables	3,100,000	11,600,000		3,100,000
Other Receivables	2,200,000	800,000		2,200,000
Gain (loss) on Price Risk Derivatives, Net	1,300,000	-900,000	2,300,000
Derivative Asset, Fair Value, Gross Asset	2,500,000			2,500,000
Derivative Liability, Fair Value, Gross Liability	100,000			100,000
Derivative, Fair Value, Net	2,400,000			2,400,000
Receivables, Fair Value Disclosure	1,000,000			1,000,000
Percentage of working interest in wells	100.00%
Total amount of supervision fees charged to wells	12,700,000	11,600,000	11,300,000
Inventories carried at cost	3,100,000	3,500,000		3,100,000
Prepaid Expense	3,900,000	3,300,000		3,900,000
Outstanding checks included in trade accounts payable	13,700,000	26,100,000		13,700,000
Acreage Sold in Oil and Gas Properties								8,300
Participation Interest Sold in Oil and Gas Properties								36.00%
Increase in Restricted Cash in Operating Activities	29,800,000
Decrease in Restricted Cash in Operating Activities	7,100,000
Restricted cash and cash equivalents included in other long term assets	1,000,000	1,000,000		1,000,000
Asset Retirement Obligation - current portion	10,709,000	15,859,000		10,709,000
Shell Oil Company Concentration Risk [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Concentration Risk, Percentage	21.00%	33.00%	46.00%
Kinder Morgan Concentration Risk [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Concentration Risk, Percentage	20.00%
Plains Marketing Concentration Risk [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Concentration Risk, Percentage	11.00%
BP America Concentration Risk [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Concentration Risk, Percentage		21.00%
Southcross Energy Concentration Risk [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Concentration Risk, Percentage			11.00%
Line of Credit [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Balance of issuance costs for credit facility				2,300,000
Minimum [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Property, Plant and Equipment, Useful Life	2 years
Maximum [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Property, Plant and Equipment, Useful Life		20 years
Senior Notes Due 2017 [Member] | Senior Notes [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Stated Rate of Senior notes					7.13%
Balance of issuance costs for credit facility				1,300,000	4,200,000
Senior Notes Due 2020 [Member] | Senior Notes [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Stated Rate of Senior notes						8.88%
Balance of issuance costs for credit facility				3,100,000		5,000,000
Senior Notes Due 2022 [Member] | Senior Notes [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Stated Rate of Senior notes							7.88%
Balance of issuance costs for credit facility				$5,900,000			$7,500,000

Earnings_Per_Share_Details

Earnings Per Share (Details) (USD $)	12 Months Ended
In Thousands, except Share data, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Basic EPS:
Net Income (Loss)	($283,427)	($2,442)	$21,701
Income, Share Amounts	43,795,000	43,331,000	42,840,000
Earnings Per Share, Basic	($6.47)	($0.06)	$0.51
Dilutive Securities:
Dilutive Options, Shares	0	0	90,000
Dilutive RSA's, Shares	0	0	244,000
Diluted EPS:
Net Income (Loss) Available to Common Stockholders, Diluted	($283,427)	($2,442)	$21,701
Weighted Average Number of Shares Outstanding, Diluted	43,795,000	43,331,000	43,174,000
Earnings Per Share, Diluted	($6.47)	($0.06)	$0.50
Earnings Per Share (Textual) [Abstract]
Options to purchase, shares	1,332,190	1,488,314	1,585,594
Options to purchase, exercise price	$34.02	$33.38	$33.13
Stock Options [Member]
Earnings Per Share (Textual) [Abstract]
Antidilutive shares not included in the computation of diluted EPS	1,400,000	1,600,000	1,300,000
Restricted Stock Awards [Member]
Earnings Per Share (Textual) [Abstract]
Antidilutive shares not included in the computation of diluted EPS	500,000	300,000	300,000
Restricted Stock Units (RSUs) [Member]
Earnings Per Share (Textual) [Abstract]
Antidilutive shares not included in the computation of diluted EPS	400,000	300,000

Provision_Benefit_for_Income_T2

Provision (Benefit) for Income Taxes (Details) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Summary of income (Loss) from continuing operations before taxes
Income (Loss) from Continuing Operations Before Income Taxes	($433,470)	$198	$37,773

Provision_Benefit_for_Income_T3

Provision (Benefit) for Income Taxes (Details 1) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Summary of consolidated income tax provision (benefit)
Current income taxes	$314	($12)	($1,144)
Deferred income taxes	-150,357	2,652	17,216
Income tax provision (benefit)	($150,043)	$2,640	$16,072

Provision_Benefit_for_Income_T4

Provision (Benefit) for Income Taxes (Details 2) (USD $)	12 Months Ended
In Thousands, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Reconciliations of income taxes computed using the U.S. Federal statutory rate to the effective income tax rates
Income taxes (or benefits) computed at U.S. statutory rate -35%	($151,714)	$69	$13,221
State tax provisions (benefits), net of federal benefits	-5,935	-184	-950
Non-deductible equity compensation	666	1,127	1,911
Stock-based compensation tax shortfall	2,409	558	0
Valuation allowance of carryover tax assets	4,635	385	2,370
Expired Operating Loss Carryovers	288	400	0
Uncertain Tax Positions	0	0	-977
Other, net	-392	285	497
Income tax provision (benefit)	($150,043)	$2,640	$16,072
Effective rate	34.60%	1333.40%	42.50%

Provision_Benefit_for_Income_T5

Provision (Benefit) for Income Taxes (Details 3) (USD $)	Dec. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Deferred tax assets:
DTA, Federal net operating losses (NOLs)	$141,896	$117,713
DTA, NOLs for excess stock-based compensation	-9,606	-9,615
DTA, State NOL carryovers	15,525	14,626
DTA, Alternative minimum tax credits	2,092	2,092
DTA, Other Loss Carryforwards	1,294	1,295
DTA, ARO	26,388	28,628
DTA, Unrealized share-based compensation	9,471	9,957
DTA, Valuation Allowance	-11,327	-6,703
DTA, Other	4,056	6,042
Total deferred tax assets	179,789	164,035
Deferred tax liabilities:
Deferred Tax Liabilities, Property, Plant and Equipment	-258,326	-393,606
Deferred Tax Liabilities, Other	-1,596	-919
Deferred Tax Liabilities, Gross	259,922	394,525
Total deferred tax liabilities	-80,133	-230,490
Net current deferred tax assets	6,243	10,715
Net non-current deferred tax liabilities	($86,376)	($241,205)

Provision_Benefit_for_Income_T6

Provision (Benefit) for Income Taxes (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Tax Disclosure [Abstract]
Effective Income Tax Rate Reconciliation, at Federal Statutory Income Tax Rate, Percent	35.00%
Stock-based compensation tax shortfall	$2,409,000	$558,000	$0
Total tax impact of APIC shortfall		2,200,000
Adjustments to Additional Paid in Capital, Income Tax Deficiency from Share-based Compensation		1,600,000
Deferred Tax Assets, Operating Loss Carryforwards	405,400,000
Valuation allowance of carryover tax assets	$10,900,000	$6,600,000

LongTerm_Debt_Details

Long-Term Debt (Details) (USD $)	12 Months Ended					0 Months Ended
	Dec. 31, 2014		Dec. 31, 2013		Dec. 31, 2012	Dec. 31, 2014		Jun. 01, 2007	Nov. 25, 2009	Oct. 03, 2012	Oct. 27, 2014	Nov. 30, 2011
											Banks
Bank Borrowings
Long-Term Debt	$1,074,534,000	[1]	$1,142,368,000	[1]		$1,074,534,000	[1]
Capitalized interest on our unproved properties	5,000,000		7,200,000		7,900,000
Number of syndicated banks											11
Current Borrowing base											417,600,000
Maximum availability aggregate facility amount											500,000,000
Line of Credit, Current Commitment Amount											417,600,000
Interest expense including commitment fees and amortization of debt issuance costs relating to the credit facility	73,207,000		69,382,000		57,303,000
Line of Credit [Member]
Bank Borrowings
Long-Term Debt	197,300,000		265,000,000			197,300,000
Percentage of applicable margin with federal fund rate	0.50%
Percentage of applicable margin with LIBOR	1.00%
Lead bank's prime rate	3.25%
Maximum level of cash dividends in any fiscal year	15,000,000					15,000,000
Aggregate limitation on purchases of stock	50,000,000					50,000,000
Line of Credit, Working Capital Ratio Required						1
Line of Credit, Covenant, Working Capital Ratio, Company Actual						1.9
Line of Credit, Covenant, Interest Coverage Ratio, Required						2.75
Line of Credit, Covenant, Interest Coverage Ratio, Company Actual						4.9
Line of Credit, Required Security Interest on Oil and Gas Properties	75.00%
Interest expense including commitment fees and amortization of debt issuance costs relating to the credit facility	7,500,000		6,000,000		3,700,000
Commitment fees included in interest expense, net	800,000		1,100,000		1,400,000
Senior Notes
Debt Issuance Cost						2,300,000
Line of Credit [Member] | Minimum [Member]
Bank Borrowings
Line of Credit Facility, Commitment Fee Percentage	0.38%
Line of Credit [Member] | Minimum [Member] | Alternative Base Interest Rate [Member]
Bank Borrowings
Debt Instrument escalating basis spread on base rate	50
Line of Credit [Member] | Minimum [Member] | Eurodollar Interest Rate [Member]
Bank Borrowings
Debt instrument escalating rates for eurodollar rate loans	150
Line of Credit [Member] | Maximum [Member]
Bank Borrowings
Line of Credit Facility, Commitment Fee Percentage	0.50%
Line of Credit [Member] | Maximum [Member] | Alternative Base Interest Rate [Member]
Bank Borrowings
Debt Instrument escalating basis spread on base rate	150
Line of Credit [Member] | Maximum [Member] | Eurodollar Interest Rate [Member]
Bank Borrowings
Debt instrument escalating rates for eurodollar rate loans	250
Senior Notes Due 2017 [Member] | Senior Notes [Member]
Bank Borrowings
Long-Term Debt	250,000,000		250,000,000			250,000,000
Maturities on long-term debt 2017	250,000,000					250,000,000
Interest expense including commitment fees and amortization of debt issuance costs relating to the credit facility	18,300,000		18,300,000		18,200,000
Senior Notes
Senior notes, issued								250,000,000
Stated rate of senior notes								7.13%
Percentage at which senior notes are issued, of par value								100.00%
Debt Issuance Cost						1,300,000		4,200,000
Holder right to require company to repurchase notes at purchase price in cash								101.00%
Senior Notes Due 2017 [Member] | Debt Instrument, Redemption, Period One [Member] | Senior Notes [Member]
Senior Notes
Debt Instrument, Redemption Price, Percentage								101.19%
Senior Notes Due 2017 [Member] | Debt Instrument, Redemption, Period Two [Member] | Senior Notes [Member]
Senior Notes
Debt Instrument, Redemption Price, Percentage								100.00%
Senior Notes Due 2020 [Member] | Senior Notes [Member]
Bank Borrowings
Long-Term Debt	222,775,000	[1]	222,446,000	[1]		222,775,000	[1]
Maturities on long-term debt 2020 & 2022	225,000,000					225,000,000
Interest expense including commitment fees and amortization of debt issuance costs relating to the credit facility	20,800,000		20,700,000		20,600,000
Senior Notes
Senior notes, issued									225,000,000
Stated rate of senior notes									8.88%
Original unamortized issuance discount on senior notes									3,600,000
Percentage at which senior notes are issued, of par value									98.39%
Effective interest rate on senior notes including discount									9.13%
Debt Issuance Cost						3,100,000			5,000,000
Holder right to require company to repurchase notes at purchase price in cash									101.00%
Senior Notes Due 2020 [Member] | Debt Instrument, Redemption, Period One [Member] | Senior Notes [Member]
Senior Notes
Debt Instrument, Redemption Price, Percentage									104.44%
Senior Notes Due 2020 [Member] | Debt Instrument, Redemption, Period Two [Member] | Senior Notes [Member]
Senior Notes
Debt Instrument, Redemption Price, Percentage									100.00%
Senior Notes Due 2022 [Member] | Senior Notes [Member]
Bank Borrowings
Long-Term Debt	404,459,000	[1]	404,922,000	[1]		404,459,000	[1]
Maturities on long-term debt 2020 & 2022	400,000,000					400,000,000
Interest expense including commitment fees and amortization of debt issuance costs relating to the credit facility	31,600,000		31,600,000		22,400,000
Senior Notes
Senior notes, issued										400,000,000		250,000,000
Stated rate of senior notes										7.88%
Original unamortized issuance discount on senior notes												2,100,000
Percentage at which senior notes are issued, of par value												99.16%
Effective interest rate on senior notes including discount												8.00%
Percentage of maximum redemption of principal amount of notes										35.00%
Redemption of debts with net proceeds of qualifying offerings at price above principle amount of debts										107.88%
Debt Issuance Cost						5,900,000				7,500,000
Holder right to require company to repurchase notes at purchase price in cash										101.00%
Senior Notes Due 2022 [Member] | Debt Instrument, Redemption, Period One [Member] | Senior Notes [Member]
Senior Notes
Debt Instrument, Redemption Price, Percentage										103.94%
Senior Notes Due 2022 [Member] | Debt Instrument, Redemption, Period Two [Member] | Senior Notes [Member]
Senior Notes
Debt Instrument, Redemption Price, Percentage										100.00%
Additional Senior Notes Due 2022 [Member] | Senior Notes [Member]
Senior Notes
Senior notes, issued										150,000,000
Percentage at which senior notes are issued, of par value										105.00%
Effective interest rate on senior notes including discount										6.99%
Original Unamortized Premium										$7,500,000
[1]	Amounts are shown net of any debt discount or premium

Commitments_and_Contingencies_1

Commitments and Contingencies (Details Textual) (USD $)	12 Months Ended			2 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Feb. 27, 2015
Obligations (Textual)
Operating Leases, Rent Expense	$21	$20.50	$19.90
Operating lease commitments [Member]
Obligations (Textual)
Operating Leases, Future Minimum Payments Due	12.6
Operating Leases, Future Minimum Payments Due, Next Twelve Months	12.6
Operating Leases, Future Minimum Payments, Due in Two Years	0.1
Gas transportation and processing obligations [Member]
Obligations (Textual)
Operating Leases, Future Minimum Payments Due	61.6
Operating Leases, Future Minimum Payments Due, Next Twelve Months	12.7
Operating Leases, Future Minimum Payments, Due in Two Years	12.5
Operating Leases, Future Minimum Payments, Due in Three Years	10.1
Operating Leases, Future Minimum Payments, Due in Four Years	10.2
Operating Leases, Future Minimum Payments, Due in Five Years	8.7
Subsequent Event [Member]
Obligations (Textual)
Operating Lease Term of Contract				11 years
Operating Lease, Early Termination Option				7 years
Operating Leases, Future Minimum Payments Due				$25

ShareBased_Compensation_Detail

Share-Based Compensation (Details) (USD $)	12 Months Ended
	Dec. 31, 2012
Weighted-average assumptions for options issued during the indicated periods
Dividend yield	0.00%
Expected volatility	61.20%
Risk-free interest rate	0.80%
Expected life of options (in years)	4 years 3 months
Weighted-average grant-date fair value	$15.71

ShareBased_Compensation_Detail1

Share-Based Compensation (Details 1) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2012
Stock option activity in shares and weighted average price
Options outstanding, beginning of period, shares	1,488,314	1,585,594
Options outstanding, beginning of period, weighted average price	$33.38	$33.13
Options granted, shares	0
Options granted, weighted average price	$0
Options canceled, shares	-156,124
Options canceled, weighted average price	$27.68
Options exercised, shares	0
Options exercised, weighted average price	$0
Options outstanding, end of period, shares	1,332,190	1,585,594
Options outstanding, end of period, weighted average price	$34.02	$33.13
Options exercisable, end of period, shares	1,230,019
Options exercisable, end of period, weighted average price	$34.14

ShareBased_Compensation_Detail2

Share-Based Compensation (Details 2) (USD $)	12 Months Ended
	Dec. 31, 2014
$ 8.00 to $24.99 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Options Outstanding, Number of Outstanding Options	380,080
Options Outstanding, Weighted Average Remaining Contractual Life	4 years 7 months
Options Outstanding, Weighted Average Exercise	$19.91
Options Exercisable, Number of Exercisable Options	380,080
Options Exercisable, Exercisable Options, Weighted Average Exercise Price	$19.91
$25.00 to $45.00 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Options Outstanding, Number of Outstanding Options	952,110
Options Outstanding, Weighted Average Remaining Contractual Life	4 years 10 months
Options Outstanding, Weighted Average Exercise	$39.66
Options Exercisable, Number of Exercisable Options	849,939
Options Exercisable, Exercisable Options, Weighted Average Exercise Price	$40.50
$8.00 to $45.00 [Member]
Share-based Compensation, Shares Authorized under Stock Option Plans, Exercise Price Range [Line Items]
Options Outstanding, Number of Outstanding Options	1,332,190
Options Outstanding, Weighted Average Remaining Contractual Life	4 years 8 months
Options Outstanding, Weighted Average Exercise	$34.02
Options Exercisable, Number of Exercisable Options	1,230,019
Options Exercisable, Exercisable Options, Weighted Average Exercise Price	$34.14

ShareBased_Compensation_Detail3

Share-Based Compensation (Details 3) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Restricted Stock [Member]
Restricted stock activity
Restricted shares outstanding, beginning of period, shares	1,267,110
Restricted shares outstanding, beginning of period, weighted average price	$21.54
Restricted shares granted, shares	747,400
Restricted shares granted, fair value, weighted average price	$11.55	$14.86	$31.12
Restricted shares canceled, shares	-208,206
Restricted shares canceled, fair value, weighted average price	$15.30
Restricted shares vested, shares	-392,292
Restricted shares vested, weighted average price	$30.09
Restricted shares outstanding, end of period, shares	1,414,012	1,267,110
Restricted shares outstanding, end of period, weighted average price	$14.81	$21.54
Restricted Stock Units (RSUs) [Member]
Restricted stock activity
Restricted shares outstanding, beginning of period, shares	189,700
Restricted shares outstanding, beginning of period, weighted average price	$15.01
Restricted shares granted, shares	185,250
Restricted shares granted, fair value, weighted average price	$11.68	$15.01
Restricted shares canceled, shares	0
Restricted shares canceled, fair value, weighted average price	$0
Restricted shares vested, shares	0
Restricted shares vested, weighted average price	$0
Restricted shares outstanding, end of period, shares	374,950	189,700
Restricted shares outstanding, end of period, weighted average price	$13.36	$15.01

ShareBased_Compensation_Detail4

Share-Based Compensation (Details Textual) (USD $)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Stock-Based Compensation Plan
Percentage of fair value of the common stock equal to exercise price	100.00%
Number of Matured Shares Delivered in Stock Swap Transactions		10,752	20,692
Percentage of payroll deductions	10.00%
Percentage of purchase price for stock acquired under the plan	85.00%
Number of shares issued under employee stock purchase plan	71,825	72,273	42,624
Purchase price of shares issued under employee stock purchase plan	$11.47	$13.08	$25.26
Net cash proceed from excise of stock options			$600,000
Actual income tax benefit from excise of stock options			300,000
Share-based compensation expenses	7,309,000	10,099,000	13,795,000
Share-based compensation (capitalized)	3,500,000	5,500,000	5,200,000
Stock Option Awards
Look back period used to estimate expected volatility of stock option grants	5 years 6 months
Remaining contract life of outstanding stock options.	4 years 8 months
Remaining contract life of exercisable stock option	4 years 6 months
Intrinsic value of exercised stock option			900,000
Restricted Stock Units [Abstract]
Performance Period for RSUs			4 years 3 months
Percent of payout for performance based restricted stock unit grants	100.00%
Employee Stock Ownership Plan
Minimum age to participate for ESOP	21 years
Amount contributed to ESOP		200,000	200,000
Shares of common stock contributed to ESOP		14,815	12,995
Employee Savings Plan [Abstract]
Employee Savings Plan, Employer Matching Contribution, Percent	100.00%
Employee Savings Plan, Maximum Annual Contribution Per Employee, Percent	6.00%
Employee Savings Plan, Employer Discretionary Contribution Amount	1,800,000	1,800,000	1,500,000
Defined Contribution Plan, Employer Discretionary Contribution Amount Paid in Cash	900,000
Employee Savings Plan, Stock Issued During Period, Shares	352,476	139,850	91,895
General and Administrative Expense [Member]
Stock-Based Compensation Plan
Share-based compensation expenses	6,700,000	9,300,000	12,900,000
Operating Lease Expense [Member]
Stock-Based Compensation Plan
Share-based compensation expenses	200,000	300,000	300,000
Employee Stock Option [Member]
Stock-Based Compensation Plan
Reduction in shares available for future grant by restricted stock	1
Stock Option Awards
Unrecognized compensation cost related to stock options	100,000
Weighted average recognition period of cost related to stock options	1 month
Restricted Stock Awards [Member]
Stock-Based Compensation Plan
Reduction in shares available for future grant by restricted stock	1.44
Stock Option Awards
Unrecognized compensation cost related to stock options	9,600,000
Weighted average recognition period of cost related to stock options	1 year 6 months
Restricted Stock Awards [Abstract]
Number of shares issued to employees, consultants and directors	747,400	869,430	543,800
Fair value of non-option shares granted	$11.55	$14.86	$31.12
Grant date fair value of shares vested	11,800,000	12,800,000	10,000,000
Performance Awards (RSUs) [Member]
Stock-Based Compensation Plan
Reduction in shares available for future grant by restricted stock	1.44
Stock Option Awards
Unrecognized compensation cost related to stock options	$2,200,000
Weighted average recognition period of cost related to stock options	1 year 10 months
Restricted Stock Awards [Abstract]
Number of shares issued to employees, consultants and directors	185,250	189,700
Vesting period	3 years 1 month
Fair value of non-option shares granted	$11.68	$15.01
Restricted Stock Units [Abstract]
Performance Period for RSUs	3 years
Minimum Payout [Member]
Restricted Stock Awards [Abstract]
Vesting period	3 years
Maximum Payout [Member]
Restricted Stock Units [Abstract]
Percent of payout for performance based restricted stock unit grants	200.00%
Employee Stock Ownership Plan
Criteria for ESOP	1 year
Employee Stock Purchase Plan [Member]
Stock-Based Compensation Plan
Shares available for future grant under stock compensation plans	318,027
Share-Based Compensation Plan [Member]
Stock-Based Compensation Plan
Shares available for future grant under stock compensation plans	1,814,928

Related_Party_Transactions_Det

Related Party Transactions (Details) (USD $)	12 Months Ended
In Millions, unless otherwise specified	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Related Party Transactions [Abstract]
Cost of service provided	$0.60	$0.60	$0.60

Acquisitions_and_Dispositions_

Acquisitions and Dispositions (Details) (USD $)	Dec. 31, 2014	Jul. 15, 2014
In Millions, unless otherwise specified		acre
Business Combinations [Abstract]
Acreage Sold in Oil and Gas Properties		8,300
Participation Interest Sold in Oil and Gas Properties		36.00%
Sale proceeds from disposal of properties		$175
Cash Received at Closing from Oil and Gas Properties		125
Cash Carry of Field Development Costs		50
Remaining Cash Carry of Field Development Costs	29
Sale Proceeds Received at Closing		147
Deferred Credits and Other Liabilities, Current		$12.50

Fair_Value_Measurements_Detail

Fair Value Measurements (Details) (Senior Notes [Member], USD $)	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
In Millions, unless otherwise specified
Senior Notes Due 2017 [Member]
Fair value of senior notes
Fair value of senior notes	$153	$256.70	$258.10
Carrying value of senior notes	250	250	250
Senior Notes Due 2020 [Member]
Fair value of senior notes
Fair value of senior notes	133.1	239.1	244.4
Carrying value of senior notes	222.8	222.4	221.1
Senior Notes Due 2022 [Member]
Fair value of senior notes
Fair value of senior notes	198	409	424
Carrying value of senior notes	$404.50	$404.90	$405.40

Fair_Value_Measurements_Detail1

Fair Value Measurements (Details 2) (Fair Value, Measurements, Recurring [Member], USD $)	Dec. 31, 2014	Dec. 31, 2013
In Millions, unless otherwise specified
Natural Gas Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset	$2.40	$0.50
Fair Value of Derivative Liability		0.7
Natural Gas Derivative Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset	0	0
Fair Value of Derivative Liability		0
Natural Gas Derivative Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset	2.4	0.5
Fair Value of Derivative Liability		0.7
Natural Gas Derivative Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset	0	0
Fair Value of Derivative Liability		0
Natural Gas Basis Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset	0.1
Fair Value of Derivative Liability	0.1
Natural Gas Basis Derivative Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset	0
Fair Value of Derivative Liability	0
Natural Gas Basis Derivative Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset	0.1
Fair Value of Derivative Liability	0.1
Natural Gas Basis Derivative Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset	0
Fair Value of Derivative Liability	0
Oil Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset		0.3
Fair Value of Derivative Liability		0.2
Oil Derivative Contract [Member] | Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset		0
Fair Value of Derivative Liability		0
Oil Derivative Contract [Member] | Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset		0.3
Fair Value of Derivative Liability		0.2
Oil Derivative Contract [Member] | Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Asset		0
Fair Value of Derivative Liability		$0