SilverBow Resources (SBOW) 10-Q 5 Nov 15 2015 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2015	Oct. 30, 2015
Document and Entity Information [Abstract]
Entity Registrant Name	SWIFT ENERGY CO
Entity Central Index Key	351,817
Document Type	10-Q
Current Fiscal Year End Date	--12-31
Document Period End Date	Sep. 30, 2015
Amendment Flag	false
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	Q3
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		44,550,975

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets - USD ($) $ in Thousands		Sep. 30, 2015		Dec. 31, 2014
Current Assets:
Cash and cash equivalents		$ 7,322		$ 406
Accounts receivable		36,610		48,451
Deferred tax asset		0		6,243
Other current assets		4,299		9,569
Total Current Assets		48,231		64,669
Property and Equipment:
Property and Equipment		6,023,634		5,934,155
Less - Accumulated depreciation, depletion, and amortization		(5,061,058)		(3,839,118)
Property and Equipment, Net		962,576		2,095,037
Other Long-Term Assets		13,471		13,641
Total Assets		1,024,278		2,173,347
Current Liabilities:
Accounts payable and accrued liabilities		49,116		68,244
Accrued capital costs		19,509		41,461
Accrued interest		13,783		21,389
Undistributed oil and gas revenues		12,589		17,825
Total Current Liabilities		94,997		148,919
Long-Term Debt	[1]	1,179,132		1,074,534
Deferred Tax Liabilities		0		86,376
Asset Retirement Obligation		65,448		62,122
Other Long-Term Liabilities		9,511		7,018
Commitments and Contingencies		0		0
Stockholders' Equity:
Preferred stock, $0.01 par value		0		0
Common stock, $0.01 par value		447		444
Additional paid-in capital		774,830		771,972
Treasury stock held, at cost		(2,487)		(9,855)
Retained earnings (Accumulated deficit)		(1,097,600)		31,817
Total Stockholders' Equity (Deficit)		(324,810)	[2]	794,378
Total Liabilities and Stockholders' Equity		$ 1,024,278		$ 2,173,347
[1]	Amounts are shown net of any debt discount or premium
[2]	Unaudited

Condensed Consolidated Balance3

Condensed Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2015	Dec. 31, 2014
Statement of Financial Position [Abstract]
Capitalized Costs, unproved property balance	$ 69,697	$ 64,903
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	44,709,758	44,379,463
Common stock, shares outstanding	44,547,481	43,918,029
Treasury stock shares held, at cost	162,277	461,434

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Revenues:
Oil and gas sales	$ 60,024	$ 133,896	$ 195,663	$ 441,440
Price-risk management and other, net	92	4,898	(1,041)	(2,472)
Total Revenues	60,116	138,794	194,622	438,968
Costs and Expenses:
General and administrative, net	8,679	10,981	31,525	33,565
Depreciation, depletion, and amortization	35,606	65,331	138,392	201,072
Accretion of asset retirement obligation	1,410	1,445	4,156	4,246
Lease operating cost	17,990	22,067	54,188	70,606
Transportation and gas processing	5,446	5,107	15,855	16,412
Severance and other taxes	4,613	10,191	14,169	28,829
Interest expense, net	19,438	18,197	56,407	55,295
Write-down of oil and gas properties	321,522	0	1,084,595	0
Total Costs and Expenses	414,704	133,319	1,399,287	410,025
Income (Loss) Before Income Taxes	(354,588)	5,475	(1,204,665)	28,943
Provision (Benefit) for Income Taxes	0	3,001	(80,133)	14,200
Net Income (Loss)	$ (354,588)	$ 2,474	$ (1,124,532)	$ 14,743
Per Share Amounts-
Earnings Per Share (Basic)	$ (7.96)	$ 0.06	$ (25.31)	$ 0.34
Earnings Per Share (Diluted)	$ (7.96)	$ 0.06	$ (25.31)	$ 0.33
Weighted Average Shares Outstanding - Basic	44,546	43,850	44,431	43,768
Weighted Average Shares Outstanding - Diluted	44,546	44,473	44,431	44,299

Condensed Consolidated Stateme5

Condensed Consolidated Statements of Stockholders' Equity - USD ($) $ in Thousands		Total	Common Stock	Additional Paid-in Capital	Treasury Stock	Retained Earnings (Accumulated Deficit)
Beginning Balance at Dec. 31, 2013		$ 1,065,350	$ 439	$ 762,242	$ (12,575)	$ 315,244
Stock issued for benefit plans		1,909	0	(1,876)	3,785	0
Purchase of treasury shares		(1,065)	0	0	(1,065)	0
Employee stock purchase plan		824	1	823	0	0
Issuance of restricted stock		0	4	(4)	0	0
Amortization of share-based compensation		10,787	0	10,787	0	0
Net Loss		(283,427)	0	0	0	(283,427)
Ending Balance at Dec. 31, 2014		794,378	444	771,972	(9,855)	31,817
Stock issued for benefit plans		919	0	(1,714)	7,518	(4,885)
Purchase of treasury shares		(150)	0	0	(150)	0
Employee stock purchase plan		302	1	301	0	0
Issuance of restricted stock		0	2	(2)	0	0
Amortization of share-based compensation		4,273	0	4,273	0	0
Net Loss		(1,124,532)	0	0	0	(1,124,532)
Ending Balance at Sep. 30, 2015	[1]	$ (324,810)	$ 447	$ 774,830	$ (2,487)	$ (1,097,600)
[1]	Unaudited

Condensed Consolidated Stateme6

Condensed Consolidated Statements of Stockholders' Equity (Parenthetical) - shares	9 Months Ended	12 Months Ended
	Sep. 30, 2015	Dec. 31, 2014
Statement of Stockholders' Equity [Abstract]
Stock issued for benefit plans (shares)	352,476	154,665
Purchase of treasury stock (shares)	53,319	102,673
Employee stock purchase plan (shares)	87,629	71,825
Issuance of restricted stock (shares)	242,666	392,292

Condensed Consolidated Stateme7

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014
Cash Flows from Operating Activities:
Net income (loss)	$ (1,124,532)	$ 14,743
Adjustments to reconcile net income to net cash provided by operating activities -
Depreciation, depletion, and amortization	138,392	201,072
Write-down of oil and gas properties	1,084,595	0
Accretion of asset retirement obligation	4,156	4,246
Deferred income taxes	(80,133)	13,507
Stock-based compensation expenses	3,288	5,571
Other Noncash Income (Expense)	3,627	(390)
(Increase) Decrease in accounts receivable and other current assets	11,841	14,159
Increase (decrease) in accounts payable and accrued liabilities	(4,768)	7,299
Increase (decrease) in income taxes payable	(450)	543
Increase (decrease) in accrued interest	(7,606)	(8,575)
Net Cash Provided by Operating Activities	28,410	252,175
Cash Flows from Investing Activities:
Additions to property and equipment	(126,752)	(316,972)
Proceeds from the sale of property and equipment	977	145,535
Funds withdrawn from restricted cash account	0	6,501
Funds deposited into restricted cash account	0	18,345
Net Cash Used in Investing Activities	(125,775)	(183,281)
Cash Flows from Financing Activities:
Proceeds from bank borrowings	258,200	356,900
Payments of bank borrowings	(153,500)	(419,900)
Net proceeds from issuances of common stock	302	824
Purchase of treasury shares	(150)	(954)
Payments of debt issuance costs	(571)	0
Net Cash Used in Financing Activities	104,281	(63,130)
Net Increase (Decrease) in Cash and Cash Equivalents	6,916	5,764
Cash and Cash Equivalents at Beginning of Period	406	3,277
Cash and Cash Equivalents at End of Period	7,322	9,041
Supplemental Disclosures of Cash Flows Information:
Cash paid during period for interest, net of amounts capitalized	62,012	61,983
Cash paid during period for income taxes	$ 450	$ 150

General Information

General Information	9 Months Ended
	Sep. 30, 2015
Organization, Consolidation and Presentation of Financial Statements [Abstract]
General Information	(1) General Information The condensed consolidated financial statements included herein have been prepared by Swift Energy Company (“Swift Energy,” the “Company,” or “we”) and reflect necessary adjustments, all of which were of a recurring nature unless otherwise disclosed herein, and are in the opinion of our management necessary for a fair presentation. Certain information and note disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States have been omitted pursuant to the rules and regulations of the Securities and Exchange Commission. We believe that the disclosures presented are adequate to allow the information presented not to be misleading. The condensed consolidated financial statements should be read in conjunction with the audited financial statements and the notes thereto included in our Annual Report on Form 10-K for the fiscal year ended December 31, 2014 as filed with the Securities and Exchange Commission on March 2, 2015.

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2015
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	(2) Summary of Significant Accounting Policies Principles of Consolidation . The accompanying condensed 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 condensed consolidated financial statements. Intercompany balances and transactions have been eliminated in preparing the accompanying condensed consolidated financial statements. Subsequent Events . On November 2, 2015 we executed an amendment to our credit facility decreasing our borrowing base and commitment amount on our credit facility, changing certain of our financial covenant ratios, and providing for a borrowing base redetermination on or about February 1, 2016 if we have not reduced the current outstanding principal amount of our unsecured or subordinated debt by at least 50% by that date, along with other changes detailed in Note 5 of these condensed 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 , the related present value of estimated future net cash flows there-from, and the ceiling test impairment calculation, • 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 three months ended September 30, 2015 and 2014 , such internal costs capitalized totaled $3.1 million and $6.9 million , respectively. For the nine months ended September 30, 2015 and 2014 , such internal costs capitalized totaled $10.1 million and $20.9 million , respectively. Interest costs are also capitalized to unproved oil and natural gas properties (refer to Note 5 of these consolidated financial statements for further discussion on capitalized interest costs). The “Property and Equipment” balances on the accompanying condensed consolidated balance sheets are summarized for presentation purposes. The following is a detailed breakout of our “Property and Equipment” balances: (in thousands) September 30, December 31, Property and Equipment Proved oil and gas properties $ 5,910,250 $ 5,826,995 Unproved oil and gas properties 69,697 64,903 Furniture, fixtures, and other equipment 43,687 42,257 Less – Accumulated depreciation, depletion, and amortization (5,061,058 ) (3,839,118 ) Property and Equipment, Net $ 962,576 $ 2,095,037 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 on a property-by-property basis 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. 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”). 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. Principally due to the effects of pricing, and also due to the timing of projects and changes in our reserves product mix, for the three and nine months ended September 30, 2015 , we reported a non-cash impairment write-down, on a before-tax basis, of $321.5 million and $1.1 billion , 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 or remain at levels prevalent in the current period, it is likely that non-cash write-downs of our oil and natural gas properties will 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. However, due to current trends in commodity pricing it is likely that we will record additional ceiling test write-downs in future periods. 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 condensed consolidated balance sheets. Natural gas balancing receivables are reported in “Other current assets” on the accompanying condensed consolidated balance sheets when our ownership share of production exceeds sales. As of September 30, 2015 and December 31, 2014 , 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 September 30, 2015 and December 31, 2014 , we had an allowance for doubtful accounts of approximately $0.1 million . The allowance for doubtful accounts has been deducted from the total “Accounts receivable” balance on the accompanying condensed consolidated balance sheets. At September 30, 2015 , our “Accounts receivable” balance included $22.6 million for oil and gas sales, $9.6 million for joint interest owners, $3.4 million for severance tax credit receivables and $1.0 million for other receivables. 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. 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 condensed consolidated statements of operations. Our supervision fees are allocated to each well based on general and administrative costs incurred for well maintenance and support. The amount of supervision fees charged for the three and nine months ended September 30, 2015 and 2014 did not exceed our actual costs incurred. The total amount of supervision fees charged to the wells we operated were $2.1 million and $3.5 million for the three months ended September 30, 2015 and 2014 , respectively and $7.0 million and $9.2 million for the nine months ended September 30, 2015 and 2014 , respectively. Other Current Assets. Included in "Other current assets" on the accompanying condensed 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 $0.9 million at September 30, 2015 and $3.1 million at December 31, 2014 . Also included in "Other current assets" on the accompanying condensed consolidated balance sheets are prepaid expenses totaling $3.1 million and $3.9 million at September 30, 2015 and December 31, 2014 , respectively. 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. At September 30, 2015 , we did not have any accrued liability for uncertain tax positions and do not anticipate recognition of any significant liabilities for uncertain tax positions during the next 12 months. Our U.S. Federal income tax returns for 2007 forward, our Louisiana income tax returns from 1999 forward and our Texas franchise tax returns after 2009 remain subject to 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. For the three months ended September 30, 2015 , the tax benefit for the book loss was fully offset with an increase in our valuation allowance against our deferred tax assets. For the nine months ended September 30, 2015 , the tax benefit for the book loss was mostly offset with an increase in our valuation allowance against our deferred tax assets. Accounts Payable and Accrued Liabilities . The “Accounts payable and accrued liabilities” balances on the accompanying condensed consolidated balance sheets are summarized below (in thousands): September 30, December 31, Trade accounts payable (1) $ 17,600 $ 31,153 Accrued operating expenses 8,134 10,784 Accrued compensation costs 7,064 8,715 Asset retirement obligation – current portion 7,124 10,709 Accrued taxes 5,652 2,957 Other payables 3,542 3,926 Total accounts payable and accrued liabilities $ 49,116 $ 68,244 (1) Included in “trade accounts payable” are liabilities of approximately $2.2 million and $13.7 million at September 30, 2015 and December 31, 2014 , 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. These amounts do not include cash balances that are contractually restricted. 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 required to deposit 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. During the third quarter of 2014, 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 had performed the related development activities. The cash changes from the account during the third quarter of 2014 relating to Saka Energi’s contributions were shown in the operating activities section of the accompanying condensed consolidated statements of cash flows. The cash changes from the account during the third quarter of 2014 relating to Swift Energy’s contributions were reported in the investing activities section on the accompanying condensed consolidated statements of cash flows. Long-term Restricted Cash. Long-term restricted cash includes amounts held in escrow accounts to satisfy plugging and abandonment obligations. As of September 30, 2015 and December 31, 2014 , 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. These restricted cash balances are reported in “Other Long-Term Assets” on the accompanying condensed consolidated balance sheets. Treasury Stock. Our treasury stock repurchases are reported at cost and are included “Treasury stock held, at cost" on the accompanying condensed consolidated balance sheets. When the Company reissues treasury stock the gains are recorded in "Additional paid-in capital" ("APIC") on the accompanying condensed consolidated balance sheets, while the losses are recorded to APIC to the extent that previous net gains on the reissuance of treasury stock are available to offset the losses. If the loss is larger than the previous gains available then the loss is recorded to "Retained earnings (Accumulated deficit)" on the accompanying condensed consolidated balance sheets. For the nine months ended September 30, 2015 , the Company recorded losses of $4.9 million to "Retained earnings (Accumulated deficit)" as a result of treasury stock transactions. 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 requires entities 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. The guidance is effective for annual and interim reporting periods beginning after December 15, 2017. We are currently reviewing the new requirements to determine the impact of this guidance on our financial statements. In April 2015, the FASB issued ASU 2015-03, providing guidance on the presentation of debt issuance costs. The guidance requires debt issuance costs related to our long-term debt to be presented on the balance sheet as a reduction of the carrying amount of the long-term debt. This guidance is effective for fiscal years beginning after December 15, 2015 and for interim periods within those fiscal years, with early adoption permitted and retrospective application required. This guidance, which we plan to adopt beginning with the first quarter of 2016, is not expected to have a material impact on our financial statements. In July 2015, the FASB issued ASU 2015-11, which changes the measurement principle for inventory from the lower of cost or market to “lower of cost and net realizable value.” The standard simplifies the current guidance under which an entity must measure inventory at the lower of cost or market (market in this context is defined as one of three different measures, one of which is net realizable value). Net realizable value is defined as the “estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation.” The guidance is effective for fiscal years beginning after December 15, 2016, including interim periods thereafter, and must be applied prospectively after the date of adoption. We are currently reviewing the new requirement to determine the impact of this guidance on our financial statements.

Share-Based Compensation

Share-Based Compensation	9 Months Ended
	Sep. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-Based Compensation	(3) Share-Based Compensation We have various types of share-based compensation plans. Refer to our definitive proxy statement for our annual meeting of shareholders filed with the SEC on April 2, 2015, as well as Note 6 of our consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended December 31, 2014 , for additional information related to these share-based compensation plans. We follow guidance contained in FASB ASC 718 to account for share-based compensation. We receive a tax deduction for certain stock option exercises during the period the stock options 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. For the three months ended September 30, 2015 , there was no income tax shortfall in earnings, while for the three months ended September 30, 2014 we did recognize an income tax shortfall in earnings of $0.2 million . For the nine months ended September 30, 2015 and 2014 , we recognized an income tax shortfall in earnings of $1.4 million and $2.1 million , respectively, primarily related to restricted stock awards that vested at a price lower than the grant date fair value. Share-based compensation expense for awards issued to both employees and non-employees, which was recorded in “General and administrative, net” in the accompanying condensed consolidated statements of operations, was $1.1 million and $1.7 million for the three months ended September 30, 2015 and 2014 , respectively, and $3.1 million and $5.1 million for the nine months ended September 30, 2015 and 2014 , respectively. Share-based compensation recorded in lease operating cost was less than $0.1 million for the three months ended September 30, 2015 and 2014 and $0.1 million and $0.2 million for the nine months ended September 30, 2015 and 2014 , respectively. We also capitalized $0.4 million and $0.9 million of share-based compensation for the three months ended September 30, 2015 and 2014 , respectively, and capitalized $1.0 million and $2.9 million for the nine months ended September 30, 2015 and 2014 , 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 we amortize the awards on a straight-line basis over the life of the awards. Stock Option Awards We use the Black-Scholes-Merton option pricing model to estimate the fair value of stock option awards. During the nine months ended September 30, 2015 , 1,800 stock option awards expired leaving 1,330,390 stock option awards outstanding at September 30, 2015 . There was no other activity relating to our stock option awards during the nine months ended September 30, 2015 . As of September 30, 2015 , our stock option awards outstanding and exercisable had no aggregate intrinsic value since all outstanding stock option awards were out of the money, and we did not have any remaining unrecognized compensation cost related to stock option awards. At September 30, 2015 , the weighted average contract life of stock option awards outstanding and exercisable was 4.0 years. Restricted Stock Awards The plans, as described in Note 6 of our consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended December 31, 2014 , allow for the issuance of restricted stock awards that generally may not be sold or otherwise transferred until certain restrictions have lapsed. The unrecognized compensation cost related to these awards is expected to be expensed over the period the restrictions lapse (generally one to three years ). 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 September 30, 2015 , we had unrecognized compensation expense of $4.9 million related to restricted stock awards which is expected to be recognized over a weighted-average period of 1.4 years. The grant date fair value of shares vested during the nine months ended September 30, 2015 was $5.3 million . The following table represents restricted stock award activity for the nine months ended September 30, 2015 : Shares Wtd. Avg. Grant Price Restricted shares outstanding, beginning of period 1,414,012 $ 14.81 Restricted shares granted 609,238 $ 2.64 Restricted shares canceled (222,057 ) $ 13.84 Restricted shares vested (242,567 ) $ 21.66 Restricted shares outstanding, end of period 1,558,626 $ 9.12 Performance-Based Restricted Stock Units For the nine months ended September 30, 2015 , the Company granted 216,450 units of performance-based restricted stock units containing market conditions that require the price of our common stock to increase to $5.22 per share by December 31, 2017, the end of the performance period, before any payout is achieved. These units were granted at 100% of the target payout level with conditions of the grants allowing for a payout ranging between no payout and 200% of target. The compensation expense for these awards is based on the per unit grant date valuation using a Monte-Carlo simulation multiplied by the target payout level. The payout level is calculated based on actual stock price performance achieved during the performance period. The awards have a cliff vesting period of 3.0 years . As of September 30, 2015 , we had unrecognized compensation expense of $1.1 million related to our restricted stock units, which is expected to be recognized over a weighted-average period of 1.6 years . No shares vested during the nine months ended September 30, 2015 and 2014 . The weighted average grant date fair value for the restricted stock units granted during the nine months ended September 30, 2015 was $1.98 per unit. The following table represents restricted stock unit activity for the nine months ended September 30, 2015 : Shares Wtd. Avg. Restricted stock units outstanding, beginning of period 374,950 $ 13.36 Restricted stock units granted 216,450 $ 1.98 Restricted stock units canceled — $ — Restricted stock units vested — $ — Restricted stock units outstanding, end of period 591,400 $ 9.20 Cash-Settled Restricted Stock Units (Liability Awards) During the nine months ended September 30, 2015 , the Company granted 147,812 units of cash-settled restricted stock units. These grants require a cash payout based on the fair value of the stock price on the date of the next Annual Shareholder Meeting in May of 2016. The grants have a cliff vesting period of approximately 1.0 year while the compensation expense and corresponding liability are remeasured quarterly over the corresponding service period. The Company recorded a liability of less than $0.1 million for these awards in "Accounts Payable and accrued liabilities” on the accompanying condensed consolidated balance sheet as of September 30, 2015 .

Earnings Per Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2015
Earnings Per Share [Abstract]
Earnings Per Share	(4) 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 three and nine months ended September 30, 2015 , 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 three and nine months ended September 30, 2014 , 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 three and nine months ended September 30, 2015 and 2014 (in thousands, except per share amounts): Three Months Ended September 30, 2015 Three Months Ended September 30, 2014 Net Loss Shares Per Share Amount Net Income Shares Per Share Amount Basic EPS: Net Income (Loss) and Share Amounts $ (354,588 ) 44,546 $ (7.96 ) $ 2,474 43,850 $ 0.06 Dilutive Securities: Restricted Stock Awards — 564 Restricted Stock Units — 59 Diluted EPS: Net Income (Loss) and Assumed Share Conversions $ (354,588 ) 44,546 $ (7.96 ) $ 2,474 44,473 $ 0.06 Nine Months Ended September 30, 2015 Nine Months Ended September 30, 2014 Net Loss Shares Per Share Net Income Shares Per Share Basic EPS: Net Income (Loss) and Share Amounts $ (1,124,532 ) 44,431 $ (25.31 ) $ 14,743 43,768 $ 0.34 Dilutive Securities: Restricted Stock Awards — 469 Restricted Stock Units — 62 Diluted EPS: Net Income (Loss) and Assumed Share Conversions $ (1,124,532 ) 44,431 $ (25.31 ) $ 14,743 44,299 $ 0.33 Approximately 1.3 million and 1.4 million stock options to purchase shares were not included in the computation of Diluted EPS for the three months ended September 30, 2015 and 2014 because they were antidilutive. We also had approximately 1.3 million and 1.4 million stock options to purchase shares were not included in the computation of Diluted EPS for the nine months ended September 30, 2015 and 2014 , because these stock options were antidilutive. Approximately 1.0 million and 0.2 million restricted stock awards for the three months ended September 30, 2015 and 2014 , respectively, and approximately 0.8 million and 0.3 million restricted stock awards for the nine months ended September 30, 2015 and 2014 , respectively, were not included in the computation of Diluted EPS because they were antidilutive. Approximately 1.2 million and 0.7 million shares for the three months ended September 30, 2015 and 2014 , respectively, and approximately 1.2 million and 0.7 million shares for the nine months ended September 30, 2015 and 2014 , respectively, 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 because the performance and market conditions had not been met, assuming the end of the reporting period was the end of the performance period.

Long-Term Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Long-Term Debt	(5) Long-Term Debt Our long-term debt as of September 30, 2015 and December 31, 2014 , was as follows (in thousands): September 30, 2015 December 31, 2014 7.125% senior notes due in 2017 $ 250,000 $ 250,000 8.875% senior notes due in 2020 (1) 223,043 222,775 7.875% senior notes due in 2022 (1) 404,089 404,459 Bank Borrowings due in 2017 302,000 197,300 Long-Term Debt (1) $ 1,179,132 $ 1,074,534 (1) Amounts are shown net of any debt discount or premium As of September 30, 2015 , we had $302.0 million of outstanding bank borrowings on our credit facility which has a maturity date of November 1, 2017. The maturities on our senior notes are $250.0 million in 2017, $225.0 million in 2020 and $400.0 million in 2022. We had capitalized interest on our unproved properties in the amount of $1.2 million for the three months ended September 30, 2015 and 2014 , respectively. We had capitalized interest on our unproved properties in the amount of $3.6 million and $3.7 million for the nine months ended September 30, 2015 and 2014 , respectively. Debt Issuance Costs . Legal fees, accounting fees, underwriting fees, printing costs, and other direct expenses associated with extensions of our bank credit facility and public debt offerings are capitalized and then amortized on an effective interest basis over the life of each of the respective senior note offerings and credit facility. The 7.125% senior notes due in 2017 mature on June 1, 2017 , and the balance of their issuance costs at September 30, 2015 , was $0.9 million . The 8.875% senior notes due in 2020 mature on January 15, 2020 , and the balance of their issuance costs at September 30, 2015 , was $2.7 million . The 7.875% senior notes due in 2022 mature on March 1, 2022 , and the balance of their issuance costs at September 30, 2015 , was $5.4 million . The balance of our revolving credit facility issuance costs at September 30, 2015 , was $2.0 million . Bank Borrowings . Effective November 2, 2015 , we executed an amendment to our credit facility agreement lowering our borrowing base and commitment amount, changing our financial covenant ratios as noted below, and providing for a borrowing base redetermination on or about February 1, 2016 if we have not reduced the current outstanding principal amount of our unsecured or subordinated debt by at least 50% by that date, along with other changes detailed below. The borrowing base and commitment amount under our credit facility were decreased from $375.0 million to $330.0 million while the maturity date of November 1, 2017 remained unchanged, subject to being accelerated to March 2, 2017 if by that date the maturity dates of our existing Senior Notes are not extended to May 1, 2018 or later, or if those Senior Notes are not repurchased, redeemed or refinanced. Effective November 2, 2015 , the amendment made changes to the existing adjusted working capital ratio, interest coverage ratio and senior secured leverage ratio (all as defined in the Credit Agreement) and removed the existing liquidity requirement in order for us to pay interest on our existing senior notes or any new debt (after giving effect to such interest payment). The adjusted working capital ratio was amended to require the ratio to not be less than 0.5 to 1.0 for each of the quarters up to and ending on December 31, 2016, returning to a ratio of not less than 1.0 to 1.0 at any time thereafter. The interest coverage ratio was amended to require the ratio to not be less than 1.15 to 1.0 for the quarters ending on December 31, 2015 through June 30, 2016, 1.3 to 1.0 for the quarters ending September 30, 2016 through December 31, 2016, and 2.0 to 1.0 any time thereafter. The senior secured leverage ratio was amended to require the ratio to not be greater than 3.5 to 1.0 for the quarters ending December 31, 2015 through June 30, 2016, 3.0 to 1.0 for the quarters ending September 30, 2016 through December 31, 2016, and 2.5 to 1.0 any time thereafter. The amendment also modified other requirements as noted in the paragraphs below. Based upon our current estimates of production and current commodity futures prices, our ability to remain in compliance with these modified financial covenant ratios in future periods is uncertain and will be impacted by a number of factors, including those which are not within our control. Since inception, no cash dividends have been declared on our common stock. As of September 30, 2015 , the terms of the credit facility required us to secure the facility with collateral equal to at least 75% (increasing to 95% , effective November 2, 2015 ) 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 September 30, 2015 , we were in compliance with these provisions. We had $302.0 million and $197.3 million in outstanding borrowings under our credit facility at September 30, 2015 and December 31, 2014 , respectively. As of September 30, 2015 , the interest rate on our credit facility was 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 was 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 then applied. The applicable margins vary depending on the level of outstanding debt with escalating rates of 75 to 175 basis points (increasing to 100 to 200 basis points effective November 2, 2015 ) above the Alternative Base Rate and escalating rates of 175 to 275 basis points (increasing to 200 to 300 basis points effective November 2, 2015 ) for Eurodollar rate loans. At September 30, 2015 , the lead bank's prime rate was 3.25% . The commitment fee terms associated with the credit facility were 0.50% for the three months ended September 30, 2015 . At September 30, 2015 , the terms of our credit facility included, 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. At September 30, 2015 , our bank credit agreement contained financial covenants detailing certain minimum financial ratios that must be maintained. The first was 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 was met at September 30, 2015 as the Company's ratio at that date was 1.3 to 1.0. The second ratio was an interest coverage ratio (as amended on May 1, 2015), calculated on a trailing twelve month basis of EBITDAX to interest expense (as defined in the Credit Agreement), of no less than 1.5 to 1.0, which was met at September 30, 2015 as the Company's ratio at that date was 2.1 to 1.0. The third ratio was a new senior secured leverage ratio (as defined in the Credit Agreement, effective on May 1, 2015), requiring that the ratio of senior secured liabilities on the last day of the quarter to EBITDAX, calculated on a trailing twelve month basis, not be greater than 3.0 to 1.0, which was met as the Company's September 30, 2015 ratio was 2.0 to 1.0. The May 1, 2015 amendment also added a new liquidity requirement (as defined in the Credit Agreement) effective July 1, 2015 (and expiring on November 2, 2015 due to the most recent amendment) which effectively required that at the date of any payment of interest in respect to the existing senior notes or any new debt (after giving effect to such interest payment), the unused borrowing base may not be less than 15% of the commitment amount then in effect. We were in compliance with this covenant during the time period in which it was in effect. Interest expense on the credit facility, including commitment fees and amortization of debt issuance costs, totaled $2.3 million and $1.7 million for the three months ended September 30, 2015 and 2014 , respectively, and totaled $6.3 million and $5.9 million for the nine months ended September 30, 2015 and 2014 , respectively. The amount of commitment fees included in interest expense, net was $0.1 million and $0.2 million for the three months ended September 30, 2015 and 2014 , respectively, and was $0.5 million and $0.6 million for the nine months ended September 30, 2015 and 2014 , respectively. 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 condensed 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 condensed 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 twelve-month intervals to 100% in 2020 and thereafter. In addition, 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 condensed 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 September 30, 2015 . Interest expense on the senior notes due in 2022, including amortization of debt issuance costs and debt premium, totaled $7.9 million for the three months ended September 30, 2015 and 2014 and $23.7 million for the nine months ended September 30, 2015 and 2014 . 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 condensed 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. 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 twelve-month 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 condensed 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 September 30, 2015 . Interest expense on the senior notes due in 2020, including amortization of debt issuance costs and debt discount, totaled $5.2 million for the three months ended September 30, 2015 and 2014 and $15.6 million for the nine months ended September 30, 2015 and 2014 . 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. We may redeem some or all of these notes, with certain restrictions, starting at a redemption price of 100% of the principal, plus accrued and unpaid interest. 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 condensed 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 September 30, 2015 . Interest expense on the senior notes due in 2017, including amortization of debt issuance costs, totaled $4.6 million for the three months ended September 30, 2015 and 2014 and $13.7 million for the nine months ended September 30, 2015 and 2014 , respectively.

Acquisitions and Dispositions

Acquisitions and Dispositions	9 Months Ended
	Sep. 30, 2015
Business Combinations [Abstract]
Acquisitions and Dispositions	(6) Acquisitions and Dispositions 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. There were no other material acquisitions or dispositions in the nine months ended September 30, 2015 or 2014 .

Price-Risk Management Price-Ris

Price-Risk Management Price-Risk Management (Notes)	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Price-Risk Management Activities	(7) Price-Risk Management Activities The Company follows FASB ASC 815-10, which requires that changes in the derivative’s fair value are recognized in earnings. The changes in the fair value of our derivatives are recognized in "Price-risk management and other, net” on the accompanying condensed 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 swaps, floors, calls, collars and participating collars. During the three months ended September 30, 2015 and 2014 , we recorded a net gain of less than of $0.1 million and a net gain of $5.0 million , respectively, and for the nine months ended September 30, 2015 and 2014 , we recorded a net gain of $0.3 million and a net loss of $2.7 million , respectively, relating to our derivative activities. The effects of our derivatives are included in the "Other" section of our operating activities on the accompanying condensed 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 current unsettled derivative assets at September 30, 2015 was $0.1 million and was recognized on the accompanying condensed consolidated balance sheet in “Other current assets.” There were no material unsettled derivative liabilities as of September 30, 2015 . At September 30, 2015 , we also had an immaterial amount of receivables for settled derivatives recognized on the accompanying condensed consolidated balance sheet in "Accounts receivable", which were subsequently received in October 2015 . The Company uses an International Swap and Derivatives Association "ISDA" master agreement for our 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 have shown a net derivative fair value asset of $0.1 million at September 30, 2015 . For further discussion related to the fair value of the Company's derivatives, refer to Note 8 of these condensed consolidated financial statements. The following tables summarize the weighted average prices and future production volumes for our unsettled derivative contracts in place as of September 30, 2015 : Natural Gas Basis Derivatives (East Texas Houston Ship Channel Settlements) Total Volumes (MMBtu) Swap Fixed Price 2015 Contracts Swaps 1,220,000 $ (0.016 )

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	(8) Fair Value Measurements FASB ASC 820-10 defines fair value, establishes guidelines for measuring fair value and expands disclosure about fair value measurements. Our financial instruments consist of cash and cash equivalents, restricted cash, accounts receivable, accounts payable, bank borrowings, and senior notes. The carrying amounts of cash and cash equivalents, restricted cash, 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 September 30, 2015 and December 31, 2014 , the fair value and carrying value of our senior notes was as follows (in millions): September 30, 2015 December 31, 2014 Fair Value Carrying Value Fair Value Carrying Value 7.125% senior notes due in 2017 $ 67.5 $ 250.0 $ 153.0 $ 250.0 8.875% senior notes due in 2020 $ 58.5 $ 223.0 $ 133.1 $ 222.8 7.875% senior notes due in 2022 $ 108.0 $ 404.1 $ 198.0 $ 404.5 Our senior notes due in 2017, 2020 and 2022 are stated at carrying value on our accompanying condensed consolidated balance sheets, 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 and liabilities that are measured at fair value as of September 30, 2015 and December 31, 2014 , and are categorized using the fair value hierarchy. For additional discussion related to the fair value of the Company's derivatives, refer to Note 7 of these condensed 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 Assets / (Liabilities) Quoted Prices in Active markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) September 30, 2015 Assets: Natural Gas Basis Derivatives $ 0.1 $ — $ 0.1 $ — 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 — Our unsettled derivative assets and liabilities in the table above are measured at gross fair value and are shown on the accompanying condensed 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 that are not supported by market activity and have significant unobservable inputs.

Asset Retirement Obligations As

Asset Retirement Obligations Asset Retirement Obligations (Notes)	9 Months Ended
	Sep. 30, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	(9) 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 condensed 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 obligation (in thousands): 2015 Asset Retirement Obligations recorded as of January 1 $ 72,831 Accretion expense 4,156 Liabilities incurred for new wells and facilities construction 147 Reductions due to sold and abandoned wells and facilities (4,574 ) Revisions in estimates 12 Asset Retirement Obligations as of September 30 $ 72,572 At September 30, 2015 and December 31, 2014 , approximately $7.1 million and $10.7 million of our asset retirement obligations were classified as a current liability in “Accounts payable and accrued liabilities” on the accompanying condensed consolidated balance sheets.

Condensed Consolidating Financi

Condensed Consolidating Financial Information	9 Months Ended
	Sep. 30, 2015
Guarantees [Abstract]
Condensed Consolidating Financial Information	(10) 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.

Commitments and Contingencies C

Commitments and Contingencies Commitments and Contingencies	9 Months Ended
	Sep. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies In January of 2015 the Company entered into a new eleven year lease agreement for office space in Houston, Texas. The operating lease commenced on March 1, 2015 and may be terminated after seven years. As of September 30, 2015, the minimum contractual obligations are approximately $24 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. During the second quarter of 2015, the Company entered into an additional gas transportation agreement covering transportation from 2016 to 2020. The agreement increased our minimum contractual obligations, over the amounts reported in our Annual Report on Form 10-K for the year ending December 31, 2014 by approximately $39 million , with no change to our obligations during 2015. Refer to Management's Discussion and Analysis of these condensed consolidated financial statements for further discussion. We had no other material changes from amounts referenced under Note 5 in our Notes to consolidated financial statements from our Annual Report on Form 10-K for the year ending December 31, 2014 .

Summary of Significant Accoun19

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2015
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation . The accompanying condensed 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 condensed consolidated financial statements. Intercompany balances and transactions have been eliminated in preparing the accompanying condensed consolidated financial statements.
Subsequent Events	Subsequent Events . On November 2, 2015 we executed an amendment to our credit facility decreasing our borrowing base and commitment amount on our credit facility, changing certain of our financial covenant ratios, and providing for a borrowing base redetermination on or about February 1, 2016 if we have not reduced the current outstanding principal amount of our unsecured or subordinated debt by at least 50% by that date, along with other changes detailed in Note 5 of these condensed 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 , the related present value of estimated future net cash flows there-from, and the ceiling test impairment calculation, • 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	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 three months ended September 30, 2015 and 2014 , such internal costs capitalized totaled $3.1 million and $6.9 million , respectively. For the nine months ended September 30, 2015 and 2014 , such internal costs capitalized totaled $10.1 million and $20.9 million , respectively. Interest costs are also capitalized to unproved oil and natural gas properties (refer to Note 5 of these consolidated financial statements for further discussion on capitalized interest costs). The “Property and Equipment” balances on the accompanying condensed consolidated balance sheets are summarized for presentation purposes. The following is a detailed breakout of our “Property and Equipment” balances: (in thousands) September 30, December 31, Property and Equipment Proved oil and gas properties $ 5,910,250 $ 5,826,995 Unproved oil and gas properties 69,697 64,903 Furniture, fixtures, and other equipment 43,687 42,257 Less – Accumulated depreciation, depletion, and amortization (5,061,058 ) (3,839,118 ) Property and Equipment, Net $ 962,576 $ 2,095,037 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 on a property-by-property basis 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. 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”). 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. Principally due to the effects of pricing, and also due to the timing of projects and changes in our reserves product mix, for the three and nine months ended September 30, 2015 , we reported a non-cash impairment write-down, on a before-tax basis, of $321.5 million and $1.1 billion , respectively, on our oil and natural gas properties.
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 condensed consolidated balance sheets. Natural gas balancing receivables are reported in “Other current assets” on the accompanying condensed consolidated balance sheets when our ownership share of production exceeds sales. As of September 30, 2015 and December 31, 2014 , 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 September 30, 2015 and December 31, 2014 , we had an allowance for doubtful accounts of approximately $0.1 million . The allowance for doubtful accounts has been deducted from the total “Accounts receivable” balance on the accompanying condensed consolidated balance sheets.
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 condensed consolidated statements of operations. Our supervision fees are allocated to each well based on general and administrative costs incurred for well maintenance and support.
Other Current Assets	Other Current Assets. Included in "Other current assets" on the accompanying condensed 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.
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 condensed consolidated balance sheets are summarized below
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. These amounts do not include cash balances that are contractually restricted.
Saka Energi Transaction	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 required to deposit 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. During the third quarter of 2014, 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 had performed the related development activities. The cash changes from the account during the third quarter of 2014 relating to Saka Energi’s contributions were shown in the operating activities section of the accompanying condensed consolidated statements of cash flows. The cash changes from the account during the third quarter of 2014 relating to Swift Energy’s contributions were reported in the investing activities section on the accompanying condensed consolidated statements of cash flows.
Long-term Restricted Cash	Long-term Restricted Cash. Long-term restricted cash includes amounts held in escrow accounts to satisfy plugging and abandonment obligations. As of September 30, 2015 and December 31, 2014 , 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. These restricted cash balances are reported in “Other Long-Term Assets” on the accompanying condensed consolidated balance sheets.
Treasury Stock	Treasury Stock. Our treasury stock repurchases are reported at cost and are included “Treasury stock held, at cost" on the accompanying condensed consolidated balance sheets. When the Company reissues treasury stock the gains are recorded in "Additional paid-in capital" ("APIC") on the accompanying condensed consolidated balance sheets, while the losses are recorded to APIC to the extent that previous net gains on the reissuance of treasury stock are available to offset the losses. If the loss is larger than the previous gains available then the loss is recorded to "Retained earnings (Accumulated deficit)" on the accompanying condensed consolidated balance sheets.
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 requires entities 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. The guidance is effective for annual and interim reporting periods beginning after December 15, 2017. We are currently reviewing the new requirements to determine the impact of this guidance on our financial statements. In April 2015, the FASB issued ASU 2015-03, providing guidance on the presentation of debt issuance costs. The guidance requires debt issuance costs related to our long-term debt to be presented on the balance sheet as a reduction of the carrying amount of the long-term debt. This guidance is effective for fiscal years beginning after December 15, 2015 and for interim periods within those fiscal years, with early adoption permitted and retrospective application required. This guidance, which we plan to adopt beginning with the first quarter of 2016, is not expected to have a material impact on our financial statements. In July 2015, the FASB issued ASU 2015-11, which changes the measurement principle for inventory from the lower of cost or market to “lower of cost and net realizable value.” The standard simplifies the current guidance under which an entity must measure inventory at the lower of cost or market (market in this context is defined as one of three different measures, one of which is net realizable value). Net realizable value is defined as the “estimated selling price in the ordinary course of business, less reasonably predictable costs of completion, disposal and transportation.” The guidance is effective for fiscal years beginning after December 15, 2016, including interim periods thereafter, and must be applied prospectively after the date of adoption. We are currently reviewing the new requirement to determine the impact of this guidance on our financial statements.

Share-Based Compensation Share-

Share-Based Compensation Share-Based Compensation (Policies)	9 Months Ended
	Sep. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Share-based Compensation, Option and Incentive Plans Policy	Share-Based Compensation We have various types of share-based compensation plans. Refer to our definitive proxy statement for our annual meeting of shareholders filed with the SEC on April 2, 2015, as well as Note 6 of our consolidated financial statements in our Annual Report on Form 10-K for the fiscal year ended December 31, 2014 , for additional information related to these share-based compensation plans. We follow guidance contained in FASB ASC 718 to account for share-based compensation. We receive a tax deduction for certain stock option exercises during the period the stock options 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.

Earnings Per Share Earnings Per

Earnings Per Share Earnings Per Share (Policies)	9 Months Ended
	Sep. 30, 2015
Earnings Per Share [Abstract]
Earnings Per Share, Policy	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 three and nine months ended September 30, 2015 , 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 three and nine months ended September 30, 2014 , and are discussed below.

Long-Term Debt Long-Term Debt (

Long-Term Debt Long-Term Debt (Policies)	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Debt Issuance Costs, Policy	Debt Issuance Costs . Legal fees, accounting fees, underwriting fees, printing costs, and other direct expenses associated with extensions of our bank credit facility and public debt offerings are capitalized and then amortized on an effective interest basis over the life of each of the respective senior note offerings and credit facility.

Price-Risk Management Price-R23

Price-Risk Management Price-Risk Management (Policies)	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Price-Risk Management Activities, Policy	Price-Risk Management Activities The Company follows FASB ASC 815-10, which requires that changes in the derivative’s fair value are recognized in earnings. The changes in the fair value of our derivatives are recognized in "Price-risk management and other, net” on the accompanying condensed 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 swaps, floors, calls, collars and participating collars.

Fair Value Measurements Fair Va

Fair Value Measurements Fair Value Disclosures (Policies)	9 Months Ended
	Sep. 30, 2015
Fair Value Disclosures [Abstract]
Fair Value of Financial Instruments, Policy	Fair Value Measurements FASB ASC 820-10 defines fair value, establishes guidelines for measuring fair value and expands disclosure about fair value measurements. Our financial instruments consist of cash and cash equivalents, restricted cash, accounts receivable, accounts payable, bank borrowings, and senior notes. The carrying amounts of cash and cash equivalents, restricted cash, accounts receivable, and accounts payable approximate fair value due to the highly liquid or short-term nature of these instruments.

Asset Retirement Obligations 25

Asset Retirement Obligations Asset Retirement Obligations (Policies)	9 Months Ended
	Sep. 30, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations, Policy	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 condensed consolidated balance sheets. This guidance requires us to record a liability for the fair value of our dismantlement and abandonment costs, excluding salvage values.

Commitments and Contingencies26

Commitments and Contingencies Commitments and Contingencies (Policies)	9 Months Ended
	Sep. 30, 2015
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies, Policy	(11) Commitments and Contingencies In January of 2015 the Company entered into a new eleven year lease agreement for office space in Houston, Texas. The operating lease commenced on March 1, 2015 and may be terminated after seven years. As of September 30, 2015, the minimum contractual obligations are approximately $24 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. During the second quarter of 2015, the Company entered into an additional gas transportation agreement covering transportation from 2016 to 2020. The agreement increased our minimum contractual obligations, over the amounts reported in our Annual Report on Form 10-K for the year ending December 31, 2014 by approximately $39 million , with no change to our obligations during 2015. Refer to Management's Discussion and Analysis of these condensed consolidated financial statements for further discussion. We had no other material changes from amounts referenced under Note 5 in our Notes to consolidated financial statements from our Annual Report on Form 10-K for the year ending December 31, 2014 .

Summary of Significant Accoun27

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2015
Accounting Policies [Abstract]
Property and Equipment	The following is a detailed breakout of our “Property and Equipment” balances: (in thousands) September 30, December 31, Property and Equipment Proved oil and gas properties $ 5,910,250 $ 5,826,995 Unproved oil and gas properties 69,697 64,903 Furniture, fixtures, and other equipment 43,687 42,257 Less – Accumulated depreciation, depletion, and amortization (5,061,058 ) (3,839,118 ) Property and Equipment, Net $ 962,576 $ 2,095,037
Accounts Payable and Accrued Liabilities	The “Accounts payable and accrued liabilities” balances on the accompanying condensed consolidated balance sheets are summarized below (in thousands): September 30, December 31, Trade accounts payable (1) $ 17,600 $ 31,153 Accrued operating expenses 8,134 10,784 Accrued compensation costs 7,064 8,715 Asset retirement obligation – current portion 7,124 10,709 Accrued taxes 5,652 2,957 Other payables 3,542 3,926 Total accounts payable and accrued liabilities $ 49,116 $ 68,244 (1) Included in “trade accounts payable” are liabilities of approximately $2.2 million and $13.7 million at September 30, 2015 and December 31, 2014 , respectively, for outstanding checks.

Share-Based Compensation (Table

Share-Based Compensation (Tables)	9 Months Ended
	Sep. 30, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Restricted stock activity	The following table represents restricted stock award activity for the nine months ended September 30, 2015 : Shares Wtd. Avg. Grant Price Restricted shares outstanding, beginning of period 1,414,012 $ 14.81 Restricted shares granted 609,238 $ 2.64 Restricted shares canceled (222,057 ) $ 13.84 Restricted shares vested (242,567 ) $ 21.66 Restricted shares outstanding, end of period 1,558,626 $ 9.12
Restricted stock units activity	The following table represents restricted stock unit activity for the nine months ended September 30, 2015 : Shares Wtd. Avg. Restricted stock units outstanding, beginning of period 374,950 $ 13.36 Restricted stock units granted 216,450 $ 1.98 Restricted stock units canceled — $ — Restricted stock units vested — $ — Restricted stock units outstanding, end of period 591,400 $ 9.20

Earnings Per Share (Tables)

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2015
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 three and nine months ended September 30, 2015 and 2014 (in thousands, except per share amounts): Three Months Ended September 30, 2015 Three Months Ended September 30, 2014 Net Loss Shares Per Share Amount Net Income Shares Per Share Amount Basic EPS: Net Income (Loss) and Share Amounts $ (354,588 ) 44,546 $ (7.96 ) $ 2,474 43,850 $ 0.06 Dilutive Securities: Restricted Stock Awards — 564 Restricted Stock Units — 59 Diluted EPS: Net Income (Loss) and Assumed Share Conversions $ (354,588 ) 44,546 $ (7.96 ) $ 2,474 44,473 $ 0.06 Nine Months Ended September 30, 2015 Nine Months Ended September 30, 2014 Net Loss Shares Per Share Net Income Shares Per Share Basic EPS: Net Income (Loss) and Share Amounts $ (1,124,532 ) 44,431 $ (25.31 ) $ 14,743 43,768 $ 0.34 Dilutive Securities: Restricted Stock Awards — 469 Restricted Stock Units — 62 Diluted EPS: Net Income (Loss) and Assumed Share Conversions $ (1,124,532 ) 44,431 $ (25.31 ) $ 14,743 44,299 $ 0.33

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2015
Debt Disclosure [Abstract]
Long-term debt	Our long-term debt as of September 30, 2015 and December 31, 2014 , was as follows (in thousands): September 30, 2015 December 31, 2014 7.125% senior notes due in 2017 $ 250,000 $ 250,000 8.875% senior notes due in 2020 (1) 223,043 222,775 7.875% senior notes due in 2022 (1) 404,089 404,459 Bank Borrowings due in 2017 302,000 197,300 Long-Term Debt (1) $ 1,179,132 $ 1,074,534 (1) Amounts are shown net of any debt discount or premium

Price-Risk Management Price-R31

Price-Risk Management Price-Risk Management (Tables)	9 Months Ended
	Sep. 30, 2015
Derivative Instruments and Hedging Activities Disclosure [Abstract]
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 September 30, 2015 : Natural Gas Basis Derivatives (East Texas Houston Ship Channel Settlements) Total Volumes (MMBtu) Swap Fixed Price 2015 Contracts Swaps 1,220,000 $ (0.016 )

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2015
Fair Value Disclosures [Abstract]
Fair value of senior notes	Based upon quoted market prices as of September 30, 2015 and December 31, 2014 , the fair value and carrying value of our senior notes was as follows (in millions): September 30, 2015 December 31, 2014 Fair Value Carrying Value Fair Value Carrying Value 7.125% senior notes due in 2017 $ 67.5 $ 250.0 $ 153.0 $ 250.0 8.875% senior notes due in 2020 $ 58.5 $ 223.0 $ 133.1 $ 222.8 7.875% senior notes due in 2022 $ 108.0 $ 404.1 $ 198.0 $ 404.5
Fair value of plan assets	The following table presents our assets and liabilities that are measured at fair value as of September 30, 2015 and December 31, 2014 , and are categorized using the fair value hierarchy. For additional discussion related to the fair value of the Company's derivatives, refer to Note 7 of these condensed 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 Assets / (Liabilities) Quoted Prices in Active markets for Identical Assets (Level 1) Significant Other Observable Inputs (Level 2) Significant Unobservable Inputs (Level 3) September 30, 2015 Assets: Natural Gas Basis Derivatives $ 0.1 $ — $ 0.1 $ — 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 —

Asset Retirement Obligations 33

Asset Retirement Obligations Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2015
Asset Retirement Obligation Disclosure [Abstract]
Roll-forward of our asset retirement obligations	The following provides a roll-forward of our asset retirement obligation (in thousands): 2015 Asset Retirement Obligations recorded as of January 1 $ 72,831 Accretion expense 4,156 Liabilities incurred for new wells and facilities construction 147 Reductions due to sold and abandoned wells and facilities (4,574 ) Revisions in estimates 12 Asset Retirement Obligations as of September 30 $ 72,572

Summary of Significant Accoun34

Summary of Significant Accounting Policies (Details) - USD ($) $ in Thousands		Sep. 30, 2015	Dec. 31, 2014
Property and Equipment
Proved oil and gas properties		$ 5,910,250	$ 5,826,995
Unproved oil and gas properties		69,697	64,903
Furniture, fixtures, and other equipment		43,687	42,257
Less - Accumulated depreciation, depletion, and amortization		(5,061,058)	(3,839,118)
Property and Equipment, Net		962,576	2,095,037
Accounts Payable and Accrued Liabilities
Trade accounts payable	[1]	17,600	31,153
Accrued operating expenses		8,134	10,784
Accrued payroll costs		7,064	8,715
Asset retirement obligation - current portion		7,124	10,709
Accrued taxes		5,652	2,957
Other payables		3,542	3,926
Total accounts payable and accrued liabilities		$ 49,116	$ 68,244
[1]	Included in “trade accounts payable” are liabilities of approximately $2.2 million and $13.7 million at September 30, 2015 and December 31, 2014, respectively, for outstanding checks.

Summary of Significant Accoun35

Summary of Significant Accounting Policies (Details Textual) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Feb. 01, 2016	Dec. 31, 2014USD ($)	Jul. 15, 2014a
Summary of Significant Accounting Policies (Textual) [Abstract]
Total capitalized internal costs	$ 3,100	$ 6,900	$ 10,100	$ 20,900
Discount rate for estimated future net revenues from proved properties			10.00%
Write-down of oil and gas properties	321,522	0	$ 1,084,595	0
Allowance for doubtful accounts receivable, current	100		100			$ 100
Accounts receivable, gross	22,600		22,600			34,800
Accounts receivable related to joint interest owners	9,600		9,600			8,400
Severance tax receivable	3,400		3,400			3,100
Other receivables	1,000		$ 1,000			2,200
Percentage of working interest in wells			100.00%
Total amount of supervision fees charged to wells	2,100	$ 3,500	$ 7,000	$ 9,200
Inventories carried at cost	900		900			3,100
Prepaid expenses	3,100		3,100			3,900
Outstanding checks included in trade accounts payable	2,200		2,200			13,700
Acreage Sold in Oil and Gas Properties | a							8,300
Participation Interest Sold in Oil and Gas Properties							36.00%
Restricted cash and cash equivalents included in other long term assets	$ 1,000		1,000			$ 1,000
Treasury stock reissued at lower than repurchase price			$ 4,900
Minimum [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Estimated useful lives of property			2 years
Maximum [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Estimated useful lives of property			20 years
Line of Credit [Member] | Subsequent Event [Member]
Summary of Significant Accounting Policies (Textual) [Abstract]
Debt Instrument, Borrowing Base Redetermination Acceleration Clause					50.00%

Share-Based Compensation (Detai

Share-Based Compensation (Details Textual) - USD ($)	Sep. 30, 2015	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014
Share-Based Compensation (Details Textual)
Tax shortfall in earnings related to share-based compensation		$ 0	$ 200,000	$ 1,400,000	$ 2,100,000
Stock-based compensation expenses				3,288,000	5,571,000
Share-based compensation (capitalized)		$ 400,000	900,000	$ 1,000,000	2,900,000
Employee Stock Option [Member]
Share-Based Compensation (Details Textual)
Expired stock option awards				(1,800)
Options outstanding, end of period, shares	1,330,390	1,330,390		1,330,390
Stock option awards exercisable aggregate intrinsic value	$ 0	$ 0		$ 0
Stock option awards outstanding aggregate intrinsic value	0	0		0
Stock option award unrecognized compensation cost	$ 0	$ 0		$ 0
Remaining contract life of outstanding stock options	4 years
Remaining contract life of exercisable stock options	4 years
Restricted Stock Awards [Member]
Restricted stock activity
Restricted shares outstanding, beginning of period, shares				1,414,012
Restricted shares outstanding, beginning of period, weighted average price				$ 14.81
Restricted shares granted, shares				609,238
Restricted shares granted, weighted average price				$ 2.64
Restricted shares canceled, shares				(222,057)
Restricted shares canceled, weighted average price				$ 13.84
Restricted shares vested, shares				(242,567)
Restricted shares vested, weighted average price				$ 21.66
Restricted shares outstanding, end of period, shares	1,558,626	1,558,626		1,558,626
Restricted shares outstanding, end of period, weighted average price	$ 9.12	$ 9.12		$ 9.12
Share-Based Compensation (Details Textual)
Unrecognized compensation cost for stock grants	$ 4,900,000	$ 4,900,000		$ 4,900,000
Weighted average remaining recognition period of cost for stock grants				1 year 5 months
Grant date fair value of shares vested				$ 5,300,000
Restricted Stock Units (RSUs) [Member]
Restricted stock activity
Restricted shares outstanding, beginning of period, shares				374,950
Restricted shares outstanding, beginning of period, weighted average price				$ 13.36
Restricted shares granted, shares				216,450
Restricted shares granted, weighted average price				$ 1.98
Restricted shares canceled, shares				0
Restricted shares canceled, weighted average price				$ 0
Restricted shares vested, shares				0
Restricted shares vested, weighted average price				$ 0
Restricted shares outstanding, end of period, shares	591,400	591,400		591,400
Restricted shares outstanding, end of period, weighted average price	$ 9.20	$ 9.20		$ 9.20
Share-Based Compensation (Details Textual)
Restricted Stock Awards Vesting Term				3 years
Unrecognized compensation cost for stock grants	$ 1,100,000	$ 1,100,000		$ 1,100,000
Weighted average remaining recognition period of cost for stock grants				1 year 7 months
Required stock price for payout on performance based restricted stock units				$ 5.22
Percent of payout for performance based restricted stock unit grants				100.00%
Cash-settled Restricted Stock Unit (RSUs) [Member]
Restricted stock activity
Restricted shares granted, shares				147,812
Share-Based Compensation (Details Textual)
Restricted Stock Awards Vesting Term				1 year
Cash-Settled Restricted Stock Unit Liability	$ 100,000	100,000		$ 100,000
Minimum [Member] | Restricted Stock Awards [Member]
Share-Based Compensation (Details Textual)
Restricted Stock Awards Vesting Term				1 year
Minimum [Member] | Restricted Stock Units (RSUs) [Member]
Share-Based Compensation (Details Textual)
Percent of payout for performance based restricted stock unit grants				0.00%
Maximum Payout [Member] | Restricted Stock Awards [Member]
Share-Based Compensation (Details Textual)
Restricted Stock Awards Vesting Term				3 years
Maximum Payout [Member] | Restricted Stock Units (RSUs) [Member]
Share-Based Compensation (Details Textual)
Percent of payout for performance based restricted stock unit grants				200.00%
General and Administrative Expense [Member]
Share-Based Compensation (Details Textual)
Stock-based compensation expenses		1,100,000	1,700,000	$ 3,100,000	5,100,000
Lease Operating Cost [Member]
Share-Based Compensation (Details Textual)
Stock-based compensation expenses		$ 100,000	$ 100,000	$ 100,000	$ 200,000

Earnings Per Share (Details)

Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Basic EPS Two Class Method:
Net income (loss)	$ (354,588)	$ 2,474	$ (1,124,532)	$ 14,743	$ (283,427)
Income, share amounts	44,546	43,850	44,431	43,768
Earnings Per Share, Basic	$ (7.96)	$ 0.06	$ (25.31)	$ 0.34
Dilutive Securities:
Dilutive RSA's, Shares	0	564	0	469
Dilutive RSU's, Shares	0	59	0	62
Diluted EPS:
Net Income (Loss) Available to Common Stockholders, Diluted	$ (354,588)	$ 2,474	$ (1,124,532)	$ 14,743
Weighted Average Number of Shares Outstanding, Diluted	44,546	44,473	44,431	44,299
Earnings Per Share, Diluted	$ (7.96)	$ 0.06	$ (25.31)	$ 0.33
Stock Options [Member]
Earnings Per Share (Textual)
Antidilutive shares excluded from EPS, shares	1,300	1,400	1,300	1,400
Restricted Stock [Member]
Earnings Per Share (Textual)
Antidilutive shares excluded from EPS, shares	1,000	200	800	300
Restricted Stock Units (RSUs) [Member]
Earnings Per Share (Textual)
Contingently Issuable Shares Not Included in Diluted EPS	1,200	700	1,200	700

Long-Term Debt (Details)

Long-Term Debt (Details) $ in Thousands		Jan. 01, 2017	Nov. 02, 2015USD ($)	Sep. 30, 2015USD ($)	May. 01, 2015USD ($)	Oct. 03, 2012USD ($)	Nov. 25, 2009USD ($)	Jun. 01, 2007USD ($)	Dec. 31, 2016	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Jun. 30, 2016	Sep. 30, 2015USD ($)	Sep. 30, 2014USD ($)	Dec. 31, 2016	Feb. 01, 2016	Dec. 31, 2014USD ($)	Nov. 30, 2011USD ($)
Bank Borrowings
Outstanding bank borrowings under credit facility	[1]			$ 1,179,132						$ 1,179,132			$ 1,179,132				$ 1,074,534
Capitalized interest on our unproved properties										1,200	$ 1,200		3,600	$ 3,700
Interest expense including amortization of debt issuance costs										19,438	18,197		56,407	55,295
Senior Notes [Member] | Senior Notes Due 2017 [Member]
Bank Borrowings
Outstanding bank borrowings under credit facility				250,000						250,000			250,000				250,000
Long-term Debt, Maturities, Repayments of Principal in Year Three				250,000						250,000			250,000
Interest expense including amortization of debt issuance costs										4,600	4,600		13,700	13,700
Senior Notes
Senior notes, issued								$ 250,000
Debt instrument, interest rate, stated percentage								7.125%
Percentage at which senior notes are issued, of par value								100.00%
Debt Issuance Cost				900				$ 4,200
Holder right to require company to repurchase notes at purchase price in cash								101.00%
Senior Notes [Member] | Senior Notes Due 2020 [Member]
Bank Borrowings
Outstanding bank borrowings under credit facility	[1]			223,043						223,043			223,043				222,775
Long-term Debt, Maturities, Repayments of Principal after Year Five				225,000						225,000			225,000
Interest expense including amortization of debt issuance costs										5,200	5,200		15,600	15,600
Senior Notes
Senior notes, issued							$ 225,000
Debt instrument, interest rate, stated percentage							8.875%
Original unamortized issuance discount on senior notes							$ 3,600
Percentage at which senior notes are issued, of par value							98.389%
Effective Interest Rate On Senior Notes Including Discount							9.125%
Debt Issuance Cost				2,700			$ 5,000
Holder right to require company to repurchase notes at purchase price in cash							101.00%
Senior Notes [Member] | Senior Notes Due 2022 [Member]
Bank Borrowings
Outstanding bank borrowings under credit facility	[1]			404,089						404,089			404,089				404,459
Long-term Debt, Maturities, Repayments of Principal after Year Five				400,000						400,000			400,000
Interest expense including amortization of debt issuance costs										$ 7,900	7,900		23,700	23,700
Senior Notes
Senior notes, issued						$ 400,000												$ 250,000
Debt instrument, interest rate, stated percentage						7.875%
Original unamortized issuance discount on senior notes																		$ 2,100
Percentage at which senior notes are issued, of par value																		99.156%
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						107.875%
Debt Issuance Cost				5,400		$ 7,500
Holder right to require company to repurchase notes at purchase price in cash						101.00%
Senior Notes [Member] | Additional Senior Notes Due 2022 [Member]
Senior Notes
Senior notes, issued						$ 150,000
Percentage at which senior notes are issued, of par value						105.00%
Effective Interest Rate On Senior Notes Including Discount						6.993%
Debt Instrument, Unamortized Premium						$ 7,500
Line of Credit [Member]
Bank Borrowings
Line of credit, required security interest on oil and gas properties										75.00%
Outstanding bank borrowings under credit facility				302,000						$ 302,000			302,000				$ 197,300
Line of Credit Facility, current borrowing capacity					$ 375,000
Line of Credit, current commitment amount					$ 375,000
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%
Commitment fee basis points for the credit facility										0.50%
Maximum level of cash dividends in any fiscal year				15,000						$ 15,000			15,000
Equity Restrictions				$ 50,000						50,000			$ 50,000
Line of credit, covenant, working capital ratio, minimum				1
Debt instrument, covenant, working capital ratio, company actual				1.3
Debt instrument, covenant, interest coverage ratio, minimum													1.5
Debt instrument, covenant, interest coverage ratio, company actual													2.1
Line of Credit, covenant, senior secured leverage ratio, minimum													3
Line of Credit, covenant, senior secured severage ratio, company actual													2
Line of Credit, covenant, liquidity requirement					15.00%
Interest expense including amortization of debt issuance costs										2,300	1,700		$ 6,300	5,900
Commitment fees included in interest expense, net										$ 100	$ 200		$ 500	$ 600
Senior Notes
Debt Issuance Cost				$ 2,000
Line of Credit [Member] | Minimum [Member] | Alternative Base Interest Rate [Member]
Bank Borrowings
Debt instrument escalating basis spread on base rate										75
Line of Credit [Member] | Minimum [Member] | Eurodollar Interest Rate [Member]
Bank Borrowings
Debt Instrument Escalating Rates for Eurodollar Rate Loans										175
Line of Credit [Member] | Maximum [Member] | Alternative Base Interest Rate [Member]
Bank Borrowings
Debt instrument escalating basis spread on base rate										175
Line of Credit [Member] | Maximum [Member] | Eurodollar Interest Rate [Member]
Bank Borrowings
Debt Instrument Escalating Rates for Eurodollar Rate Loans										275
Debt Instrument, Redemption, Period One [Member] | Senior Notes [Member] | Senior Notes Due 2017 [Member]
Senior Notes
Debt Instrument, Redemption Price, Percentage								100.00%
Debt Instrument, Redemption, Period One [Member] | Senior Notes [Member] | Senior Notes Due 2020 [Member]
Senior Notes
Debt Instrument, Redemption Price, Percentage							104.438%
Debt Instrument, Redemption, Period One [Member] | Senior Notes [Member] | Senior Notes Due 2022 [Member]
Senior Notes
Debt Instrument, Redemption Price, Percentage						103.938%
Debt Instrument, Redemption, Period Two [Member] | Senior Notes [Member] | Senior Notes Due 2020 [Member]
Senior Notes
Debt Instrument, Redemption Price, Percentage							100.00%
Debt Instrument, Redemption, Period Two [Member] | Senior Notes [Member] | Senior Notes Due 2022 [Member]
Senior Notes
Debt Instrument, Redemption Price, Percentage						100.00%
Subsequent Event [Member] | Line of Credit [Member]
Bank Borrowings
Line of credit, required security interest on oil and gas properties			95.00%
Line of Credit Facility, current borrowing capacity			$ 330,000
Line of Credit, current commitment amount			$ 330,000
Line of credit, covenant, working capital ratio, minimum		1													0.5
Debt instrument, covenant, interest coverage ratio, minimum		2							1.30			1.15
Line of Credit, covenant, senior secured leverage ratio, minimum		2.50							3			3.50
Senior Notes
Debt Instrument, Borrowing Base Redetermination Acceleration Clause																50.00%
Subsequent Event [Member] | Line of Credit [Member] | Minimum [Member] | Alternative Base Interest Rate [Member]
Bank Borrowings
Debt instrument escalating basis spread on base rate			100
Subsequent Event [Member] | Line of Credit [Member] | Minimum [Member] | Eurodollar Interest Rate [Member]
Bank Borrowings
Debt Instrument Escalating Rates for Eurodollar Rate Loans			200
Subsequent Event [Member] | Line of Credit [Member] | Maximum [Member] | Alternative Base Interest Rate [Member]
Bank Borrowings
Debt instrument escalating basis spread on base rate			200
Subsequent Event [Member] | Line of Credit [Member] | Maximum [Member] | Eurodollar Interest Rate [Member]
Bank Borrowings
Debt Instrument Escalating Rates for Eurodollar Rate Loans			300
[1]	Amounts are shown net of any debt discount or premium

Acquisitions and Dispositions A

Acquisitions and Dispositions Acquisitions and Dispositions (Details)	Jul. 15, 2014a
Business Combinations [Abstract]
Acreage Sold in Oil and Gas Properties	8,300
Participation Interest Sold in Oil and Gas Properties	36.00%

Price-Risk Management Price-R40

Price-Risk Management Price-Risk Management (Details) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2015USD ($)MMBTU$ / MMBTU	Sep. 30, 2014USD ($)	Sep. 30, 2015USD ($)MMBTU$ / MMBTU	Sep. 30, 2014USD ($)
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Gain (Loss) on Price Risk Derivatives, Net	$ 0.1	$ 5	$ 0.3	$ (2.7)
Derivative, Fair Value, Net	$ 0.1		$ 0.1
Year 2015 [Member] | Natural Gas Basis Derivative Contract [Member] | Basis Swap [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Future Gas Production Hedged in MMBTU (Energy Item Type) | MMBTU	1,220,000		1,220,000
Derivative, Swap Type, Average Fixed Price | $ / MMBTU	(0.016)		(0.016)
Other Current Assets [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 0.1		$ 0.1

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Millions	Sep. 30, 2015	Dec. 31, 2014	Oct. 03, 2012	Nov. 25, 2009	Jun. 01, 2007
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural Gas Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets		$ 0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | Natural Gas Basis Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets	$ 0	0
Fair Value of Derivative Liabilities		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural Gas Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets		2.4
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | Natural Gas Basis Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets	0.1	0.1
Fair Value of Derivative Liabilities		0.1
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets		0
Fair Value, Measurements, Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | Natural Gas Basis Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets	0	0
Fair Value of Derivative Liabilities		0
Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value Measurement [Member] | Natural Gas Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets		2.4
Fair Value, Measurements, Recurring [Member] | Estimate of Fair Value Measurement [Member] | Natural Gas Basis Derivative Contract [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value of Derivative Assets	0.1	0.1
Fair Value of Derivative Liabilities		0.1
Senior Notes [Member] | Senior Notes Due 2017 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of senior notes	67.5	153
Carrying value of senior notes	250	250
Debt instrument, interest rate, stated percentage					7.125%
Senior Notes [Member] | Senior Notes Due 2020 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of senior notes	58.5	133.1
Carrying value of senior notes	223	222.8
Debt instrument, interest rate, stated percentage				8.875%
Senior Notes [Member] | Senior Notes Due 2022 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair value of senior notes	108	198
Carrying value of senior notes	$ 404.1	$ 404.5
Debt instrument, interest rate, stated percentage			7.875%

Asset Retirement Obligations 42

Asset Retirement Obligations Asset Retirement Obligations (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2015	Sep. 30, 2014	Sep. 30, 2015	Sep. 30, 2014	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	$ 72,572		$ 72,572		$ 72,831
Accretion expense	1,410	$ 1,445	4,156	$ 4,246
Liabilities incurred for new wells and facilities construction			147
Reductions due to sold and abandoned wells			(4,574)
Revisions in estimates			12
Asset retirement obligation - current portion	$ 7,124		$ 7,124		$ 10,709

Commitments and Contingencies43

Commitments and Contingencies Commitments and Contingencies (Details Textual) $ in Millions	3 Months Ended
	Sep. 30, 2015USD ($)
Commitments and Contingencies Disclosure [Abstract]
Lessee Leasing Arrangements, Operating Leases, Term of Contract	11 years
Operating Lease, Early Termination Option	7 years
Operating Leases, Future Minimum Payments Due	$ 24
Purchase Obligation	$ 39