Cimarex Resolute (REN) 10-K 7 Mar 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Feb. 29, 2016	Jun. 30, 2015
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Trading Symbol	REN
Entity Registrant Name	Resolute Energy Corp
Entity Central Index Key	1,469,510
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	No
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		77,430,057
Entity Public Float			$ 53.5

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 9,297	$ 4,352
Accounts receivable	37,100	57,909
Commodity derivative instruments	92,431	72,753
Prepaid expenses and other current assets	1,387	1,858
Total current assets	140,215	136,872
Property and equipment, at cost:
Oil and gas properties, full cost method of accounting, Unproved	21,264	270,375
Oil and gas properties, full cost method of accounting, Proved	1,732,707	1,706,847
Other property and equipment	9,648	9,994
Accumulated depletion, depreciation and amortization	(1,540,447)	(744,220)
Net property and equipment	223,172	1,242,996
Other assets:
Restricted cash	21,497	19,858
Commodity derivative instruments	3,463	39,799
Other assets	2,636	182
Total assets	390,983	1,439,707
Current liabilities:
Accounts payable	7,101	25,781
Accrued expenses	45,496	65,799
Accrued interest payable	5,764	5,739
Asset retirement obligations	891	327
Secured term loan facility	0	1,494
Total current liabilities	59,252	99,140
Long term liabilities:
Revolving credit facility	0	231,936
Secured term loan facility	118,944	133,199
Senior notes	396,051	394,807
Asset retirement obligations	18,347	31,013
Deferred income taxes	0	22,354
Other long term liabilities	1,670	640
Total liabilities	$ 594,264	$ 913,089
Commitments and contingencies
Stockholders’ equity (deficit):
Preferred stock, $0.0001 par value; 1,000,000 shares authorized; none issued or outstanding
Common stock, $0.0001 par value; 225,000,000 shares authorized; issued and outstanding 77,210,735 and 77,634,737 shares at December 31, 2015 and 2014, respectively	$ 8	$ 8
Additional paid-in capital	659,118	646,738
Accumulated deficit	(862,407)	(120,128)
Total stockholders’ equity (deficit)	(203,281)	526,618
Total liabilities and stockholders’ equity (deficit)	$ 390,983	$ 1,439,707

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2015	Dec. 31, 2014
Statement Of Financial Position [Abstract]
Preferred stock, par value	$ 0.0001	$ 0.0001
Preferred stock, shares authorized	1,000,000	1,000,000
Preferred stock, issued	0	0
Preferred stock, outstanding	0	0
Common stock, par value	$ 0.0001	$ 0.0001
Common stock, shares authorized	225,000,000	225,000,000
Common stock, issued	77,210,735	77,634,737
Common stock, outstanding	77,210,735	77,634,737

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenue:
Oil	$ 137,893	$ 293,970	$ 321,047
Gas	12,628	26,254	21,444
Natural gas liquids	4,123	9,147	7,288
Total revenue	154,644	329,371	349,779
Operating expenses:
Lease operating	79,393	112,683	103,276
Production and ad valorem taxes	19,985	37,216	40,402
Depletion, depreciation, amortization, and asset retirement obligation accretion	94,338	132,154	116,344
Impairment of proved oil and gas properties	705,000	120,000	188,000
General and administrative	31,447	39,992	35,625
Restricted cash awards	1,185	0	0
Total operating expenses	931,348	442,045	483,647
Loss from operations	(776,704)	(112,674)	(133,868)
Other income (expense):
Interest expense, net	(64,358)	(31,489)	(29,302)
Commodity derivative instruments gain (loss)	76,492	118,141	(15,336)
Other income (expense)	(63)	32	21
Total other income (expense)	12,071	86,684	(44,617)
Loss before income taxes	(764,633)	(25,990)	(178,485)
Income tax benefit	22,354	4,140	64,679
Net loss	$ (742,279)	$ (21,850)	$ (113,806)
Net loss per common share:
Basic and diluted	$ (9.91)	$ (0.30)	$ (1.67)
Weighted average common shares outstanding:
Basic	74,932	73,798	68,260
Diluted	74,932	73,798	68,260

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity (Deficit) - USD ($) $ in Thousands	Total	Common Stock	Additional Paid-in Capital	Retained Earnings/Accumulated (Deficit)
Beginning Balance at Dec. 31, 2012	$ 532,184	$ 6	$ 516,650	$ 15,528
Beginning Balance (in shares) at Dec. 31, 2012		61,873,000
Issuance of stock, restricted stock and share-based compensation	14,965	$ 1	14,964	0
Issuance of stock, restricted stock and share-based compensation (in shares)		1,925,000
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations	(1,551)	$ 0	(1,551)	0
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations (in shares)		(820,000)
Issuance of stock, net of underwriters discounts and commissions	101,760	$ 1	101,759	0
Issuance of stock, net of underwriters discounts and commissions (in shares)		13,250,000
Net loss	(113,806)	$ 0	0	(113,806)
Ending Balance at Dec. 31, 2013	533,552	$ 8	631,822	(98,278)
Ending Balance (in shares) at Dec. 31, 2013		76,228,000
Issuance of stock, restricted stock and share-based compensation	16,651	$ 0	16,651	0
Issuance of stock, restricted stock and share-based compensation (in shares)		2,084,000
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations	(1,735)	$ 0	(1,735)	0
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations (in shares)		(677,000)
Net loss	(21,850)	$ 0	0	(21,850)
Ending Balance at Dec. 31, 2014	$ 526,618	$ 8	646,738	(120,128)
Ending Balance (in shares) at Dec. 31, 2014	77,634,737	77,635,000
Issuance of stock, restricted stock and share-based compensation	$ 12,556		12,556
Issuance of stock, restricted stock and share-based compensation (in shares)		161,000
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations	(176)		(176)
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations (in shares)		(585,000)
Net loss	(742,279)			(742,279)
Ending Balance at Dec. 31, 2015	$ (203,281)	$ 8	$ 659,118	$ (862,407)
Ending Balance (in shares) at Dec. 31, 2015	77,210,735	77,211,000

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating activities:
Net loss	$ (742,279)	$ (21,850)	$ (113,806)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion, depreciation, amortization, and asset retirement obligation accretion	94,338	132,154	116,344
Impairment of proved oil and gas properties	705,000	120,000	188,000
Amortization of deferred financing costs and long-term debt premium and discount	11,578	2,337	2,481
Share-based compensation	12,148	16,331	14,924
Commodity derivative instruments loss (gain)	(76,492)	(118,141)	15,336
Commodity derivative settlement gains (losses)	93,150	(4,988)	(35,812)
Deferred income tax benefit	(22,354)	(4,140)	(64,663)
Change in operating assets and liabilities:
Accounts receivable	21,216	36,768	(15,961)
Other current assets	322	(706)	539
Accounts payable and accrued expenses	(27,173)	(14,297)	25,905
Accrued interest payable	25	0	41
Net cash provided by operating activities	69,479	143,468	133,328
Investing activities:
Oil and gas exploration and development expenditures	(67,636)	(183,565)	(261,758)
Purchase of oil and gas properties	0	0	(257,948)
Proceeds from sale of oil and gas properties and other	268,773	11,122	121,361
Purchase of other property and equipment	(124)	(1,925)	(2,467)
Restricted cash	(1,489)	(1,639)	203
Other	59	114	(4,909)
Net cash provided by (used in) investing activities	199,583	(175,893)	(405,518)
Financing activities:
Proceeds from bank borrowings	183,000	433,500	638,000
Repayments of bank borrowings	(418,000)	(533,500)	(465,000)
Proceeds from issuance of term loans	46,500	139,500	0
Repayment of term loans	(71,697)	0	0
Redemption of restricted stock for employee income taxes	(176)	(1,735)	(1,551)
Payment of financing costs	(3,744)	(1,007)	(1,934)
Proceeds from issuance of common stock, net of underwriters discounts and commissions	0	0	101,760
Net cash provided by (used in) financing activities	(264,117)	36,758	271,275
Net increase (decrease) in cash and cash equivalents	4,945	4,333	(915)
Cash and cash equivalents at beginning of period	4,352	19	934
Cash and cash equivalents at end of period	9,297	4,352	19
Cash paid during the period for:
Interest, net of amounts capitalized	64,364	31,890	29,280
Income taxes	0	0	0
Supplemental schedule of non-cash investing and financing activities:
Capital expenditures financed through current liabilities	10,482	17,651	30,069
Increase (decrease) to asset retirement obligations	333	(2,012)	11,421
Asset retirement obligations assumed	0	0	1,659
Asset retirement obligations sold	$ 14,985	$ 157	$ 723

Organization and Nature of Busi

Organization and Nature of Business	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Organization and Nature of Business	Note 1 — Organization and Nature of Business Resolute Energy Corporation (“Resolute” or the “Company”), is an independent oil and gas company engaged in the exploitation, development, exploration for and acquisition of oil and gas properties. The Company’s asset base is comprised primarily of properties in Aneth Field located in the Paradox Basin in southeast Utah (the “Aneth Field Properties” or “Aneth Field”) and the Permian Basin in west Texas and southeast New Mexico. The Company conducts all of its activities in the United States of America. Resolute Energy Corporation, the stand-alone parent entity, has insignificant independent assets and no operations. There are no restrictions on the Company’s ability to obtain cash dividends or other distributions of funds from its subsidiaries, except those imposed by applicable law.

Basis of Presentation and Summa

Basis of Presentation and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Basis of Presentation and Summary of Significant Accounting Policies	Note 2 — Basis of Presentation and Summary of Significant Accounting Policies Basis of Presentation The consolidated financial statements include Resolute and its subsidiaries, and have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”). All significant intercompany transactions have been eliminated upon consolidation. Certain prior period amounts have been reclassified to conform to the current period presentation. In connection with the preparation of the consolidated financial statements, Resolute evaluated subsequent events that occurred after the balance sheet date, through the date of filing. Assumptions, Judgments and Estimates The preparation of the consolidated financial statements in conformity with GAAP requires management to make various assumptions, judgments and estimates to determine the reported amounts of assets, liabilities, revenue and expenses, and in the disclosures of commitments and contingencies. Changes in these assumptions, judgments and estimates will occur as a result of the passage of time and the occurrence of future events. Accordingly, actual results could differ from amounts previously established. Significant estimates with regard to the consolidated financial statements include proved oil and gas reserve volumes and the related present value of estimated future net cash flows used in the ceiling test applied to capitalized oil and gas properties; asset retirement obligations; valuation of derivative assets and liabilities; the estimated fair value and allocation of the purchase price related to business combinations; share-based compensation expense; depletion depreciation, and amortization; accrued liabilities; revenue and related receivables and income taxes. Fair Value of Financial Instruments The carrying amount of the majority of Resolute’s financial instruments, namely cash and cash equivalents, accounts receivable and accounts payable, approximate their fair value because of the short-term nature of these instruments. The revolving credit facility (see Note 5) has a recorded value that approximates its fair market value while the fair value of the $400 million in principal senior notes due May 1, 2020 (the “Senior Notes” or the “Notes”) and the $128.3 million in the second lien secured term loan due March 2018 (the “Secured Term Loan Facility”) are based on data from independent market makers or price received at measurement date. The fair value of derivative instruments (see Note 10) is estimated based on market conditions in effect at the end of each reporting period. Industry Segment and Geographic Information Resolute conducts oil, gas and natural gas liquids (“NGL”) exploration and production operations in one segment. All of Resolute’s operations and assets are located in the United States, and all of its revenue is attributable to domestic customers. Resolute considers gathering, processing and marketing functions as supportive of its oil and gas producing activities, and accordingly, they are not reported as separate segments. Cash and Cash Equivalents Resolute considers all highly liquid investments with original maturities of three months or less at the date of purchase to be cash equivalents. Resolute periodically maintains cash and cash equivalents in bank deposit accounts and money market funds which may be in excess of federally insured amounts. Resolute has not experienced any losses in such accounts and believes it is not exposed to any significant credit risk on such accounts. Accounts Receivable The Company’s accounts receivable consist of the following for the periods indicated (in thousands): December 31, 2015 2014 Trade receivables $ 14,224 $ 23,240 Revenue receivables 12,967 27,926 Derivative receivables 9,759 6,638 Other receivables 150 105 Total accounts receivable $ 37,100 $ 57,909 The Company’s accounts receivable consist mainly of receivables from oil, gas, and NGL purchasers and from joint interest owners on properties the Company operates. For receivables from joint interest owners, the Company typically has the ability to withhold future revenue disbursements to recover non-payment of joint interest billings. Generally, the Company’s oil and gas receivables are due within fifteen days and are collected in less than two months, and the Company has had minimal bad debts. The Company routinely assesses the recoverability of all material trade and other receivables to determine their collectability. As of December 31, 2015 and 2014, the Company had no allowance for doubtful accounts recorded. Deferred Financing Costs In 2015, the Financial Accounting Standards Board (“FASB”) issued new authoritative guidance related to the presentation of deferred financing costs. This authoritative guidance is effective for the annual period beginning after December 15, 2015, including interim reporting periods within that reporting period. The new guidance proscribes the application be applied retrospectively. The Company has elected to early adopt this guidance in 2015. Accordingly, the Company has reclassified certain deferred financing costs to a direct deduction from the carrying amounts of debt for the balance sheets at December 31, 2015 and 2014 (see Note 5). Deferred financing costs are amortized over the estimated life of the related obligation. The Company incurred $0 in deferred financing costs in 2015, $4.8 million in 2014 and $1.9 million in 2013, and amortized $5.0 million, $2.5 million and $2.7 million to interest expense during 2015, 2014 and 2013, respectively. Capitalized Interest Interest is capitalized when associated with significant investments in unproved properties and major development projects that are excluded from current depletion, depreciation and amortization calculations and on which exploration or development activities are in progress. Capitalized interest is calculated by multiplying the Company’s weighted-average interest rate on debt outstanding by the amount of qualified costs. Costs excluded from the depletion, depreciation and amortization calculations are classified as unproved properties along with any associated capitalized interest. Capitalized interest totaled $6.0 million, $14.9 million and $15.9 million during 2015, 2014 and 2013, respectively. Concentration of Credit Risk Financial instruments that potentially subject Resolute to concentrations of credit risk consist primarily of trade, production and derivative settlement receivables. Resolute derived approximately 58% and 14% of its total 2015 revenue from Western Refining, Inc. (“Western”) and Holly Frontier LLC, respectively; 62% and 14% of its total 2014 revenue from Western and Plains Marketing LP, respectively and 61% and 15% of its total 2013 revenue from Western and Plains Marketing LP, respectively. If Resolute was compelled to sell its oil to an alternative market, costs associated with the transportation of its production may increase, and such increase could materially and negatively affect its operations. The concentration of credit risk in the oil and gas industry affects the overall exposure to credit risk because customers may be similarly affected by changes in economic or other conditions. The creditworthiness of customers and other counterparties is subject to continuing review, including the use of master netting agreements where appropriate. Commodity derivative contracts expose Resolute to the credit risk of non-performance by the counterparty to the contracts. This exposure is diversified among major investment grade financial institutions, all of which participate in Resolute’s Revolving Credit Facility (see Note 5). Oil and Gas Properties The Company uses the full cost method of accounting for oil and gas producing activities. All costs incurred in the acquisition, exploration and development of properties, including costs of unsuccessful exploration, costs of surrendered and abandoned leaseholds, delay lease rentals and the fair value of estimated future costs of site restoration, dismantlement and abandonment activities, improved recovery systems and a portion of general and administrative and operating expenses are capitalized on a country wide basis (the “Cost Center”). Resolute conducts tertiary recovery projects on certain of its oil and gas properties in order to recover additional hydrocarbons that are not recoverable from primary or secondary recovery methods. Under the full cost method, all development costs are capitalized at the time incurred. Development costs include charges associated with access to and preparation of well locations, drilling and equipping development wells, test wells, and service wells including injection wells, and acquiring, constructing, and installing production facilities and providing for improved recovery systems. Improved recovery systems include all related facility development costs and the cost of the acquisition of tertiary injectants, primarily purchased carbon dioxide (“CO 2 2 2 2 In contrast, other costs related to the daily operation of the improved recovery systems are considered production costs and are expensed as incurred. These costs include, but are not limited to, compression, electricity, separation, re-injection of recovered CO 2 Capitalized general and administrative and operating costs include salaries, employee benefits, costs of consulting services and other specifically identifiable capital costs and do not include costs related to production operations, general corporate overhead or similar activities. Resolute capitalized general and administrative and operating costs related to its acquisition, exploration and development activities of $6.3 million during 2015, $9.8 million during 2014 and $8.4 million during 2013. Investments in unproved properties are not depleted, pending determination of the existence of proved reserves. The Company’s investments in unproved properties are related to exploration plays in the Permian Basin in Texas and southeast New Mexico. The Company expects to evaluate these locations for the existence of proved reserves in the next three years, although volatility in commodity prices may impact the timing of the evaluation. Unproved properties are assessed at least annually to determine whether impairment has occurred. Unproved properties whose costs are individually significant are assessed individually by considering the primary lease terms of the properties, the holding period of the properties and geographic and geologic data obtained relating to the properties. Where it is not practicable to assess individually the amount of impairment of properties for which costs are not individually significant, such properties are grouped for purposes of assessing impairment. The amount of impairment assessed is added to the costs to be amortized. No gain or loss is recognized upon the sale or abandonment of undeveloped or producing oil and gas properties unless the sale represents a significant portion of the Company’s oil and gas properties and the gain or loss significantly alters the relationship between the capitalized costs and proved reserves of the cost center. Depletion of oil and gas properties is computed on the unit-of-production method based on proved reserves. Depletable costs include estimates of asset retirement obligations and future development costs of proved reserves, including, but not limited to, costs to drill and equip development wells, construct and install production and processing facilities, and improved recovery systems, including the cost of required future CO 2 Pursuant to full cost accounting rules, Resolute is required to perform a quarterly “ceiling test” calculation to test its oil and gas properties for possible impairment. The primary components impacting the calculation are commodity prices, reserve quantities added and produced, overall exploration and development costs and depletion expense. If the net capitalized cost of the Company’s oil and gas properties subject to the amortization (the “carrying value”) exceeds the ceiling limitation, the excess would be charged to expense. The ceiling limitation is equal to the sum of the present value discounted at 10% of estimated future net cash flows from proved reserves, the cost of properties not being amortized, the lower of cost or estimated fair value of unproven properties included in the costs being amortized, and all related income tax effects. During 2015, 2014 and 2013, the Company recorded $705 million, $120 million and $188 million, respectively, non-cash impairment of the carrying value of its oil and gas properties as a result of the ceiling test limitation. If in future periods a negative impact continues on one or more of the components of the calculation, including market prices of oil and gas (based on a trailing twelve-month unweighted average of the oil and gas prices in effect on the first day of each month), differentials from posted prices, future drilling and capital plans, operating costs or expected production, the Company may incur further full cost ceiling impairment related to its oil and gas properties in such periods. Business Combinations The Company accounts for all business combinations using the acquisition method which involves the use of significant judgment. Under the acquisition method of accounting, a business combination is accounted for based on the fair value of the consideration given. The assets and liabilities acquired are measured at fair value and the purchase price is allocated to the assets and liabilities based on these fair values. The excess of the cost of an acquisition, if any, over the fair value of the assets acquired and liabilities assumed is recognized as goodwill. The excess of the fair value of assets acquired and liabilities assumed over the cost of an acquisition, if any, is recognized immediately in earnings as a gain. Determining the fair values of the assets and liabilities acquired involves the use of judgment as fair values are not always readily determinable. Different techniques may be used to determine fair values, including market prices (where available), appraisals, comparisons to transactions for similar assets and liabilities and the present value of estimated future cash flows, among others. Other Property and Equipment Other property and equipment are recorded at cost. Costs of renewals and improvements that substantially extend the useful lives of the assets are capitalized. Maintenance and repair costs which do not extend the useful lives of property and equipment are charged to expense as incurred. Depreciation and amortization is calculated using the straight-line method over the estimated useful lives of the assets. Office furniture, automobiles, and computer hardware and software are depreciated over three to five years. Field offices and partial ownership of aircraft are depreciated over fifteen to twenty years. Leasehold improvements are depreciated, using the straight line method, over the shorter of the lease term or the useful life of the asset. When other property and equipment is sold or retired, the capitalized costs and related accumulated depreciation and amortization are removed from the accounts. Impairment of Long-Lived Assets Other than Oil and Gas Properties Resolute evaluates long-lived assets other than oil and gas properties for impairment when indicators of possible impairment are present. Resolute performs an analysis of the anticipated undiscounted future net cash flows of the related long-lived assets and if the carrying value of the related asset exceeds the undiscounted cash flows, the carrying value is reduced to the asset’s fair value and an impairment loss is recorded against the long-lived asset. There have been no provisions for impairment of long-lived assets other than oil and gas properties recorded for the years ended December 31, 2015, 2014 and 2013. Asset Retirement Obligations Asset retirement obligations relate to future costs associated with the plugging and abandonment of oil and gas wells, removal of equipment and facilities from leased acreage and returning such land to its original condition. The fair value of a liability for an asset retirement obligation is recorded in the period in which it is incurred and the cost of such liability is recorded as an increase in the carrying amount of the related long-lived asset by the same amount. The liability is accreted each period and the capitalized cost is depleted as part of the full cost pool. Revisions to estimated asset retirement obligations result in adjustments to the related capitalized asset and corresponding liability. The restricted cash of $21.5 million located on the Company’s consolidated balance sheet in non-current other assets at December 31, 2015, is legally restricted for the purpose of settling asset retirement obligations of Aneth Field. Derivative Instruments Resolute utilizes derivative instruments to manage its exposure to oil and gas price volatility and these instruments may take the form of swaps, puts, calls, collars and other such arrangements. Derivative instruments are recognized on the balance sheet as either assets or liabilities measured at fair value. Resolute has not elected to apply cash flow hedge accounting, and consequently, recognizes gains and losses in earnings rather than deferring such amounts in other comprehensive income as allowed under cash flow hedge accounting. Realized gains and losses on derivative instruments are recognized in the period in which the related contract is settled. Both the realized and mark-to-market gains and losses on derivative instruments are reflected in other income (expense) in the consolidated statements of income. Cash flows from derivatives are reported as cash flows from operating activities. Revenue Recognition Oil and gas revenue is recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred and the collectability of the revenue is probable. Oil and gas revenue is recorded using the sales method. General and Administrative Expenses General and administrative expenses are reported net of amounts capitalized to oil and gas properties and of reimbursements of overhead costs that are billed to working interest owners of the oil and gas properties operated by Resolute. Share-Based Compensation Expense Share-based compensation expense is measured at the estimated grant date fair value of the awards and is amortized over the requisite service period (usually the vesting period). The Company estimates forfeitures in calculating the cost related to share-based compensation as opposed to recognizing these forfeitures and the corresponding reduction in expense as they occur. Income Taxes Income taxes and uncertain tax positions are accounted for in accordance with FASB Accounting Standards Codification (“ASC”) Topic 740, Accounting for Income Taxes The FASB issued Accounting Standards Update (ASU) 2015-17, Balance Sheet Classification of Deferred Taxes

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
Acquisitions and Divestitures	Note 3 — Acquisitions and Divestitures Divestitures Divestiture of Gardendale Properties in the Midland Basin In November 2015 the Company entered into a Purchase and Sale Agreement (the “PSA”) to sell its Gardendale oil and gas properties in the Midland Basin in Midland and Ector counties, Texas, for a purchase price of $177.5 million, subject to customary purchase price adjustments, including for title and environmental defects (the “Gardendale Sale”). The sale was consummated on December 22, 2015, with an effective date of September 1, 2015. The net proceeds of the sale were used to reduce debt under the Company’s Revolving Credit Facility and Secured Term Loan Facility (both as defined below). As part of the sale, the Company is no longer liable for asset retirement obligations of $5.6 million at December 31, 2015. Divestiture of Hilight Field Properties in the Powder River Basin In October 2015, the Company sold its Hilight Field Properties in the Powder River Basin for approximately $55 million. The sale was consummated on October 6, 2015, with an effective date of July 1, 2015. The net proceeds under these sales were used to pay down amounts outstanding under the Revolving Credit Facility (as defined below). As a part of the sale, the Company is no longer liable for asset retirement obligations of $8.1 million at December 31, 2015. Divestiture of Howard and Martin County Properties In May 2015, the Company sold its Howard and Martin County properties in the Permian Basin for approximately $42 million. The sale was consummated on May 1, 2015, with an effective date of March 1, 2015. The net proceeds under these sales were used to pay down amounts outstanding under the Revolving Credit Facility (as defined below). As part of the sale, the Company is no longer liable for asset retirement obligations of $1.3 million at December 31, 2015. The unaudited pro forma financial information for the year ended December 31, 2015 reflects Resolute’s 2015 results as if the Gardendale, Hilight Field, and Howard and Martin County properties were sold on January 1, 2015 (in thousands, except per share amounts): 2015 Total revenue $ 123,830 Loss from operations (775,872 ) Net loss (730,381 ) Basic and diluted net loss per common share $ (9.75 ) Divestiture of New Home Properties In June 2013, the Company entered into a purchase and sale agreement with HRC Energy, LLC, a Colorado limited liability company, and a wholly-owned subsidiary of Halcón Resources Corporation, a Delaware corporation, effective March 1, 2013, to dispose of certain Bakken properties located in Williams County, North Dakota (the “New Home Properties”) and other non-operated Bakken properties for proceeds of $70.1 million. The transaction closed on July 15, 2013 and net proceeds received were recorded as a reduction to the capitalized costs of the Company’s oil and gas properties. Permian Property Acquisitions On December 28, 2012, the Company purchased properties in the Wolfberry play in the Midland Basin portion of the Permian Basin in Midland and Ector counties, Texas, for a purchase price of approximately $133 million. Concurrently with the latter transaction, the Company acquired, for additional consideration of $6 million, the option to buy the balance of the working interest in and operatorship of the properties under substantially the same terms as the initial transaction, (the “Option Properties”). On March 22, 2013, the Company exercised the option and acquired the Option Properties for $258 million, net of the option fee after customary purchase price adjustments, which were estimated at closing. Revenue and expenses related to the acquired properties are included in the consolidated statement of operations beginning on the closing date of the respective transaction. The properties acquired under the December and March acquisitions, which the Company refers to as the “Permian Acquisitions,” were accounted for using the acquisition method. The Company has completed its assessment of the fair values of the assets acquired and liabilities assumed. Accordingly, the following table presents the final purchase price allocation of the Permian Acquisitions at December 31, 2013, based on the fair values of assets acquired and liabilities assumed (in thousands): 2013 Proved oil and gas properties $ 93,000 Unproved oil and gas properties 167,000 Asset retirement obligations assumed (2,000 ) Total purchase price $ 258,000 Pro Forma Financial Information The unaudited pro forma consolidated financial information in the table below summarizes the results of operations of the Company as though the purchase of the Option Properties in March 2013 had occurred on January 1, 2012. The pro forma financial information is presented for informational purposes only and is not indicative of the results of operations that would have been achieved if the Permian Acquisitions had taken place at the beginning of the earliest periods presented or that may result in the future. The pro forma adjustments made utilize certain assumptions that Resolute believes are reasonable based on the available information. The unaudited pro forma financial information for the year ended December 31, 2013 combines the historical results of the Permian Acquisitions and Resolute (in thousands, except per share amounts): 2013 Revenue $ 360,837 Revenue in excess of operating expenses 215,273 Net income (loss) (111,243 ) Basic and diluted net income (loss) per share $ (1.63 )

Earnings per Share

Earnings per Share	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Earnings per Share	Note 4 — Earnings per Share The Company computes basic net income (loss) per share using the weighted average number of shares of common stock outstanding during the period. Diluted net income (loss) per share is computed using the weighted average number of shares of common stock and, if dilutive, potential shares of common stock outstanding during the period. Potentially dilutive shares consist of the incremental shares and options issuable under the Company’s 2009 Performance Incentive Plan (the “Incentive Plan”). The treasury stock method is used to measure the dilutive impact of potentially dilutive shares. The following table details the potential weighted average dilutive and anti-dilutive securities for the periods presented (in thousands): Twelve Months Ended December 31, 2015 2014 2013 Potential dilutive restricted stock 1,779 2,973 2,529 Anti-dilutive securities 4,901 27,523 35,569 The following table sets forth the 2015, 2014 and 2013 computation of basic and diluted net income (loss) per share of common stock for the periods presented (in thousands, except per share amounts): 2015 2014 2013 Net loss $ (742,279 ) $ (21,850 ) $ (113,806 ) Basic weighted average common shares outstanding 74,932 73,798 68,260 Add: dilutive effect of non-vested restricted stock — — — Diluted weighted average common shares outstanding 74,932 73,798 68,260 Basic and diluted net loss per common share $ (9.91 ) $ (0.30 ) $ (1.67 )

Long Term Debt

Long Term Debt	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Long Term Debt	Note 5 — Long Term Debt As of the dates indicated, the Company’s long-term debt consisted of the following (in thousands): Principal Unamortized premium/ (discount) Unamortized deferred financing costs December 31, 2015 Revolving credit facility $ — $ — $ (2,121 ) $ (2,121 ) Secured term loan facility 128,303 (7,223 ) (2,136 ) 118,944 8.50% senior notes 400,000 1,233 (5,182 ) 396,051 Total long-term debt $ 528,303 $ (5,990 ) $ (9,439 ) $ 512,874 Principal Unamortized premium/ (discount) Unamortized deferred financing costs December 31, 2014 Revolving credit facility $ 235,000 $ — $ (3,064 ) $ 231,936 Secured term loan facility 150,000 (10,500 ) (4,807 ) 134,693 8.50% senior notes 400,000 1,461 (6,654 ) 394,807 Total $ 785,000 $ (9,039 ) $ (14,525 ) $ 761,436 Current portion of secured term loan facility 1,494 Long-term debt $ 759,942 Unamortized deferred financing costs associated with the revolving credit facility at December 31, 2015, have been included in other assets. For the years ended December 31, 2015, 2014, and 2013, the Company incurred interest expense on long-term debt of $70.3 million, $46.4 million and $45.2 million, respectively. The Company capitalized $6.0 million, $14.9 million and $15.9 million of interest expense during the years ended December 31, 2015, 2014 and 2013, respectively. Revolving Credit Facility Resolute’s revolving credit facility is with a syndicate of banks led by Wells Fargo Bank, National Association, as Administrative Agent, and Bank of Montreal, as Syndication Agent (the “Revolving Credit Facility”) with Resolute as the borrower. The Revolving Credit Facility specifies a maximum borrowing base as determined by the lenders. The determination of the borrowing base takes into consideration the estimated value of Resolute’s oil and gas properties in accordance with the lenders’ customary practices for oil and gas loans. The borrowing base is redetermined semi-annually, and the amount available for borrowing could be increased or decreased as a result of such redeterminations. Under certain circumstances, either Resolute or the lenders may request an interim redetermination. The Revolving Credit Facility matures in March 2018. In March 2013 we entered into the Sixth Amendment, which among other things, also extended the maturity date of the Revolving Credit Facility from April 2017 to March 2018. On March 7, 2014, we entered into the Ninth Amendment to the amended and restated Revolving Credit Facility which redefined and adjusted the Maximum Leverage Ratio to (a) 4.90:1.00 for the fiscal quarters ending March 31, 2014, and June 30, 2014, (b) 4.75:1.00 for the fiscal quarters ending September 30, 2014, and December 31, 2014, and (c) 4.00:1.00 for all quarters thereafter. The Ninth Amendment also provided that as of the last day of each fiscal quarter in 2014 the ratio of senior secured debt as of such date to Adjusted EBITDA as defined in the Revolving Credit Facility for the four quarter period ending on such date may not exceed 2.75:1.00. In December 2014 Resolute entered into the Eleventh Amendment to the amended and restated Revolving Credit Facility agreement that, among other things, conformed the covenant package in the Revolving Credit Facility to that of the Secured Term Loan Facility (defined below). The covenants require, among other things, maintenance of certain ratios, measured on a quarterly basis, as follows: (i) secured debt to EBITDA of no more than 3.5 to 1.0, (ii) PV-10 of total proved reserves to total secured debt of at least 1.1 to 1.0, rising over time to 1.5 to 1.0 for any fiscal quarter ending on or after December 31, 2015, and (iii) PV-10 of proved developed reserves to total secured debt of at least 1.0 to 1.0. Our Revolving Credit Facility and our Secured Term Loan Facility also require us to enter into derivative agreements covering at least 70% of our anticipated production from proved developed producing properties on a rolling twenty four month basis, but prohibit us from entering into derivative arrangements for more than (i) 85% of our anticipated production from proved properties in the subsequent two years and (ii) the greater of 75% of our anticipated production from proved properties or 85% of our production from projected proved developed producing properties after such two year period, using economic parameters specified in our Revolving Credit Facility. In April 2015 Resolute entered into the Twelfth Amendment to the amended and restated Revolving Credit Facility agreement which set the borrowing base at $275 million effective April 15, 2015, and included a provision for the sale of the oil and gas properties in Howard and Martin counties, Texas (which was consummated May 1, 2015), subject to a $5 million automatic reduction in the borrowing base upon the closing of such sale. Furthermore, the amendment extended the deadline for incurring up to $50 million of additional loans under the Secured Term Loan Agreement (discussed below) to May 31, 2015, amended the claw back provision related thereto such that the borrowing base was reduced automatically upon such incurrence by an amount equal to 20% of the principal amount of such additional loans (rather than the 90% claw back provision previously in effect) and modified the maximum first lien leverage ratio covenant so that the ratio level will not step down to 2.0 to 1.0 until the aggregate outstanding principal balance of the second lien debt exceeds $200 million (rather than when it equals or exceeds $200 million). In May 2015 Resolute borrowed an additional $50 million of second lien term debt (discussed below). As a result, the Company’s borrowing base under the Revolving Credit Facility was automatically reduced by $10 million to $260 million. In October 2015 the Company completed its fall borrowing base redetermination, and the borrowing base was set at $165 million. This amount reflected a $15 million reduction attributable to the sale of the Powder River Basin properties described in Note 3. In December 2015 the Company completed the sale of its Gardendale oil and gas properties in the Midland Basin in Midland and Ector countries, Texas. In connection with the Gardendale Sale, the Company’s borrowing base under its Revolving Credit Facility was reduced by $20 million to $145 million. As of December 31, 2015, outstanding borrowings under the Revolving Credit Facility were $0, under a borrowing base of $145 million. The borrowing base availability had been reduced by $3.1 million in conjunction with letters of credit issued at December 31, 2015. To the extent that the borrowing base, as adjusted from time to time, exceeds the outstanding balance, no repayments of principal are required prior to maturity. However, should the borrowing base be set at a level below the outstanding balance, Resolute would be required to eliminate that excess over 120 days following that determination. The Revolving Credit Facility is guaranteed by all of Resolute’s subsidiaries and is collateralized by substantially all of the proved oil and gas assets of Resolute Aneth, LLC and Resolute Natural Resources Southwest, LLC, which are wholly-owned subsidiaries of the Company. Each base rate borrowing under the Revolving Credit Facility accrues interest at either (a) the London Interbank Offered Rate (“LIBOR”), plus a margin which varies from 1.50% to 2.50% or (b) the alternative Base Rate defined as the greater of (i) the Administrative Agent’s Prime Rate (ii) the Federal Funds effective Rate plus 0.5% or (iii) an adjusted London Interbank Offered Rate plus a margin which ranges from 0.50% to 1.50%. Each such margin is based on the level of utilization under the borrowing base. The Revolving Credit Facility includes customary terms and covenants that place limitations on certain types of activities, the payment of dividends, and require satisfaction of certain financial tests. Resolute was in compliance with all material terms and covenants of the Revolving Credit Facility at December 31, 2015. Secured Term Loan Agreement On December 30, 2014, Resolute and certain of its subsidiaries, as guarantors, entered into a second lien Secured Term Loan Agreement with Bank of Montreal, as administrative agent, and the lenders party thereto, pursuant to which the Company borrowed $150 million (the “Secured Term Loan Facility”). Initial funding of the Secured Term Loan Facility occurred on December 31, 2014, with net proceeds of approximately $135 million after payment of transaction-related fees, expenses and discounts. Net proceeds were used to repay amounts outstanding under the Revolving Credit Facility. The Secured Term Loan Facility will mature on the date that is six months after the maturity of the Company’s existing Revolving Credit Facility, but in no event later than November 1, 2019. On May 18, 2015, Resolute and certain of its subsidiaries, as guarantors, entered into an Amendment to the Secured Term Loan Agreement and Increased Facility Activation Notice-Incremental Term Loans (the “Amendment”) with Bank of Montreal, as administrative agent, and the lenders party thereto, pursuant to which the Company borrowed an additional $50 million of second lien term debt (the “Incremental Term Loans”) under its Secured Term Loan Agreement dated December 30, 2014. Funding of the Incremental Term Loans occurred on May 19, 2015. The Incremental Term Loans have the same terms as the existing second lien borrowings under the Secured Term Loan Agreement, adjusted for the date of the closing. The $50 million of Incremental Term Loans was placed with the same lenders that participated in the initial $150 million second lien closing in December 2014. Net proceeds from the Incremental Term Loans of approximately $46 million after payment of transaction-related fees, expenses and discounts, were used to repay amounts outstanding under the Revolving Credit Facility. Obligations under the Secured Term Loan Facility are guaranteed by certain of the Company’s subsidiaries and secured by second priority liens on substantially all of the assets of the Company and its subsidiaries that serve as collateral under the Revolving Credit Facility. Borrowings under the Secured Term Loan Facility will generally bear interest at adjusted LIBOR plus 10%, with a 1% LIBOR floor. The covenants in the Secured Term Loan Facility require, among other things, maintenance of certain ratios, measured on a quarterly basis, as follows: (i) secured debt to EBITDA of no more than 3.5 to 1.0, (ii) PV-10 of total proved reserves to total secured debt of at least 1.1 to 1.0, rising over time to 1.5 to 1.0 for any fiscal quarter ending on or after December 31, 2015, and (iii) PV-10 of proved developed reserves to total secured debt of at least 1.0 to 1.0. Resolute was in compliance with all material terms and covenants of the Secured Term Loan Facility at December 31, 2015. The Company may prepay all or a portion of the Secured Term Loan Facility at any time. The Secured Term Loan Facility is subject to mandatory prepayments of 75% of the net cash proceeds from asset sales after any mandatory repayment of first lien debt, subject to a limited right to reinvest proceeds in oil and gas activities and subject to the right of the lenders to waive prepayment. Prepayments made out of proceeds from asset sales are not subject to prepayment premiums. Mandatory repayments are required of 100% of the net cash proceeds of certain debt or equity issuances. Such prepayments are subject to a premium of between 10% declining to 2% during the first 36 months after closing. To the extent not otherwise achieved, aggregate repayments that substantially pay off principal amounts under the second lien facility shall include an additional payment sufficient to ensure that the lenders achieve a 1.25 to 1.0 minimum multiple of their invested capital. However, in connection with the Twelfth Amendment to the amended and restated Revolving Credit Facility agreement described above, the mandatory prepayment of Secured Term Loan Facility debt under the Howard and Martin County properties sale was waived. Furthermore, in connection with the Powder River Basin sale, on October 5, 2015, the Company also entered into a letter agreement under the Company’s Secured Term Loan Facility, pursuant to which the mandatory prepayment of Secured Term Loan Facility debt was waived. During December 2015, the Company retired $70 million of the amount outstanding under the Secured Term Loan Facility following the sale of the Gardendale interests in Midland Basin on December 22, 2015. Due to the lack of an active market, quoted market prices for the Company’s Secured Term Loan Facility or similar debt are not available. The Company used valuation techniques that relied on unobservable inputs, current information including LIBOR interest rates and the specific terms of the Secured Term Loan Facility to estimate the fair value (a Level 3 fair value measurement). The fair value of the Company’s Secured Term Loan Facility at December 31, 2015, was estimated to be $121.1 million, which approximates the principal less the unamortized discount. Senior Notes In April 2012 the Company consummated a private placement of senior notes with a principal amount of $250 million, and in December 2012 placed a follow-on issuance of senior notes with a principal amount of $150 million. The Senior Notes are due May 1, 2020, and bear an annual interest rate of 8.50% with the interest on the Notes payable semiannually in cash on May 1 and November 1 of each year. Resolute used the $250 million of proceeds from the May 2012 issuance to repay outstanding borrowings under the Revolving Credit Facility, with the remainder reserved for general corporate purposes, including capital expenditures. The Company used the $150 million of proceeds from the December 2012 issuance to partially finance the Permian Acquisitions. The Senior Notes were issued under an Indenture (the “Indenture”) among the Company, the Company’s existing subsidiaries (the “Guarantors”) and U.S. Bank National Association, as trustee (the “Trustee”) in a private transaction not subject to the registration requirements of the Securities Act of 1933. In March 2013, the Company registered the Senior Notes with the Securities and Exchange Commission by filing an amendment to the registration statement on Form S-4 enabling holders of the Senior Notes to exchange the privately placed Notes for publically registered Notes with substantially identical terms. The Indenture contains affirmative and negative covenants that, among other things, limit the Company’s and the Guarantors’ ability to make investments, incur additional indebtedness or issue preferred stock, create liens, sell assets, enter into agreements that restrict dividends or other payments by restricted subsidiaries, consolidate, merge or transfer all or substantially all of the assets of the Company, engage in transactions with the Company’s affiliates, pay dividends or make other distributions on capital stock or prepay subordinated indebtedness and create unrestricted subsidiaries. The Indenture also contains customary events of default. Upon occurrence of events of default arising from certain events of bankruptcy or insolvency, the Senior Notes shall become due and payable immediately without any declaration or other act of the Trustee or the holders of the Senior Notes. Upon the occurrence of certain other events of default, the Trustee or the holders of the Senior Notes may declare all outstanding Senior Notes to be due and payable immediately. The Company was in compliance with all financial covenants under its Senior Notes as of December 31, 2015. The Senior Notes are general unsecured senior obligations of the Company and guaranteed on a senior unsecured basis by the Guarantors. The Senior Notes rank equally in right of payment with all existing and future senior indebtedness of the Company, will be subordinated in right of payment to all existing and future senior secured indebtedness of the Guarantors, will rank senior in right of payment to any future subordinated indebtedness of the Company and will be fully and unconditionally guaranteed by the Guarantors on a senior basis. The Senior Notes are redeemable by the Company on or after May 1, 2016 on not less than 30 or more than 60 days’ prior notice, at redemption prices set forth in the Indenture. The Senior Notes may be redeemed at any time prior to May 1, 2016, at the option of the Company at a redemption price equal to 100% of the principal amount of the Notes redeemed plus the applicable premium, and accrued and unpaid interest and additional interest, if any, to the applicable redemption date as set forth in the Indenture. If a change of control occurs, each holder of the Notes will have the right to require that the Company purchase all of such holder’s Notes in an amount equal to 101% of the principal of such Notes, plus accrued and unpaid interest, if any, to the date of the purchase. The fair value of the Senior Notes at December 31, 2015, was estimated to be $177.9 million based upon data from independent market makers (Level 2 fair value measurement).

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	Note 6 — Income Taxes The following table summarizes the components of the provision for income taxes (in thousands): 2015 2014 2013 Current income tax benefit $ — $ — $ 16 Deferred income tax benefit 22,354 4,140 64,663 Total income tax benefit $ 22,354 $ 4,140 $ 64,679 The provision for income taxes for the years ended December 31, 2015, 2014 and 2013 differs from the amount that would be provided by applying the statutory U.S. federal income tax rate of 35% to income before income taxes. This difference relates primarily to state income taxes and estimated permanent differences as follows (in thousands): 2015 2014 2013 Expected statutory income tax benefit $ 267,621 $ 9,097 $ 62,470 State income tax benefit 13,394 480 3,254 Equity compensation (4,822 ) (4,273 ) (2,031 ) Non-deductible executive compensation — (468 ) (54 ) Prior Year True Up net 4 (163 ) 12 Valuation allowance (253,592 ) — — Other (251 ) (533 ) 1,028 Total income tax benefit $ 22,354 $ 4,140 $ 64,679 The tax effects of temporary differences that give rise to significant portions of the deferred income tax assets and liabilities are presented below (in thousands): December 31, 2015 2014 Deferred income tax assets (liabilities): Derivative financial instruments (35,481 ) (41,645 ) Net operating loss carryovers 183,964 97,022 Asset retirement obligation 7,118 11,596 Startup and organization costs 122 140 Deferred acquisition costs 45 45 Percentage depletion 1,360 1,341 Property and equipment costs 91,937 (95,379 ) Equity compensation 3,342 3,947 Other 1,185 579 Valuation allowance (253,592 ) — Total long term assets (liabilities) — (22,354 ) Net deferred tax asset (liability) $ — $ (22,354 ) The Company has U.S. net operating loss carry forwards of $505 million at December 31, 2015, which will begin expiring in 2026. The Company assesses the recoverability of its deferred tax assets each period by considering whether it is more likely than not that all or a portion of the deferred tax assets will be realized. The Company considers all available evidence (both positive and negative) in determining whether a valuation allowance is required. As a result of the Company's analysis, it was concluded that as of December 31, 2015 a valuation allowance should be established against the Company's deferred tax asset. The Company recorded a valuation allowance as of December 31, 2015 of $253.5 million on its deferred tax asset. The Company will continue to monitor facts and circumstances in the reassessment of the likelihood that the deferred tax assets will be realized. The Company adopted the accounting for uncertain tax positions per FASB ASC Topic 740, Accounting for Income Taxes, from inception. This guidance prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. This guidance requires that the Company recognize in our consolidated financial statements, only those tax positions that are “more-likely-than-not” of being sustained as of the adoption date, based on the technical merits of the position. As a result of the implementation of ASC 740.10, the Company performed a comprehensive review of our material tax positions. This guidance had no effect on the Company's financial position, cash flows or results of operations at 2015, 2014 or 2013 as the Company had no unrecognized tax benefits. The Company's policy is to recognize interest and penalties related to uncertain tax positions in income tax expense. The Company has no accrued interest or penalties related to uncertain tax positions as of December 31, 2015, 2014 or 2013. The Company early adopted ASU No. 2015-17, Income Tax (Topic 740): Balance Sheet Classification of Deferred Taxes, which requires that all deferred tax assets and liabilities, along with any related valuation allowance, be classified as noncurrent on the balance sheet. The Company applied this ASU retrospectively to all periods presented. The Company is subject to the following material taxing jurisdictions: U.S. federal, Colorado, Texas and Utah. The tax years that remain open to examination by the Internal Revenue Service are the years 2011 through 2015. The tax years that remain open to examination by state taxing authorities are 2010 through 2015.

Stockholders' Equity and Equity

Stockholders' Equity and Equity Based Awards	12 Months Ended
	Dec. 31, 2015
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Stockholders' Equity and Equity Based Awards	Note 7 — Stockholders’ Equity and Equity Based Awards Preferred Stock The Company is authorized to issue up to 1,000,000 shares of preferred stock, par value $0.0001 with such designations, voting and other rights and preferences as may be determined from time to time by the Board of Directors. No shares were issued and outstanding as of December 31, 2015 or December 31, 2014. Common Stock The authorized common stock of the Company consists of 225,000,000 shares. The holders of the common shares are entitled to one vote for each share of common stock. In addition, the holders of the common stock are entitled to receive dividends when, as and if declared by the Board of Directors. At December 31, 2015 and 2014, the Company had 77,210,735 and 77,634,737 shares of common stock issued and outstanding, respectively. During the second quarter 2013, the Company issued 13.3 million shares of common stock in a public offering at $8.00 per share for net proceeds of $101.8 million, after underwriting discounts and commissions. The net proceeds were used to repay outstanding borrowings under the Revolving Credit Facility. During 2015, 2014 and 2013, no warrants were repurchased. During 2015, 2014 and 2012, no warrants were exercised. At December 31, 2014, no warrants remain outstanding as all warrants expired on September 25, 2014. Resolute’s common stock trading price is currently below the $1.00 per share minimum price requirement of the New York Stock Exchange (the “NYSE”). The Company had been in non-compliance with the $1.00 per share requirement in early 2015 and subsequently received approval by its stockholders to effect a reverse stock split of our common stock at any time prior to December 31, 2015. That prior period of non-compliance was cured in June 2015 through higher trading prices for the common stock. The Company was again notified of non-compliance with the $1.00 per share requirement in July 2015. In consultation with the NYSE, the Company confirmed that NYSE policies permit the Company a period up until the 2016 annual stockholder meeting to bring the trading price of the Company’s common stock back up to the $1.00 continued listing standard. As such, the Company determined not to undertake the reverse stock split prior to year-end 2015. In the event that the trading price of the Company’s common stock does not increase as a result of market improvement before the 2016 annual stockholder meeting, then, in order to maintain its listing the Company will pursue approval by its stockholders of a reverse stock split, and consummate the reverse stock split promptly following the 2016 annual meeting. Resolute also received notification on November 30, 2015, from the NYSE that the Company’s market capitalization was below the NYSE’s continued listing standard. The Company is considered below criteria established by the NYSE because the Company’s average market capitalization fell below $50 million over a trailing consecutive 30 trading-day period and its last reported stockholders’ equity was less than $50 million. In accordance with NYSE procedures, the Company had 45 days from the receipt of the notice to submit a business plan to the NYSE demonstrating how it intends to regain compliance with the NYSE’s continued listing standards within eighteen months. Resolute developed and submitted such a business plan within the required time frame and the NYSE accepted the plan. The Company will be subject to quarterly monitoring for compliance with the business plan and the Company’s common stock will continue to trade on the NYSE during the eighteen month period, subject to the Company’s compliance with other NYSE continued listing requirements. The NYSE may choose to shorten the usual compliance period if prior to the end of the eighteen months the Company’s market capitalization is over $50 million for two consecutive quarters. Long-Term Employee Incentive Plan The Company accounts for share-based compensation in accordance with FASB ASC Topic 718, Stock Compensation On July 31, 2009, the Company adopted the Incentive Plan, providing for long-term share-based awards intended as a means for the Company to attract, motivate, retain and reward directors, officers, employees and other eligible persons through the grant of awards and incentives for high levels of individual performance and improved financial performance of the Company. The share-based awards are also intended to further align the interests of award recipients and the Company’s stockholders. The maximum number of shares of common stock that may be issued under the Incentive Plan is 12,257,744 (which includes the additional 3,100,000 shares under Amendment No. 2 to the incentive plan approved by the Company’s stockholders on June 8, 2015). On May 5, the Board and its Compensation Committee approved a long-term incentive program for 2015 under the Incentive Plan consisting of grants of (i) options to purchase shares of common stock of the Company, vesting in equal annual installments on each of the first three anniversaries of the date of grant, with an exercise price of $1.35 per share and a ten year term, (ii) time-vested restricted cash awards of $5.2 million, vesting in equal annual installments on each of the first three anniversaries of the date of grant, and (iii) performance-vested restricted cash awards of $2.9 million, as described below. On September 14, 2015, the Board and its Compensation Committee approved a grant consistent with the terms defined above of options to purchase shares of common stock of the Company, vesting in equal annual installments on each of the first three anniversaries of the date of grant, with an exercise price of $0.42 per share and a ten year term. For the Year Ended December 31, 2015 2014 2013 Stock option awards $ 365 $ — $ — Time-based restricted stock awards 9,067 12,101 11,023 Stock appreciation awards 45 240 751 TSR awards 2,848 3,990 3,150 Time-based restricted cash awards 959 — — Performance-based restricted cash awards 225 — — Total Incentive Plan compensation expense $ 13,509 $ 16,331 $ 14,924 As of December 31, 2015, the Company held unrecognized share-based compensation expense (in thousands) which is expected to be recognized over a weighted-average period as follows: Weighted Unrecognized Average Compensation Years Expense Remaining Stock option awards $ 5,320 2.3 Time-based restricted stock awards 1,662 0.9 TSR awards 1,326 0.8 Total unrecognized compensation expense $ 8,308 In February 2016, the Board of Directors and Compensation Committee of the Company approved long-term incentive awards to employees and non-employee directors for 2016 consisting of a combination of stock options, cash-settled stock appreciation rights and restricted cash grants under the Incentive Plan. The 2016 long-term incentive awards to employees and non-employee directors consisted of grants of (i) options to purchase 3,700,000 shares of common stock of the Company with a ten-year term, vesting in three equal annual installments on March 8 of 2017, 2018 and 2019, with exercise prices of $0.53 per share (as to 1,669,606 shares) and $0.583 per share (as to 2,030,394 shares), (ii) 8,514,381 cash-settled stock appreciation rights with a ten-year term, vesting in three equal annual installments on March 8 of 2017, 2018 and 2019, with a base price of $0.53 per share (as to 2,431,964 rights) and $0.583 per share (as to 6,082,417 rights), (iii) $5,310,000 time-vested restricted cash awards, vesting in three equal annual installments on March 8 of 2017, 2018 and 2019, and (iv) 225,748 shares of restricted stock vesting on March 8, 2017. Equity Awards Equity awards consist of service-based and performance-based restricted stock and stock options under the Incentive Plan. Stock Option Awards Options issued to employees to purchase shares of common stock vest in three equal annual installments at specified dates based on continued employment with a ten year term. The compensation expense to be recognized for the option awards was measured based on the Company’s estimated fair value at the date of grant using a Black-Scholes pricing model as well as an estimated forfeiture rate of 10%, no dividends, expected stock price volatility ranging from 63% to 67%, and a risk free rate ranging between 2.06% to 2.27%. During the year ended December 31, 2015, the Company granted 2,043,002 options, with a weighted-average exercise price of $1.28 per share, to employees to purchase shares of common stock, pursuant to the Incentive Plan. The following table summarizes the changes in non-vested option awards for the periods presented: 2015 Weighted Average Grant Date Shares Fair Value Non-vested, beginning of period — $ — Granted 2,043,002 0.92 Vested — — Forfeited (60,500 ) 0.97 Non-vested, end of period 1,982,502 $ 0.92 Time-Based Restricted Stock Awards Shares of time-based restricted stock issued to employees generally vest in three or four equal annual installments at specified dates based on continued employment. Shares issued to non-employee directors vest in one year based on continued services. The compensation expense to be recognized for the time-based restricted stock awards was measured based on the Company’s closing stock price on the dates of grant, utilizing estimated forfeiture rates between 0% and 20% which are updated periodically based on actual employee turnover. During the year ended December 31, 2015, the Company granted 160,500 shares of time-based restricted stock to employees and non-employee directors, pursuant to the Incentive Plan. The following table summarizes the changes in non-vested time-based restricted stock awards for the periods presented: 2015 2014 2013 Weighted Weighted Weighted Average Average Average Grant Date Grant Date Grant Date Shares Fair Value Shares Fair Value Shares Fair Value Non-vested, beginning of period 2,497,830 $ 9.43 2,005,721 $ 10.62 1,176,890 $ 12.00 Granted 160,500 1.35 1,595,535 8.86 1,570,393 10.31 Vested (1,110,683 ) 9.56 (819,615 ) 10.87 (559,763 ) 12.47 Forfeited (118,673 ) 8.80 (283,811 ) 9.65 (181,799 ) 11.15 Non-vested, end of period 1,428,974 $ 8.42 2,497,830 $ 9.43 2,005,721 $ 10.62 Stock Appreciation Awards For grants made through year-end 2012, performance-based shares generally vest in equal tranches beginning on December 31 of the year of the grant if there has been a 10% annual appreciation in the trading price of the Company’s common stock, compounded annually, from the twenty trading day average stock price ended on December 31 of the year prior to the grant (which was $11.639 for 2012 grants). At the end of each year, the twenty trading day average stock price will be measured, and if the 10% threshold is met, the stock subject to the performance criteria will vest. If the 10% threshold is not met, shares that have not vested will be carried forward to the following year subject to a four year maximum vesting period. These awards are referred to as “Stock Appreciation Awards.” At December 31, 2015, 2014 and 2013, 257,659, 156,793 and 390,174 of the Stock Appreciation Awards, respectively, were forfeited by their holders as the four year maximum vesting period for the grants had expired and the 10% threshold had not been met. The following table summarizes the changes in non-vested Stock Appreciation Awards for the periods presented: 2015 2014 2013 Weighted Weighted Weighted Average Average Average Grant Date Grant Date Grant Date Shares Fair Value Shares Fair Value Shares Fair Value Non-vested, beginning of period 266,652 $ 3.95 444,571 $ 7.60 895,892 $ 8.43 Granted — — — — — — Vested — — — — — — Forfeited (8,993 ) 3.75 (21,126 ) 7.04 (61,147 ) 7.82 Expired (257,659 ) 3.96 (156,793 ) 13.89 (390,174 ) 9.38 Non-vested, end of period — $ — 266,652 $ 3.95 444,571 $ 7.60 TSR Awards In 2014 and 2013, the Compensation Committee awarded 487,819 and 354,517 performance-based restricted shares, respectively, to executive officers of the Company under the Incentive Plan. The restricted stock grants vest only upon achievement of thresholds of cumulative total shareholder return (“TSR”) as compared to a specified peer group (the “Performance-Vested Shares”). A TSR percentile (the “TSR Percentile”) is calculated based on the change in the value of the Company’s common stock between the grant date and the applicable vesting date, including any dividends paid during the period, as compared to the respective TSRs of a specified group of seventeen peer companies. The Performance-Vested Shares vest in three installments to the extent that the applicable TSR Percentile ranking thresholds are met upon the one-, two- and three-year anniversaries of the grant date. Performance-Vested Shares that are eligible to vest on a vesting date, but do not qualify for vesting, become eligible for vesting again on the next vesting date. All Performance-Vested Shares that do not vest as of the final vesting date will be forfeited on such date. The Compensation Committee also granted rights to earn additional shares of common stock upon achievement of a higher TSR Percentile (“Outperformance Shares”). The Outperformance Shares are earned in increasing increments based on a TSR Percentile attained over a specified threshold. Outperformance Shares may be earned on any vesting date to the extent that the applicable TSR Percentile ranking thresholds are met in three installments on the one-, two- and three-year anniversaries of the grant date. Outperformance Shares that are earned at a vesting date will be issued to the recipient; however, prior to such issuance, the recipient is not entitled to stockholder rights with respect to Outperformance Shares. Outperformance Shares that are eligible to be earned but remain unearned on a vesting date become eligible to be earned again on the next vesting date. The right to earn any theretofore unearned Outperformance Shares terminates immediately following the final vesting date. The Performance-Vested Shares and the Outperformance Shares are referred to as the “TSR Awards.” The compensation expense to be recognized for the TSR Awards and Stock Appreciation Awards was measured based on the estimated fair value at the date of grant using a Monte Carlo simulation model and utilizes an estimated forfeiture rate of 4% which is updated periodically based on actual employee turnover. The valuation model for the Performance-Based Awards used the following assumptions: Grant Year Average Expected Volatility Expected Dividend Yield Risk-Free Interest Rate 2013 35.0% 0% 0.42% 2014 39.4% 0% 0.69% The following table summarized changes in non-vested TSR Awards for the periods presented: 2015 2014 2013 Weighted Weighted Weighted Average Average Average Grant Date Grant Date Grant Date Shares Fair Value Shares Fair Value Shares Fair Value Non-vested, beginning of period 764,598 $ 14.26 340,166 $ 15.91 — $ — Granted — — 487,819 13.32 354,517 15.91 Vested — — (63,387 ) 15.91 — — Forfeited — — — — (14,351 ) 15.91 Non-vested, end of period 764,598 $ 14.26 764,598 $ 14.26 340,166 $ 15.91 Liability Awards Liability awards consist of awards that are settled in cash instead of shares, as discussed below. Time-Based Restricted Cash Awards Awards of time-based restricted cash issued to employees vest in three equal annual increments at specified dates based on continued employment. Time based restricted cash issued to non-employee directors vest in one year based on continued service. The compensation expense to be recognized for the time-based restricted cash awards was measured utilizing an estimated forfeiture rate of 15% which will be updated periodically based on actual employee turnover. The total estimated future liability of the time-based restricted cash awards as of December 31, 2015, was $4.4 million, of which $1.0 million has been accrued. Performance-Based Restricted Cash Awards The performance criteria for the performance-based restricted cash awards granted in May 2015 are based on future prices of the Company’s common stock trading at or above specified thresholds. If and as certain stock price thresholds are met, using a 60 trading day average, various multiples of the performance-vested cash award will be attained. The first stock price hurdle is at $2.00 at which the award would be payable at 1x, and the highest stock price hurdle would be $8.00 at which the award would be payable at a multiple of 6x. Interim hurdles and multiples between these end points are set forth in the governing agreements. The performance-based cash awards have a ten year term ( i.e. The fair value of the performance-based restricted cash awards as of grant date and December 31, 2015, was $0.9 million and $0.6 million, respectively, of which $0.2 million has been accrued at year end based upon the three-year vesting. The fair value was estimated using an option pricing model for a cash or nothing call, an estimated forfeiture rate of 5% and an average effective term of seven years. As the fair value of liability awards is required to be re-measured at each period end, amounts recognized in future periods will vary.

Asset Retirement Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	Note 8 — Asset Retirement Obligation Resolute’s estimated asset retirement obligation liability is based on estimated economic lives, estimates as to the cost to abandon the wells in the future, and federal and state regulatory requirements. The liability is discounted using a credit-adjusted risk-free rate estimated at the time the liability is incurred or revised that ranges between 7% and 12%. Revisions to the liability could occur due to changes in estimated abandonment costs or well economic lives, or if federal or state regulators enact new requirements regarding the abandonment of wells. Asset retirement obligations are valued utilizing Level 3 fair value measurement inputs. The following table provides a reconciliation of Resolute’s asset retirement obligations for the periods presented (in thousands): December 31, 2015 2014 Asset retirement obligations at beginning of period $ 31,340 $ 31,989 Additional liability incurred / acquired 96 144 Accretion expense 2,740 2,576 Liabilities settled (15,177 ) (1,282 ) Revisions to previous estimates 239 (2,087 ) Asset retirement obligations at end of period 19,238 31,340 Less: current asset retirement obligations (891 ) (327 ) Long-term asset retirement obligations $ 18,347 $ 31,013

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2015
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Derivative Instruments	Note 9 — Derivative Instruments Resolute enters into commodity derivative contracts to manage its exposure to oil and gas price volatility. Resolute has not elected to designate derivative instruments as hedges under the provisions of FASB ASC Topic 815, Derivatives and Hedging The Company utilizes fixed price swaps, basis swaps, option contracts and two- and three-way collars. These instruments generally entitle Resolute (the floating price payer in most cases) to receive settlement from the counterparty (the fixed price payer in most cases) for each calculation period in amounts, if any, by which the settlement price for the scheduled trading days applicable to each calculation period is less than the fixed strike price or floor price. The Company would pay the counterparty if the settlement price for the scheduled trading days applicable to each calculation period exceeds the fixed strike price or ceiling price. The amount payable by Resolute, if the floating price is above the fixed or ceiling price, is the product of the notional contract quantity and the excess of the floating price over the fixed or ceiling price per calculation period. The amount payable by the counterparty, if the floating price is below the fixed or floor price, is the product of the notional contract quantity and the excess of the fixed or floor price over the floating price per calculation period. A three-way collar consists of a two-way collar contract combined with a put option contract sold by the Company with a strike price below the floor price of the two-way collar. The Company receives price protection at the purchased put option floor price of the two-way collar if commodity prices are above the sold put option strike price. If commodity prices fall below the sold put option strike price, the Company receives the cash market price plus the variance between the two put option strike prices. This type of instrument captures more value in a rising commodity price environment, but limits the benefits in a downward commodity price environment. Basis swaps, when used in connection with fixed price swaps, fix the price differential between the NYMEX commodity price and the index price at which the production is sold. As of December 31, 2015, the fair value of the Company’s commodity derivatives was a net asset of $95.9 million (Level 2 fair value measurement). The following table represents Resolute’s commodity swap contracts as of December 31, 2015: Oil (NYMEX WTI) Gas (NYMEX Henry Hub) Remaining Term Bbl per Day Weighted MMBtu per Day Weighted Average Swap Price per MMBtu Jan – Dec 2016 6,500 $ 80.42 — $ — July – Dec 2016 75 $ 52.75 5,100 $ 2.975 Jan – June 2017 65 $ 54.75 2,400 $ 3.083 The following table represents Resolute’s three-way oil collar contracts as of December 31, 2015: Oil (NYMEX WTI) Weighted Average Weighted Average Weighted Average Remaining Term Bbl per Day Short Put Price per Bbl Floor Price per Bbl Ceiling Price per Bbl Jan – Dec 2017 1,000 $ 45.00 $ 60.00 $ 71.73 Subsequent to December 31, 2015, Resolute entered into additional commodity derivative contracts as summarized below: Oil (NYMEX WTI) Gas (NYMEX Henry Hub) Commodity Swap Bbl per Day Weighted MMBtu per Day Weighted Average Swap Price per MMBtu Apr - June 2016 — — 4,600 $ 1.805 Jan - Dec 2017 1,000 $ 49.00 — — Jan - Mar 2017 — — 1,600 $ 2.488 Apr - June 2017 — — 1,700 $ 2.327 Gas (NYMEX Henry Hub) Two -Way Collar MMBtu per Day Weighted Average Floor Price per MMBtu Weighted Average Ceiling Price per MMBtu July - Sept 2017 3,250 $ 2.25 $ 2.53 Oct - Dec 2017 3,250 $ 2.25 $ 2.75 Oil (NYMEX WTI) Oil Call Contract Bbl per Day Sold Call Price Jan - Dec 2018 1,100 $ 50.00 Resolute does not offset the fair value amounts of derivative assets and liabilities with the same counterparty for financial reporting purposes. See Note 10 for the location and fair value amounts of Resolute’s commodity derivative instruments reported in the consolidated balance sheets at December 31, 2015 and 2014. The table below summarizes the location and amount of commodity derivative instrument gains and losses reported in the consolidated statements of income (in thousands): 2015 2014 2013 Other income (expense): Commodity derivative settlements $ 93,150 $ (4,988 ) $ (35,812 ) Mark-to-market gain (16,658 ) 123,129 20,476 Commodity derivative instruments gain (loss) $ 76,492 $ 118,141 $ (15,336 ) Credit Risk and Contingent Features in Derivative Instruments Resolute is exposed to credit risk to the extent of nonperformance by the counterparties in the derivative contracts discussed above. All counterparties are lenders under Resolute’s Revolving Credit Facility. Accordingly, Resolute is not required to provide any credit support to its counterparties other than cross collateralization with the properties securing the Revolving Credit Facility. Resolute’s derivative contracts are documented with industry standard contracts known as a Schedule to the Master Agreement and International Swaps and Derivative Association, Inc. Master Agreement (“ISDA”). Typical terms for each ISDA include credit support requirements, cross default provisions, termination events, and set-off provisions. Resolute has set-off provisions with its lenders that, in the event of counterparty default, allow Resolute to set-off amounts owed under the Revolving Credit Facility or other general obligations against amounts owed for derivative contract liabilities. The maximum amount of loss in the event of all counterparties defaulting is $95.9 million as of December 31, 2015, due to the set off provisions noted above.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 10 — Fair Value Measurements FASB ASC Topic 820 , Fair Value Measurements and Disclosures, — Level 1 – Quoted prices in active markets for identical assets or liabilities. — Level 2 – Quoted prices in active markets for similar assets and liabilities, quoted prices for identical or similar instruments in markets that are not active and model-derived valuations whose inputs are observable or whose significant value drivers are observable. — Level 3 – Significant inputs to the valuation model are unobservable. An asset or liability subject to the fair value requirements is categorized within the hierarchy based on the lowest level of input that is significant to the fair value measurement. Resolute’s assessment of the significance of a particular input to the fair value measurement in its entirety requires judgment and considers factors specific to the asset or liability. Following is a description of the valuation methodologies used by Resolute as well as the general classification of such instruments pursuant to the hierarchy. As of December 31, 2015, Resolute’s commodity derivative instruments were required to be measured at fair value on a recurring basis. Resolute used the income approach in determining the fair value of its derivative instruments, utilizing present value techniques for valuing its swaps and basis swaps and option-pricing models for valuing its options. Inputs to these valuation techniques include published forward index prices, volatilities, and credit risk considerations, including the incorporation of published interest rates and credit spreads. Substantially all of these inputs are observable in the marketplace throughout the full term of the contract, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace and are therefore designated as Level 2 within the valuation hierarchy. The following is a listing of Resolute’s commodity derivative assets and liabilities required to be measured at fair value on a recurring basis and where they are classified within the hierarchy as of December 31, 2015, and December 31, 2014 (in thousands): Level 2 December 31, 2015 December 31, 2014 Assets Derivative instruments, current $ 92,431 $ 72,753 Derivative instruments, long term 3,463 39,799 Total assets $ 95,894 $ 112,552

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2015
Commitments And Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 11 — Commitments and Contingencies CO 2 Take-or-Pay Agreements Resolute is party to a take-or-pay purchase agreement with Kinder Morgan CO 2 2 2 2 2 Future minimum CO 2 CO 2 Year Commitments 2016 12,078 2017 546 Total $ 12,624 Operating Leases Rental payments expensed under operating leases for office facilities were approximately $1.1 million, $1.6 million and $2.0 million during 2015, 2014 and 2013, respectively. Net rental payments expensed under operating leases for compressors and other oilfield equipment were approximately $1.9 million, $2.6 million and $2.9 million during 2015, 2014 and 2013, respectively. Future payments for the Company’s office facilities, equipment leases and vehicle leases under these operating lease agreements, as of December 31, 2015, are as follows (in thousands): Year Office Lease Rentals Field Equipment Rentals Vehicle Lease Rentals Total 2016 $ 1,832 $ 4,782 $ 766 $ 7,380 2017 1,699 1,275 346 3,320 2018 1,560 — 107 1,667 2019 and thereafter 4,390 — 10 4,400 Total $ 9,481 $ 6,057 $ 1,229 $ 16,767 Escrow Funding Agreement Under the terms of Resolute’s predecessor Company’s purchase of working interests in Aneth Field from ExxonMobil Corporation (the “ExxonMobil Properties”) in 2006, Resolute and NNOGC were required to fund an escrow account sufficient to complete abandonment, well plugging, site restoration and related obligations arising from ownership of the acquired interests. The contribution net to the Company’s working interest, is included in “other assets: restricted cash” in the consolidated balance sheets at December 31, 2015 and 2014. The Company is required to make additional deposits to the escrow account annually. In 2016, Resolute must fund approximately $1.6 million. In years after 2016, the Company must fund additional payments averaging approximately $0.9 million per year until 2031. Total contributions from the date of acquisition through 2031 will aggregate $26.0 million. Annual interest earned in the escrow account, if any, becomes part of the balance and reduces the payment amount required for funding the escrow account each year. As of December 31, 2015, the Company has funded the 2015 annual contractual amount of approximately $1.6 million required to meet its future obligation. NNOGC Purchase Options Resolute’s purchase of the Aneth Field Properties was facilitated by the predecessor Company’s strategic alliance with NNOGC and, through NNOGC, the Navajo Nation. This strategic alliance with NNOGC is embodied in a Cooperative Agreement consummated with NNOGC in 2004 to facilitate the joint acquisition of working interests in Greater Aneth from Chevron Corporation and its affiliates (the “Chevron Properties”). The agreement was amended subsequently to facilitate the joint acquisition of the ExxonMobil Properties and was amended again in conjunction with the sale of 10% of the Company’s interest in Aneth Field to NNOGC during the second quarter of 2012. Under the original terms of the Cooperative Agreement, NNOGC was granted three separate but substantially similar purchase options. Each purchase option entitled NNOGC to purchase from Resolute up to 10% of the undivided working interests in the Chevron Properties or the ExxonMobil Properties, as applicable, as to each unit in the Aneth Field Properties. The Cooperative Agreement amendment executed in 2012 provides for the cancellation of the second set of options held by NNOGC to purchase an additional 10% interest in the Aneth Field Properties and stipulates that NNOGC has one remaining option to purchase an additional 10% of the Company’s interest in the Aneth Field Properties (as it stood prior to the current option exercise and excluding the interest acquired from Denbury and certain other minority interests). The remaining option is exercisable in July 2017 at the then current fair market value of such interest. The exercise by NNOGC of its remaining purchase option in full would not give it the right to remove Resolute as operator of any of the Aneth Field Properties.

Supplemental Oil and Gas Inform

Supplemental Oil and Gas Information	12 Months Ended
	Dec. 31, 2015
Extractive Industries [Abstract]
Supplemental Oil and Gas Information	Note 12 — Supplemental Oil and Gas Information (unaudited) Costs Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Costs incurred during 2015, 2014 and 2013 related to oil and gas property acquisition, exploration and development activities, including the fair value of oil and gas properties acquired are summarized as follows (in thousands): 2015 2014 2013 Acquisition costs Proved $ — $ — $ 155,958 Unproved 6,583 7,007 121,362 Exploration costs 13,764 111,769 150,072 Development costs* 39,883 50,291 97,308 Total $ 60,230 $ 169,067 $ 524,700 * Includes $8.9 million, $16.3 million and $20.0 million of acquired CO 2 . Capitalized Costs of Oil and Gas Properties Net capitalized costs related to Resolute’s oil and gas producing activities at December 31, 2015 and December 31, 2014 were as follows (in thousands): 2015 2014 Proved oil and gas properties $ 1,732,707 $ 1,706,847 Unevaluated oil and gas properties, not subject to amortization 21,264 270,375 Accumulated depletion, depreciation and amortization (1,534,479 ) (738,979 ) Oil and gas properties, net $ 219,492 $ 1,238,243 Oil and Gas Reserve Quantities The reserve data as of December 31, 2015, was prepared by Resolute. Netherland, Sewell & Associates, Inc. (“NSAI”), independent petroleum engineers, audited all properties. Users of this information should be aware that the process of estimating quantities of proved oil and gas reserves is very complex, requiring significant subjective decisions to be made in the evaluation of available geological, engineering and economic data for each reservoir. The data for a given reservoir may also change substantially over time as a result of numerous factors, including, but not limited to, additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. As a result, revisions to existing reserves estimates may occur from time to time. Although every reasonable effort is made to ensure reserves estimates reported represent the most accurate assessments possible, the subjective decisions and variances in available data for various reservoirs make these estimates generally less precise than other estimates included in the financial statement disclosures. Presented below is a summary of the changes in estimated reserves (in thousands): Oil Equivalent Oil (Bbl) Gas (MMcf) NGL (Bbl) (Boe) (1) Proved reserves as of January 1, 2013 62,557 47,721 8,264 78,774 Purchase of minerals in place 4,592 10,821 1,422 7,818 Production (3,499 ) (4,565 ) (207 ) (4,467 ) Extensions, discoveries and other additions (2) 4,038 6,128 746 5,805 Sales of minerals in place (5,124 ) (3,379 ) (219 ) (5,906 ) Revisions of previous estimates (3) (15,053 ) (14,337 ) (5,189 ) (22,630 ) Proved reserves as of December 31, 2013 47,511 42,389 4,817 59,394 Purchase of minerals in place — — — — Production (3,489 ) (6,942 ) — (4,647 ) Extensions, discoveries and other additions (2) 25,756 10,128 1,357 28,800 Sales of minerals in place (215 ) (26 ) (5 ) (224 ) Revisions of previous estimates (5,848 ) (8,751 ) (1,799 ) (9,105 ) Proved reserves as of December 31, 2014 63,715 36,798 4,370 74,218 Purchase of minerals in place — — — — Production (3,270 ) (5,193 ) (400 ) (4,535 ) Extensions, discoveries and other additions (2) 1,965 8,208 1,269 4,602 Sales of minerals in place (5,289 ) (23,674 ) (2,837 ) (12,072 ) Revisions of previous estimates (28,373 ) (2,279 ) (341 ) (29,093 ) Proved reserves as of December 31, 2015 28,748 13,860 2,061 33,120 Proved developed reserves: As of December 31, 2015 25,672 7,098 1,019 27,874 As of December 31, 2014 34,359 25,775 2,791 41,446 As of December 31, 2013 38,791 29,488 3,136 46,842 Proved undeveloped reserves: As of December 31, 2015 3,076 6,761 1,043 5,246 As of December 31, 2014 29,356 11,023 1,579 32,772 As of December 31, 2013 8,720 12,901 1,681 12,552 1) 2) Extensions, discoveries and other additions in 2015 are associated with the Permian drilling program in Reeves County resulting in 576 MBoe added to proved developed producing reserves from drilling proved locations, and 970 MBoe from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 3,632 MBoe reserves. Extensions, discoveries and other additions in 2014 were primarily associated with reinstatement of CO2 enhanced recovery projects that were removed for year-end 2013 reporting to comply with the SEC five-year rule pertaining to undeveloped reserves. Approximately 21.1 MMBoe had been reinstated as proved undeveloped all comprised of four named CO2 injection projects identified in the Aneth Field Properties: 8.9 MMBoe for Aneth Unit Phase 4 CO2 injection, 3.0 MMBoe for McElmo Unit DCIIC CO2 injection, 4.9 MMBoe for Ratherford DCIA CO2 injection and 4.3 MMBoe for Ratherford DCIIC CO2 injection. Additionally, the Permian Basin and Powder River Basin properties held active drilling programs in 2014 resulting in 1.7 MMBoe added to proved developed producing from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 6.0 MMBoe reserves. 3) Decreases in proved reserves associated with revisions of previous estimates resulted primarily from reduced product pricing. Deferral of the Aneth CO 2 Standardized Measure of Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves: The following summarizes the policies used in the preparation of the accompanying oil and gas reserves disclosures, standardized measures of discounted future net cash flows from proved oil and gas reserves and the reconciliations of standardized measures at December 31, 2015. The information disclosed is an attempt to present the information in a manner comparable with industry peers. The information is based on estimates of proved reserves attributable to Resolute’s interest in oil and gas properties as of December 31, 2015. Proved reserves are estimated quantities of oil and gas that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. The standardized measure of discounted future net cash flows from production of proved reserves was developed as follows: 1) Estimates were made of quantities of proved reserves and future periods during which they are expected to be produced based on year-end economic conditions. 2) The estimated future cash flows were compiled by applying average annual prices of oil and gas relating to Resolute’s proved reserves to the year-end quantities of those reserves. 3) The future cash flows were reduced by estimated production costs, costs to develop and produce the proved reserves and abandonment costs, all based on year-end economic conditions. 4) Future income tax expenses were based on year-end statutory tax rates giving effect to the remaining tax basis in the oil and gas properties, other deductions, credits and allowances relating to Resolute’s proved oil and gas reserves. 5) Future net cash flows were discounted to present value by applying a discount rate of 10%. The standardized measure of discounted future net cash flows does not purport, nor should it be interpreted, to present the fair value of Resolute’s oil and gas reserves. An estimate of fair value would also take into account, among other things, the recovery of reserves not presently classified as proved, anticipated future changes in prices and costs and a discount factor more representative of the time value of money and the risks inherent in reserve estimates. The following summary sets forth Resolute’s future net cash flows relating to proved oil and gas reserves based on the standardized measure prescribed by FASB ASC Topic 932: December 31, 2015 2014 2013 (in thousands) Future cash inflows $ 1,293,000 $ 5,858,000 $ 4,647,000 Future production costs (774,000 ) (2,719,000 ) (2,050,000 ) Future development costs (180,000 ) (1,008,000 ) (547,000 ) Future income taxes — (412,000 ) (398,000 ) Future net cash flows 339,000 1,719,000 1,652,000 10% annual discount for estimated timing of cash flows (140,000 ) (886,000 ) (759,000 ) Standardized measure of discounted future net cash flows $ 199,000 $ 833,000 $ 893,000 The principal sources of change in the standardized measure of discounted future net cash flows are: December 31, 2015 2014 2013 (in thousands) Standardized measure, beginning of year $ 833,000 $ 893,000 $ 872,000 Sales of oil and gas produced, net of production costs (181,000 ) (196,000 ) (206,000 ) Net changes in prices and production costs (917,000 ) (191,000 ) 61,000 Purchases of minerals in place — — 106,000 Sales of minerals in place (134,000 ) (6,000 ) (84,000 ) Previously estimated development costs incurred during the year 33,000 49,000 89,000 Extensions, discoveries and improved recovery 13,000 207,000 111,000 Changes in estimated future development costs 119,000 (13,000 ) (64,000 ) Revisions of previous quantity estimates 196,000 (16,000 ) (203,000 ) Accretion of discount 70,000 89,000 79,000 Net change in income taxes 104,000 44,000 67,000 Changes in timing and other 63,000 (27,000 ) 65,000 Standardized measure, end of year $ 199,000 $ 833,000 $ 893,000

Quarterly Financial Data

Quarterly Financial Data	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data	Note 13 — Quarterly Financial Data (unaudited) The following is a summary of the unaudited financial data for each quarter for the years ended December 31, 2015 and 2014 (in thousands except per share data): Three Months Ended March 31, June 30, September 30, December 31, 2015 2015 2015 2015 Year Ended December 31, 2015 Revenue $ 41,133 $ 48,396 $ 36,617 $ 28,498 Operating expenses (285,469 ) (270,291 ) (253,484 ) (122,104 ) Income (loss) from operations (244,336 ) (221,895 ) (216,867 ) (93,606 ) Net income (loss) (208,222 ) (259,107 ) (182,770 ) (92,180 ) Earnings (loss) per common share: Basic $ (2.80 ) $ (3.46 ) $ (2.44 ) $ (1.23 ) Diluted $ (2.80 ) $ (3.46 ) $ (2.44 ) $ (1.23 ) Weighted average common shares outstanding: Basic 74,284 74,826 74,857 74,897 Diluted 74,284 74,826 74,857 74,897 Three Months Ended March 31, June 30, September 30, December 31, 2014 2014 2014 2014 Year Ended December 31, 2014: Revenue $ 90,878 $ 88,459 $ 84,102 $ 65,932 Operating expenses (79,803 ) (81,527 ) (81,384 ) (199,331 ) Income (loss) from operations 11,075 6,932 2,718 (133,399 ) Net income (loss) (3,548 ) (16,120 ) 14,966 (17,148 ) Earnings (loss) per common share: Basic $ (0.05 ) $ (0.22 ) $ 0.20 $ (0.23 ) Diluted $ (0.05 ) $ (0.22 ) $ 0.20 $ (0.23 ) Weighted average common shares outstanding: Basic 73,540 73,843 73,886 73,917 Diluted 73,540 73,843 74,050 73,917

Basis of Presentation and Sum20

Basis of Presentation and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The consolidated financial statements include Resolute and its subsidiaries, and have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”). All significant intercompany transactions have been eliminated upon consolidation. Certain prior period amounts have been reclassified to conform to the current period presentation. In connection with the preparation of the consolidated financial statements, Resolute evaluated subsequent events that occurred after the balance sheet date, through the date of filing.
Assumptions, Judgments and Estimates	Assumptions, Judgments and Estimates The preparation of the consolidated financial statements in conformity with GAAP requires management to make various assumptions, judgments and estimates to determine the reported amounts of assets, liabilities, revenue and expenses, and in the disclosures of commitments and contingencies. Changes in these assumptions, judgments and estimates will occur as a result of the passage of time and the occurrence of future events. Accordingly, actual results could differ from amounts previously established. Significant estimates with regard to the consolidated financial statements include proved oil and gas reserve volumes and the related present value of estimated future net cash flows used in the ceiling test applied to capitalized oil and gas properties; asset retirement obligations; valuation of derivative assets and liabilities; the estimated fair value and allocation of the purchase price related to business combinations; share-based compensation expense; depletion depreciation, and amortization; accrued liabilities; revenue and related receivables and income taxes.
Fair Value of Financial Instruments	Fair Value of Financial Instruments The carrying amount of the majority of Resolute’s financial instruments, namely cash and cash equivalents, accounts receivable and accounts payable, approximate their fair value because of the short-term nature of these instruments. The revolving credit facility (see Note 5) has a recorded value that approximates its fair market value while the fair value of the $400 million in principal senior notes due May 1, 2020 (the “Senior Notes” or the “Notes”) and the $128.3 million in the second lien secured term loan due March 2018 (the “Secured Term Loan Facility”) are based on data from independent market makers or price received at measurement date. The fair value of derivative instruments (see Note 10) is estimated based on market conditions in effect at the end of each reporting period.
Industry Segment and Geographic Information	Industry Segment and Geographic Information Resolute conducts oil, gas and natural gas liquids (“NGL”) exploration and production operations in one segment. All of Resolute’s operations and assets are located in the United States, and all of its revenue is attributable to domestic customers. Resolute considers gathering, processing and marketing functions as supportive of its oil and gas producing activities, and accordingly, they are not reported as separate segments.
Cash and Cash Equivalents	Cash and Cash Equivalents Resolute considers all highly liquid investments with original maturities of three months or less at the date of purchase to be cash equivalents. Resolute periodically maintains cash and cash equivalents in bank deposit accounts and money market funds which may be in excess of federally insured amounts. Resolute has not experienced any losses in such accounts and believes it is not exposed to any significant credit risk on such accounts.
Accounts Receivable	Accounts Receivable The Company’s accounts receivable consist of the following for the periods indicated (in thousands): December 31, 2015 2014 Trade receivables $ 14,224 $ 23,240 Revenue receivables 12,967 27,926 Derivative receivables 9,759 6,638 Other receivables 150 105 Total accounts receivable $ 37,100 $ 57,909 The Company’s accounts receivable consist mainly of receivables from oil, gas, and NGL purchasers and from joint interest owners on properties the Company operates. For receivables from joint interest owners, the Company typically has the ability to withhold future revenue disbursements to recover non-payment of joint interest billings. Generally, the Company’s oil and gas receivables are due within fifteen days and are collected in less than two months, and the Company has had minimal bad debts. The Company routinely assesses the recoverability of all material trade and other receivables to determine their collectability. As of December 31, 2015 and 2014, the Company had no allowance for doubtful accounts recorded.
Deferred Financing Costs	Deferred Financing Costs In 2015, the Financial Accounting Standards Board (“FASB”) issued new authoritative guidance related to the presentation of deferred financing costs. This authoritative guidance is effective for the annual period beginning after December 15, 2015, including interim reporting periods within that reporting period. The new guidance proscribes the application be applied retrospectively. The Company has elected to early adopt this guidance in 2015. Accordingly, the Company has reclassified certain deferred financing costs to a direct deduction from the carrying amounts of debt for the balance sheets at December 31, 2015 and 2014 (see Note 5). Deferred financing costs are amortized over the estimated life of the related obligation. The Company incurred $0 in deferred financing costs in 2015, $4.8 million in 2014 and $1.9 million in 2013, and amortized $5.0 million, $2.5 million and $2.7 million to interest expense during 2015, 2014 and 2013, respectively.
Capitalized Interest	Capitalized Interest Interest is capitalized when associated with significant investments in unproved properties and major development projects that are excluded from current depletion, depreciation and amortization calculations and on which exploration or development activities are in progress. Capitalized interest is calculated by multiplying the Company’s weighted-average interest rate on debt outstanding by the amount of qualified costs. Costs excluded from the depletion, depreciation and amortization calculations are classified as unproved properties along with any associated capitalized interest. Capitalized interest totaled $6.0 million, $14.9 million and $15.9 million during 2015, 2014 and 2013, respectively.
Concentration of Credit Risk	Concentration of Credit Risk Financial instruments that potentially subject Resolute to concentrations of credit risk consist primarily of trade, production and derivative settlement receivables. Resolute derived approximately 58% and 14% of its total 2015 revenue from Western Refining, Inc. (“Western”) and Holly Frontier LLC, respectively; 62% and 14% of its total 2014 revenue from Western and Plains Marketing LP, respectively and 61% and 15% of its total 2013 revenue from Western and Plains Marketing LP, respectively. If Resolute was compelled to sell its oil to an alternative market, costs associated with the transportation of its production may increase, and such increase could materially and negatively affect its operations. The concentration of credit risk in the oil and gas industry affects the overall exposure to credit risk because customers may be similarly affected by changes in economic or other conditions. The creditworthiness of customers and other counterparties is subject to continuing review, including the use of master netting agreements where appropriate. Commodity derivative contracts expose Resolute to the credit risk of non-performance by the counterparty to the contracts. This exposure is diversified among major investment grade financial institutions, all of which participate in Resolute’s Revolving Credit Facility (see Note 5).
Oil and Gas Properties	Oil and Gas Properties The Company uses the full cost method of accounting for oil and gas producing activities. All costs incurred in the acquisition, exploration and development of properties, including costs of unsuccessful exploration, costs of surrendered and abandoned leaseholds, delay lease rentals and the fair value of estimated future costs of site restoration, dismantlement and abandonment activities, improved recovery systems and a portion of general and administrative and operating expenses are capitalized on a country wide basis (the “Cost Center”). Resolute conducts tertiary recovery projects on certain of its oil and gas properties in order to recover additional hydrocarbons that are not recoverable from primary or secondary recovery methods. Under the full cost method, all development costs are capitalized at the time incurred. Development costs include charges associated with access to and preparation of well locations, drilling and equipping development wells, test wells, and service wells including injection wells, and acquiring, constructing, and installing production facilities and providing for improved recovery systems. Improved recovery systems include all related facility development costs and the cost of the acquisition of tertiary injectants, primarily purchased carbon dioxide (“CO 2 2 2 2 In contrast, other costs related to the daily operation of the improved recovery systems are considered production costs and are expensed as incurred. These costs include, but are not limited to, compression, electricity, separation, re-injection of recovered CO 2 Capitalized general and administrative and operating costs include salaries, employee benefits, costs of consulting services and other specifically identifiable capital costs and do not include costs related to production operations, general corporate overhead or similar activities. Resolute capitalized general and administrative and operating costs related to its acquisition, exploration and development activities of $6.3 million during 2015, $9.8 million during 2014 and $8.4 million during 2013. Investments in unproved properties are not depleted, pending determination of the existence of proved reserves. The Company’s investments in unproved properties are related to exploration plays in the Permian Basin in Texas and southeast New Mexico. The Company expects to evaluate these locations for the existence of proved reserves in the next three years, although volatility in commodity prices may impact the timing of the evaluation. Unproved properties are assessed at least annually to determine whether impairment has occurred. Unproved properties whose costs are individually significant are assessed individually by considering the primary lease terms of the properties, the holding period of the properties and geographic and geologic data obtained relating to the properties. Where it is not practicable to assess individually the amount of impairment of properties for which costs are not individually significant, such properties are grouped for purposes of assessing impairment. The amount of impairment assessed is added to the costs to be amortized. No gain or loss is recognized upon the sale or abandonment of undeveloped or producing oil and gas properties unless the sale represents a significant portion of the Company’s oil and gas properties and the gain or loss significantly alters the relationship between the capitalized costs and proved reserves of the cost center. Depletion of oil and gas properties is computed on the unit-of-production method based on proved reserves. Depletable costs include estimates of asset retirement obligations and future development costs of proved reserves, including, but not limited to, costs to drill and equip development wells, construct and install production and processing facilities, and improved recovery systems, including the cost of required future CO 2 Pursuant to full cost accounting rules, Resolute is required to perform a quarterly “ceiling test” calculation to test its oil and gas properties for possible impairment. The primary components impacting the calculation are commodity prices, reserve quantities added and produced, overall exploration and development costs and depletion expense. If the net capitalized cost of the Company’s oil and gas properties subject to the amortization (the “carrying value”) exceeds the ceiling limitation, the excess would be charged to expense. The ceiling limitation is equal to the sum of the present value discounted at 10% of estimated future net cash flows from proved reserves, the cost of properties not being amortized, the lower of cost or estimated fair value of unproven properties included in the costs being amortized, and all related income tax effects. During 2015, 2014 and 2013, the Company recorded $705 million, $120 million and $188 million, respectively, non-cash impairment of the carrying value of its oil and gas properties as a result of the ceiling test limitation. If in future periods a negative impact continues on one or more of the components of the calculation, including market prices of oil and gas (based on a trailing twelve-month unweighted average of the oil and gas prices in effect on the first day of each month), differentials from posted prices, future drilling and capital plans, operating costs or expected production, the Company may incur further full cost ceiling impairment related to its oil and gas properties in such periods.
Business Combinations	Business Combinations The Company accounts for all business combinations using the acquisition method which involves the use of significant judgment. Under the acquisition method of accounting, a business combination is accounted for based on the fair value of the consideration given. The assets and liabilities acquired are measured at fair value and the purchase price is allocated to the assets and liabilities based on these fair values. The excess of the cost of an acquisition, if any, over the fair value of the assets acquired and liabilities assumed is recognized as goodwill. The excess of the fair value of assets acquired and liabilities assumed over the cost of an acquisition, if any, is recognized immediately in earnings as a gain. Determining the fair values of the assets and liabilities acquired involves the use of judgment as fair values are not always readily determinable. Different techniques may be used to determine fair values, including market prices (where available), appraisals, comparisons to transactions for similar assets and liabilities and the present value of estimated future cash flows, among others.
Other Property and Equipment	Other Property and Equipment Other property and equipment are recorded at cost. Costs of renewals and improvements that substantially extend the useful lives of the assets are capitalized. Maintenance and repair costs which do not extend the useful lives of property and equipment are charged to expense as incurred. Depreciation and amortization is calculated using the straight-line method over the estimated useful lives of the assets. Office furniture, automobiles, and computer hardware and software are depreciated over three to five years. Field offices and partial ownership of aircraft are depreciated over fifteen to twenty years. Leasehold improvements are depreciated, using the straight line method, over the shorter of the lease term or the useful life of the asset. When other property and equipment is sold or retired, the capitalized costs and related accumulated depreciation and amortization are removed from the accounts.
Impairment of Long-Lived Assets Other than Oil and Gas Properties	Impairment of Long-Lived Assets Other than Oil and Gas Properties Resolute evaluates long-lived assets other than oil and gas properties for impairment when indicators of possible impairment are present. Resolute performs an analysis of the anticipated undiscounted future net cash flows of the related long-lived assets and if the carrying value of the related asset exceeds the undiscounted cash flows, the carrying value is reduced to the asset’s fair value and an impairment loss is recorded against the long-lived asset. There have been no provisions for impairment of long-lived assets other than oil and gas properties recorded for the years ended December 31, 2015, 2014 and 2013.
Asset Retirement Obligations	Asset Retirement Obligations Asset retirement obligations relate to future costs associated with the plugging and abandonment of oil and gas wells, removal of equipment and facilities from leased acreage and returning such land to its original condition. The fair value of a liability for an asset retirement obligation is recorded in the period in which it is incurred and the cost of such liability is recorded as an increase in the carrying amount of the related long-lived asset by the same amount. The liability is accreted each period and the capitalized cost is depleted as part of the full cost pool. Revisions to estimated asset retirement obligations result in adjustments to the related capitalized asset and corresponding liability. The restricted cash of $21.5 million located on the Company’s consolidated balance sheet in non-current other assets at December 31, 2015, is legally restricted for the purpose of settling asset retirement obligations of Aneth Field.
Derivative Instruments	Derivative Instruments Resolute utilizes derivative instruments to manage its exposure to oil and gas price volatility and these instruments may take the form of swaps, puts, calls, collars and other such arrangements. Derivative instruments are recognized on the balance sheet as either assets or liabilities measured at fair value. Resolute has not elected to apply cash flow hedge accounting, and consequently, recognizes gains and losses in earnings rather than deferring such amounts in other comprehensive income as allowed under cash flow hedge accounting. Realized gains and losses on derivative instruments are recognized in the period in which the related contract is settled. Both the realized and mark-to-market gains and losses on derivative instruments are reflected in other income (expense) in the consolidated statements of income. Cash flows from derivatives are reported as cash flows from operating activities.
Revenue Recognition	Revenue Recognition Oil and gas revenue is recognized when production is sold to a purchaser at a fixed or determinable price, when delivery has occurred and title has transferred and the collectability of the revenue is probable. Oil and gas revenue is recorded using the sales method.
General and Administrative Expenses	General and Administrative Expenses General and administrative expenses are reported net of amounts capitalized to oil and gas properties and of reimbursements of overhead costs that are billed to working interest owners of the oil and gas properties operated by Resolute.
Share-Based Compensation Expense	Share-Based Compensation Expense Share-based compensation expense is measured at the estimated grant date fair value of the awards and is amortized over the requisite service period (usually the vesting period). The Company estimates forfeitures in calculating the cost related to share-based compensation as opposed to recognizing these forfeitures and the corresponding reduction in expense as they occur.
Income Taxes	Income Taxes Income taxes and uncertain tax positions are accounted for in accordance with FASB Accounting Standards Codification (“ASC”) Topic 740, Accounting for Income Taxes The FASB issued Accounting Standards Update (ASU) 2015-17, Balance Sheet Classification of Deferred Taxes

Basis of Presentation and Sum21

Basis of Presentation and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Accounts Receivable	The Company’s accounts receivable consist of the following for the periods indicated (in thousands): December 31, 2015 2014 Trade receivables $ 14,224 $ 23,240 Revenue receivables 12,967 27,926 Derivative receivables 9,759 6,638 Other receivables 150 105 Total accounts receivable $ 37,100 $ 57,909

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
Unaudited Pro Forma Financial Information on Properties Sold	The unaudited pro forma financial information for the year ended December 31, 2015 reflects Resolute’s 2015 results as if the Gardendale, Hilight Field, and Howard and Martin County properties were sold on January 1, 2015 (in thousands, except per share amounts): 2015 Total revenue $ 123,830 Loss from operations (775,872 ) Net loss (730,381 ) Basic and diluted net loss per common share $ (9.75 )
Final Purchase Price Allocation of New Permian Properties	The Company has completed its assessment of the fair values of the assets acquired and liabilities assumed. Accordingly, the following table presents the final purchase price allocation of the Permian Acquisitions at December 31, 2013, based on the fair values of assets acquired and liabilities assumed (in thousands): 2013 Proved oil and gas properties $ 93,000 Unproved oil and gas properties 167,000 Asset retirement obligations assumed (2,000 ) Total purchase price $ 258,000
Unaudited Pro Forma Financial Information	The unaudited pro forma financial information for the year ended December 31, 2013 combines the historical results of the Permian Acquisitions and Resolute (in thousands, except per share amounts): 2013 Revenue $ 360,837 Revenue in excess of operating expenses 215,273 Net income (loss) (111,243 ) Basic and diluted net income (loss) per share $ (1.63 )

Earnings per Share (Tables)

Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2015
Earnings Per Share [Abstract]
Weighted Average Dilutive and Anti-Dilutive Securities	The following table details the potential weighted average dilutive and anti-dilutive securities for the periods presented (in thousands): Twelve Months Ended December 31, 2015 2014 2013 Potential dilutive restricted stock 1,779 2,973 2,529 Anti-dilutive securities 4,901 27,523 35,569
Computation of Basic and Diluted Net Income (Loss) per Share of Common Stock	The following table sets forth the 2015, 2014 and 2013 computation of basic and diluted net income (loss) per share of common stock for the periods presented (in thousands, except per share amounts): 2015 2014 2013 Net loss $ (742,279 ) $ (21,850 ) $ (113,806 ) Basic weighted average common shares outstanding 74,932 73,798 68,260 Add: dilutive effect of non-vested restricted stock — — — Diluted weighted average common shares outstanding 74,932 73,798 68,260 Basic and diluted net loss per common share $ (9.91 ) $ (0.30 ) $ (1.67 )

Long Term Debt (Tables)

Long Term Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Long-term Debt	As of the dates indicated, the Company’s long-term debt consisted of the following (in thousands): Principal Unamortized premium/ (discount) Unamortized deferred financing costs December 31, 2015 Revolving credit facility $ — $ — $ (2,121 ) $ (2,121 ) Secured term loan facility 128,303 (7,223 ) (2,136 ) 118,944 8.50% senior notes 400,000 1,233 (5,182 ) 396,051 Total long-term debt $ 528,303 $ (5,990 ) $ (9,439 ) $ 512,874 Principal Unamortized premium/ (discount) Unamortized deferred financing costs December 31, 2014 Revolving credit facility $ 235,000 $ — $ (3,064 ) $ 231,936 Secured term loan facility 150,000 (10,500 ) (4,807 ) 134,693 8.50% senior notes 400,000 1,461 (6,654 ) 394,807 Total $ 785,000 $ (9,039 ) $ (14,525 ) $ 761,436 Current portion of secured term loan facility 1,494 Long-term debt $ 759,942 Unamortized deferred financing costs associated with the revolving credit facility at December 31, 2015, have been included in other assets. For the years ended December 31, 2015, 2014, and 2013, the Company incurred interest expense on long-term debt of $70.3 million, $46.4 million and $45.2 million, respectively. The Company capitalized $6.0 million, $14.9 million and $15.9 million of interest expense during the years ended December 31, 2015, 2014 and 2013, respectively.

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Components of Provision for Income Taxes	The following table summarizes the components of the provision for income taxes (in thousands): 2015 2014 2013 Current income tax benefit $ — $ — $ 16 Deferred income tax benefit 22,354 4,140 64,663 Total income tax benefit $ 22,354 $ 4,140 $ 64,679
Reconciliation of Provision for Income Taxes to Amount Provided by Applying Statutory United States Federal Income Tax Rate to Income Before Income Taxes	The provision for income taxes for the years ended December 31, 2015, 2014 and 2013 differs from the amount that would be provided by applying the statutory U.S. federal income tax rate of 35% to income before income taxes. This difference relates primarily to state income taxes and estimated permanent differences as follows (in thousands): 2015 2014 2013 Expected statutory income tax benefit $ 267,621 $ 9,097 $ 62,470 State income tax benefit 13,394 480 3,254 Equity compensation (4,822 ) (4,273 ) (2,031 ) Non-deductible executive compensation — (468 ) (54 ) Prior Year True Up net 4 (163 ) 12 Valuation allowance (253,592 ) — — Other (251 ) (533 ) 1,028 Total income tax benefit $ 22,354 $ 4,140 $ 64,679
Tax Effects of Temporary Differences that Give Rise to Significant Portions of Deferred Income Tax Assets and Liabilities	The tax effects of temporary differences that give rise to significant portions of the deferred income tax assets and liabilities are presented below (in thousands): December 31, 2015 2014 Deferred income tax assets (liabilities): Derivative financial instruments (35,481 ) (41,645 ) Net operating loss carryovers 183,964 97,022 Asset retirement obligation 7,118 11,596 Startup and organization costs 122 140 Deferred acquisition costs 45 45 Percentage depletion 1,360 1,341 Property and equipment costs 91,937 (95,379 ) Equity compensation 3,342 3,947 Other 1,185 579 Valuation allowance (253,592 ) — Total long term assets (liabilities) — (22,354 ) Net deferred tax asset (liability) $ — $ (22,354 )

Stockholders' Equity and Equi26

Stockholders' Equity and Equity Based Awards (Tables)	12 Months Ended
	Dec. 31, 2015
Expense Related to Incentive Plan	For the Year Ended December 31, 2015 2014 2013 Stock option awards $ 365 $ — $ — Time-based restricted stock awards 9,067 12,101 11,023 Stock appreciation awards 45 240 751 TSR awards 2,848 3,990 3,150 Time-based restricted cash awards 959 — — Performance-based restricted cash awards 225 — — Total Incentive Plan compensation expense $ 13,509 $ 16,331 $ 14,924
Unrecognized Compensation Expense and Weighted Average Period Related to Incentive Plan	As of December 31, 2015, the Company held unrecognized share-based compensation expense (in thousands) which is expected to be recognized over a weighted-average period as follows: Weighted Unrecognized Average Compensation Years Expense Remaining Stock option awards $ 5,320 2.3 Time-based restricted stock awards 1,662 0.9 TSR awards 1,326 0.8 Total unrecognized compensation expense $ 8,308
Valuation Model for Performance-Based Awards	The valuation model for the Performance-Based Awards used the following assumptions: Grant Year Average Expected Volatility Expected Dividend Yield Risk-Free Interest Rate 2013 35.0% 0% 0.42% 2014 39.4% 0% 0.69%
Stock Option Awards
Changes in Non-Vested Stock Option Awards	The following table summarizes the changes in non-vested option awards for the periods presented: 2015 Weighted Average Grant Date Shares Fair Value Non-vested, beginning of period — $ — Granted 2,043,002 0.92 Vested — — Forfeited (60,500 ) 0.97 Non-vested, end of period 1,982,502 $ 0.92
Time-based restricted stock awards
Changes in Non-Vested Awards	The following table summarizes the changes in non-vested time-based restricted stock awards for the periods presented: 2015 2014 2013 Weighted Weighted Weighted Average Average Average Grant Date Grant Date Grant Date Shares Fair Value Shares Fair Value Shares Fair Value Non-vested, beginning of period 2,497,830 $ 9.43 2,005,721 $ 10.62 1,176,890 $ 12.00 Granted 160,500 1.35 1,595,535 8.86 1,570,393 10.31 Vested (1,110,683 ) 9.56 (819,615 ) 10.87 (559,763 ) 12.47 Forfeited (118,673 ) 8.80 (283,811 ) 9.65 (181,799 ) 11.15 Non-vested, end of period 1,428,974 $ 8.42 2,497,830 $ 9.43 2,005,721 $ 10.62
Stock appreciation awards
Changes in Non-Vested Awards	The following table summarizes the changes in non-vested Stock Appreciation Awards for the periods presented: 2015 2014 2013 Weighted Weighted Weighted Average Average Average Grant Date Grant Date Grant Date Shares Fair Value Shares Fair Value Shares Fair Value Non-vested, beginning of period 266,652 $ 3.95 444,571 $ 7.60 895,892 $ 8.43 Granted — — — — — — Vested — — — — — — Forfeited (8,993 ) 3.75 (21,126 ) 7.04 (61,147 ) 7.82 Expired (257,659 ) 3.96 (156,793 ) 13.89 (390,174 ) 9.38 Non-vested, end of period — $ — 266,652 $ 3.95 444,571 $ 7.60
TSR awards
Changes in Non-Vested Awards	The following table summarized changes in non-vested TSR Awards for the periods presented: 2015 2014 2013 Weighted Weighted Weighted Average Average Average Grant Date Grant Date Grant Date Shares Fair Value Shares Fair Value Shares Fair Value Non-vested, beginning of period 764,598 $ 14.26 340,166 $ 15.91 — $ — Granted — — 487,819 13.32 354,517 15.91 Vested — — (63,387 ) 15.91 — — Forfeited — — — — (14,351 ) 15.91 Non-vested, end of period 764,598 $ 14.26 764,598 $ 14.26 340,166 $ 15.91

Asset Retirement Obligation (Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Reconciliation of Asset Retirement Obligations	The following table provides a reconciliation of Resolute’s asset retirement obligations for the periods presented (in thousands): December 31, 2015 2014 Asset retirement obligations at beginning of period $ 31,340 $ 31,989 Additional liability incurred / acquired 96 144 Accretion expense 2,740 2,576 Liabilities settled (15,177 ) (1,282 ) Revisions to previous estimates 239 (2,087 ) Asset retirement obligations at end of period 19,238 31,340 Less: current asset retirement obligations (891 ) (327 ) Long-term asset retirement obligations $ 18,347 $ 31,013

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2015
Derivative [Line Items]
Summary of Subsequent Additional Commodity Derivative Contracts	Subsequent to December 31, 2015, Resolute entered into additional commodity derivative contracts as summarized below: Oil (NYMEX WTI) Gas (NYMEX Henry Hub) Commodity Swap Bbl per Day Weighted MMBtu per Day Weighted Average Swap Price per MMBtu Apr - June 2016 — — 4,600 $ 1.805 Jan - Dec 2017 1,000 $ 49.00 — — Jan - Mar 2017 — — 1,600 $ 2.488 Apr - June 2017 — — 1,700 $ 2.327 Gas (NYMEX Henry Hub) Two -Way Collar MMBtu per Day Weighted Average Floor Price per MMBtu Weighted Average Ceiling Price per MMBtu July - Sept 2017 3,250 $ 2.25 $ 2.53 Oct - Dec 2017 3,250 $ 2.25 $ 2.75 Oil (NYMEX WTI) Oil Call Contract Bbl per Day Sold Call Price Jan - Dec 2018 1,100 $ 50.00
Amount of Commodity Derivative Instrument Gains (Losses)	The table below summarizes the location and amount of commodity derivative instrument gains and losses reported in the consolidated statements of income (in thousands): 2015 2014 2013 Other income (expense): Commodity derivative settlements $ 93,150 $ (4,988 ) $ (35,812 ) Mark-to-market gain (16,658 ) 123,129 20,476 Commodity derivative instruments gain (loss) $ 76,492 $ 118,141 $ (15,336 )
Commodity Swap Contracts
Derivative [Line Items]
Commodity Contracts and Swaps	The following table represents Resolute’s commodity swap contracts as of December 31, 2015: Oil (NYMEX WTI) Gas (NYMEX Henry Hub) Remaining Term Bbl per Day Weighted MMBtu per Day Weighted Average Swap Price per MMBtu Jan – Dec 2016 6,500 $ 80.42 — $ — July – Dec 2016 75 $ 52.75 5,100 $ 2.975 Jan – June 2017 65 $ 54.75 2,400 $ 3.083
Three-Way Oil Collar
Derivative [Line Items]
Commodity Contracts and Swaps	The following table represents Resolute’s three-way oil collar contracts as of December 31, 2015: Oil (NYMEX WTI) Weighted Average Weighted Average Weighted Average Remaining Term Bbl per Day Short Put Price per Bbl Floor Price per Bbl Ceiling Price per Bbl Jan – Dec 2017 1,000 $ 45.00 $ 60.00 $ 71.73

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Assets and Liabilities Required to be Measured at Fair Value on Recurring Basis	The following is a listing of Resolute’s commodity derivative assets and liabilities required to be measured at fair value on a recurring basis and where they are classified within the hierarchy as of December 31, 2015, and December 31, 2014 (in thousands): Level 2 December 31, 2015 December 31, 2014 Assets Derivative instruments, current $ 92,431 $ 72,753 Derivative instruments, long term 3,463 39,799 Total assets $ 95,894 $ 112,552

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2015
Commitments And Contingencies Disclosure [Abstract]
Future minimum CO2 purchase commitments	Future minimum CO 2 CO 2 Year Commitments 2016 12,078 2017 546 Total $ 12,624
Schedule of Future Payment Operating Leases Agreements	Future payments for the Company’s office facilities, equipment leases and vehicle leases under these operating lease agreements, as of December 31, 2015, are as follows (in thousands): Year Office Lease Rentals Field Equipment Rentals Vehicle Lease Rentals Total 2016 $ 1,832 $ 4,782 $ 766 $ 7,380 2017 1,699 1,275 346 3,320 2018 1,560 — 107 1,667 2019 and thereafter 4,390 — 10 4,400 Total $ 9,481 $ 6,057 $ 1,229 $ 16,767

Supplemental Oil and Gas Info31

Supplemental Oil and Gas Information (Tables)	12 Months Ended
	Dec. 31, 2015
Extractive Industries [Abstract]
Costs Incurred in Oil and Gas Property Acquisition Exploration and Development Activities	Costs incurred during 2015, 2014 and 2013 related to oil and gas property acquisition, exploration and development activities, including the fair value of oil and gas properties acquired are summarized as follows (in thousands): 2015 2014 2013 Acquisition costs Proved $ — $ — $ 155,958 Unproved 6,583 7,007 121,362 Exploration costs 13,764 111,769 150,072 Development costs* 39,883 50,291 97,308 Total $ 60,230 $ 169,067 $ 524,700 * Includes $8.9 million, $16.3 million and $20.0 million of acquired CO 2 .
Net Capitalized Costs Related to Resolute's Oil and Gas Producing Activities	Net capitalized costs related to Resolute’s oil and gas producing activities at December 31, 2015 and December 31, 2014 were as follows (in thousands): 2015 2014 Proved oil and gas properties $ 1,732,707 $ 1,706,847 Unevaluated oil and gas properties, not subject to amortization 21,264 270,375 Accumulated depletion, depreciation and amortization (1,534,479 ) (738,979 ) Oil and gas properties, net $ 219,492 $ 1,238,243
Changes in Estimated Reserves	Presented below is a summary of the changes in estimated reserves (in thousands): Oil Equivalent Oil (Bbl) Gas (MMcf) NGL (Bbl) (Boe) (1) Proved reserves as of January 1, 2013 62,557 47,721 8,264 78,774 Purchase of minerals in place 4,592 10,821 1,422 7,818 Production (3,499 ) (4,565 ) (207 ) (4,467 ) Extensions, discoveries and other additions (2) 4,038 6,128 746 5,805 Sales of minerals in place (5,124 ) (3,379 ) (219 ) (5,906 ) Revisions of previous estimates (3) (15,053 ) (14,337 ) (5,189 ) (22,630 ) Proved reserves as of December 31, 2013 47,511 42,389 4,817 59,394 Purchase of minerals in place — — — — Production (3,489 ) (6,942 ) — (4,647 ) Extensions, discoveries and other additions (2) 25,756 10,128 1,357 28,800 Sales of minerals in place (215 ) (26 ) (5 ) (224 ) Revisions of previous estimates (5,848 ) (8,751 ) (1,799 ) (9,105 ) Proved reserves as of December 31, 2014 63,715 36,798 4,370 74,218 Purchase of minerals in place — — — — Production (3,270 ) (5,193 ) (400 ) (4,535 ) Extensions, discoveries and other additions (2) 1,965 8,208 1,269 4,602 Sales of minerals in place (5,289 ) (23,674 ) (2,837 ) (12,072 ) Revisions of previous estimates (28,373 ) (2,279 ) (341 ) (29,093 ) Proved reserves as of December 31, 2015 28,748 13,860 2,061 33,120 Proved developed reserves: As of December 31, 2015 25,672 7,098 1,019 27,874 As of December 31, 2014 34,359 25,775 2,791 41,446 As of December 31, 2013 38,791 29,488 3,136 46,842 Proved undeveloped reserves: As of December 31, 2015 3,076 6,761 1,043 5,246 As of December 31, 2014 29,356 11,023 1,579 32,772 As of December 31, 2013 8,720 12,901 1,681 12,552 1) 2) Extensions, discoveries and other additions in 2015 are associated with the Permian drilling program in Reeves County resulting in 576 MBoe added to proved developed producing reserves from drilling proved locations, and 970 MBoe from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 3,632 MBoe reserves. Extensions, discoveries and other additions in 2014 were primarily associated with reinstatement of CO2 enhanced recovery projects that were removed for year-end 2013 reporting to comply with the SEC five-year rule pertaining to undeveloped reserves. Approximately 21.1 MMBoe had been reinstated as proved undeveloped all comprised of four named CO2 injection projects identified in the Aneth Field Properties: 8.9 MMBoe for Aneth Unit Phase 4 CO2 injection, 3.0 MMBoe for McElmo Unit DCIIC CO2 injection, 4.9 MMBoe for Ratherford DCIA CO2 injection and 4.3 MMBoe for Ratherford DCIIC CO2 injection. Additionally, the Permian Basin and Powder River Basin properties held active drilling programs in 2014 resulting in 1.7 MMBoe added to proved developed producing from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 6.0 MMBoe reserves. 3) Decreases in proved reserves associated with revisions of previous estimates resulted primarily from reduced product pricing. Deferral of the Aneth CO 2
Future Net Cash Flows Relating to Proved Oil and Gas Reserves	The following summary sets forth Resolute’s future net cash flows relating to proved oil and gas reserves based on the standardized measure prescribed by FASB ASC Topic 932: December 31, 2015 2014 2013 (in thousands) Future cash inflows $ 1,293,000 $ 5,858,000 $ 4,647,000 Future production costs (774,000 ) (2,719,000 ) (2,050,000 ) Future development costs (180,000 ) (1,008,000 ) (547,000 ) Future income taxes — (412,000 ) (398,000 ) Future net cash flows 339,000 1,719,000 1,652,000 10% annual discount for estimated timing of cash flows (140,000 ) (886,000 ) (759,000 ) Standardized measure of discounted future net cash flows $ 199,000 $ 833,000 $ 893,000
Principal Sources of Change in Standardized Measure of Discounted Future Net Cash Flows	The principal sources of change in the standardized measure of discounted future net cash flows are: December 31, 2015 2014 2013 (in thousands) Standardized measure, beginning of year $ 833,000 $ 893,000 $ 872,000 Sales of oil and gas produced, net of production costs (181,000 ) (196,000 ) (206,000 ) Net changes in prices and production costs (917,000 ) (191,000 ) 61,000 Purchases of minerals in place — — 106,000 Sales of minerals in place (134,000 ) (6,000 ) (84,000 ) Previously estimated development costs incurred during the year 33,000 49,000 89,000 Extensions, discoveries and improved recovery 13,000 207,000 111,000 Changes in estimated future development costs 119,000 (13,000 ) (64,000 ) Revisions of previous quantity estimates 196,000 (16,000 ) (203,000 ) Accretion of discount 70,000 89,000 79,000 Net change in income taxes 104,000 44,000 67,000 Changes in timing and other 63,000 (27,000 ) 65,000 Standardized measure, end of year $ 199,000 $ 833,000 $ 893,000

Quarterly Financial Data (Table

Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Schedule of Quarterly Financial Data	The following is a summary of the unaudited financial data for each quarter for the years ended December 31, 2015 and 2014 (in thousands except per share data): Three Months Ended March 31, June 30, September 30, December 31, 2015 2015 2015 2015 Year Ended December 31, 2015 Revenue $ 41,133 $ 48,396 $ 36,617 $ 28,498 Operating expenses (285,469 ) (270,291 ) (253,484 ) (122,104 ) Income (loss) from operations (244,336 ) (221,895 ) (216,867 ) (93,606 ) Net income (loss) (208,222 ) (259,107 ) (182,770 ) (92,180 ) Earnings (loss) per common share: Basic $ (2.80 ) $ (3.46 ) $ (2.44 ) $ (1.23 ) Diluted $ (2.80 ) $ (3.46 ) $ (2.44 ) $ (1.23 ) Weighted average common shares outstanding: Basic 74,284 74,826 74,857 74,897 Diluted 74,284 74,826 74,857 74,897 Three Months Ended March 31, June 30, September 30, December 31, 2014 2014 2014 2014 Year Ended December 31, 2014: Revenue $ 90,878 $ 88,459 $ 84,102 $ 65,932 Operating expenses (79,803 ) (81,527 ) (81,384 ) (199,331 ) Income (loss) from operations 11,075 6,932 2,718 (133,399 ) Net income (loss) (3,548 ) (16,120 ) 14,966 (17,148 ) Earnings (loss) per common share: Basic $ (0.05 ) $ (0.22 ) $ 0.20 $ (0.23 ) Diluted $ (0.05 ) $ (0.22 ) $ 0.20 $ (0.23 ) Weighted average common shares outstanding: Basic 73,540 73,843 73,886 73,917 Diluted 73,540 73,843 74,050 73,917

Basis of Presentation and Sum33

Basis of Presentation and Summary of Significant Accounting Policies - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2015USD ($)Segment	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)	Apr. 30, 2012USD ($)
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Long term debt, principal	$ 528,303,000	$ 785,000,000
Number of Operating Segments | Segment	1
Allowance for doubtful accounts	$ 0	0
Deferred financing cost	0	4,800,000	$ 1,900,000
Deferred financing cost amortization interest expense	5,000,000	2,500,000	2,700,000
Capitalized Interest	6,000,000	14,900,000	15,900,000
Capitalized general and administrative and operating costs	$ 6,300,000	$ 9,800,000	$ 8,400,000
Unproved properties, evaluation time for existence of proved reserves	3 years
Discount factor	10.00%	10.00%	10.00%
Impairment of proved oil and gas properties	$ 705,000,000	$ 120,000,000	$ 188,000,000
Provisions for impairment of long-lived assets other than oil and gas properties	0	0	$ 0
Restricted cash	$ 21,500,000
New accounting pronouncement, reclassification of other assets to deferred income taxes		$ 900,000
Future Net Revenue from Proved Oil and Gas Reserves
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Discount factor	10.00%
Office furniture, automobiles, and computer hardware and software | Minimum
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Property and equipment estimated useful life	3 years
Office furniture, automobiles, and computer hardware and software | Maximum
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Property and equipment estimated useful life	5 years
Field offices and partial ownership of aircraft | Minimum
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Property and equipment estimated useful life	15 years
Field offices and partial ownership of aircraft | Maximum
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Property and equipment estimated useful life	20 years
Revenue | Western Refining, Inc. | Customer Concentration Risk
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Concentration of credit risk percentage	58.00%	62.00%	61.00%
Revenue | Holly Frontier LLC | Customer Concentration Risk
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Concentration of credit risk percentage	14.00%
Revenue | Plains Marketing LP | Customer Concentration Risk
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Concentration of credit risk percentage		14.00%	15.00%
Senior Notes
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Long term debt, principal	$ 400,000,000			$ 150,000,000	$ 250,000,000
Senior notes, maturity	May 1, 2020
Term Loan Facility | Second Lien
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Senior notes, maturity	Mar. 31, 2018
Long-term debt, fair value	$ 128,300,000

Accounts Receivable (Detail)

Accounts Receivable (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Receivables [Abstract]
Trade receivables	$ 14,224	$ 23,240
Revenue receivables	12,967	27,926
Derivative receivables	9,759	6,638
Other receivables	150	105
Total accounts receivable	$ 37,100	$ 57,909

Acquisitions and Divestitures -

Acquisitions and Divestitures - Additional Information (Detail) - USD ($) $ in Thousands	Mar. 22, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2012	Nov. 30, 2015	Oct. 31, 2015	May. 31, 2015	Jun. 30, 2013
Business Disposition [Line items]
Asset Retirement Obligation Liabilities Settled		$ 15,177	$ 1,282
Purchase agreement, purchase price of properties	$ 258,000
Purchase agreement, option fee to buy the balance of the working interest and field and operations				$ 6,000
Wolfberry Play Midland Basin Permian Basin Midland And Ector Counties TX
Business Disposition [Line items]
Purchase agreement, purchase price of properties				$ 133,000
Gardendale Properties
Business Disposition [Line items]
Sale of properties					$ 177,500
Purchase and sale agreement, effective date		Sep. 1, 2015
Transaction date		Dec. 22, 2015
Asset Retirement Obligation Liabilities Settled		$ 5,600
Hilight Field
Business Disposition [Line items]
Sale of properties						$ 55,000
Purchase and sale agreement, effective date		Jul. 1, 2015
Transaction date		Oct. 6, 2015
Asset Retirement Obligation Liabilities Settled		$ 8,100
Howard and Martin County
Business Disposition [Line items]
Sale of properties							$ 42,000
Purchase and sale agreement, effective date		Mar. 1, 2015
Transaction date		May 1, 2015
Asset Retirement Obligation Liabilities Settled		$ 1,300
Purchase and sales agreement with Halcón Resources Corporation
Business Disposition [Line items]
Sale of properties								$ 70,100
Purchase and sale agreement, effective date		Mar. 1, 2013
Transaction date		Jul. 15, 2013

Unaudited Pro Forma Financial I

Unaudited Pro Forma Financial Information on Properties Sold (Detail) - Gardendale, Hilight Field, Howard and Martin County Properties $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)$ / shares
Business Acquisition [Line Items]
Total revenue	$ 123,830
Loss from operations	(775,872)
Net loss	$ (730,381)
Basic and diluted net loss per common share | $ / shares	$ (9.75)

Final Purchase Price Allocation

Final Purchase Price Allocation of Permian Acquisitions (Detail) - Permian Properties $ in Thousands	Dec. 31, 2013USD ($)
Business Acquisition [Line Items]
Asset retirement obligations assumed	$ (2,000)
Total purchase price	258,000
Proved oil and gas properties
Business Acquisition [Line Items]
Oil and gas properties	93,000
Unproved oil and gas properties
Business Acquisition [Line Items]
Oil and gas properties	$ 167,000

Unaudited Pro Forma Financial38

Unaudited Pro Forma Financial Information (Detail) - Permian Properties $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2013USD ($)$ / shares
Business Acquisition [Line Items]
Revenue	$ 360,837
Revenue in excess of operating expenses	215,273
Net income (loss)	$ (111,243)
Basic and diluted net income (loss) per share | $ / shares	$ (1.63)

Weighted Average Dilutive and A

Weighted Average Dilutive and Anti-Dilutive Securities (Detail) - shares shares in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Earnings Per Share [Abstract]
Potential dilutive restricted stock	1,779	2,973	2,529
Anti-dilutive securities	4,901	27,523	35,569

Computation of Basic and Dilute

Computation of Basic and Diluted Net Income (Loss) Per Share of Common Stock (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Earnings Per Share Diluted [Line Items]
Net loss	$ (92,180)	$ (182,770)	$ (259,107)	$ (208,222)	$ (17,148)	$ 14,966	$ (16,120)	$ (3,548)	$ (742,279)	$ (21,850)	$ (113,806)
Basic weighted average common shares outstanding	74,897	74,857	74,826	74,284	73,917	73,886	73,843	73,540	74,932	73,798	68,260
Diluted weighted average common shares outstanding	74,897	74,857	74,826	74,284	73,917	74,050	73,843	73,540	74,932	73,798	68,260
Basic and diluted net loss per common share									$ (9.91)	$ (0.30)	$ (1.67)

Long-term Debt (Detail)

Long-term Debt (Detail) - USD ($)	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Principal	$ 528,303,000	$ 785,000,000
Unamortized premium/ (discount)	(5,990,000)	(9,039,000)
Unamortized deferred financing costs	(9,439,000)	(14,525,000)
Total long-term debt	512,874,000	761,436,000
Current portion of secured term loan facility	0	1,494,000
Long-term debt		759,942,000
Revolving credit facility
Debt Instrument [Line Items]
Principal		235,000,000
Unamortized deferred financing costs	(2,121,000)	(3,064,000)
Total long-term debt	(2,121,000)	231,936,000
Secured term loan facility
Debt Instrument [Line Items]
Principal	128,303,000	150,000,000
Unamortized premium/ (discount)	(7,223,000)	(10,500,000)
Unamortized deferred financing costs	(2,136,000)	(4,807,000)
Total long-term debt	118,944,000	134,693,000
8.50% senior notes
Debt Instrument [Line Items]
Principal	400,000,000	400,000,000
Unamortized premium/ (discount)	1,233,000	1,461,000
Unamortized deferred financing costs	(5,182,000)	(6,654,000)
Total long-term debt	$ 396,051,000	$ 394,807,000

Long-term Debt (Parenthetical)

Long-term Debt (Parenthetical) (Detail)	Dec. 31, 2015	Dec. 31, 2014
8.50% senior notes
Debt Instrument [Line Items]
Debt instrument, interest rate	8.50%	8.50%

Long Term Debt - Additional Inf

Long Term Debt - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Debt Disclosure [Abstract]
Interest Expense on Long-term debt	$ 70.3	$ 46.4	$ 45.2
Interest expense capitalized	$ 6	$ 14.9	$ 15.9

Long Term Debt - Revolving Cred

Long Term Debt - Revolving Credit Facility - Additional Information (Detail) - USD ($)	Apr. 15, 2015	Dec. 31, 2015	Oct. 31, 2015	May. 31, 2015	Dec. 31, 2014	Apr. 30, 2012	Dec. 31, 2015	Mar. 07, 2014
Debt Instrument [Line Items]
Line of credit, borrowing base		$ 145,000,000		$ 260,000,000			$ 145,000,000
Borrowing base reduced							$ 3,100,000
Additional borrowings under term loan facility				50,000,000
Revolving credit facility, borrowing base reduced				$ 10,000,000
Borrowing base adjustment period							120 days
Federal Funds Effective Swap Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						0.50%
Option A | London Interbank Offered Rate (LIBOR) | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						1.50%
Option A | London Interbank Offered Rate (LIBOR) | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						2.50%
Powder River Basin Properties
Debt Instrument [Line Items]
Line of credit, borrowing base			$ 165,000,000
Revolving credit facility, borrowing base reduced			$ 15,000,000
Gardendale Sale
Debt Instrument [Line Items]
Line of credit, borrowing base		145,000,000					$ 145,000,000
Revolving credit facility, borrowing base reduced		20,000,000
Revolving Credit Facility and Secured Term Loan Facility
Debt Instrument [Line Items]
Secured debt to EBITDA ratio maximum					350.00%		350.00%
Proved reserves to secured debt ratio, minimum					110.00%		110.00%
Proved reserves to secured debt ratio, minimum for quarter ending on or after December 31, 2015					150.00%		150.00%
Proved developed reserves to secured debt ratio, minimum					100.00%		100.00%
Revolving Credit Facility covenant description							The covenants require, among other things, maintenance of certain ratios, measured on a quarterly basis, as follows: (i) secured debt to EBITDA of no more than 3.5 to 1.0, (ii) PV-10 of total proved reserves to total secured debt of at least 1.1 to 1.0, rising over time to 1.5 to 1.0 for any fiscal quarter ending on or after December 31, 2015, and (iii) PV-10 of proved developed reserves to total secured debt of at least 1.0 to 1.0. Our Revolving Credit Facility and our Secured Term Loan Facility also require us to enter into derivative agreements covering at least 70% of our anticipated production from proved developed producing properties on a rolling twenty four month basis, but prohibit us from entering into derivative arrangements for more than (i) 85% of our anticipated production from proved properties in the subsequent two years and (ii) the greater of 75% of our anticipated production from proved properties or 85% of our production from projected proved developed producing properties after such two year period, using economic parameters specified in our Revolving Credit Facility
Derivative agreement, percentage of anticipated production from proved properties, minimum					70.00%
Derivative agreement, percentage of anticipated production from proved properties, maximum					85.00%
Derivative agreement, percentage of anticipated production from proved properties					75.00%
Derivative agreement, percentage of projected proved developed producing reserves					85.00%
Anticipated production from proved properties period					2 years
Sixth Amendment
Debt Instrument [Line Items]
Revolving credit facility, maturity date							Mar. 31, 2018
Ninth Amendment | Fiscal quarter ending March 31, 2014
Debt Instrument [Line Items]
Maximum Leverage Ratio								490.00%
Ninth Amendment | Fiscal quarters ending June 30, 2014
Debt Instrument [Line Items]
Maximum Leverage Ratio								490.00%
Ninth Amendment | Fiscal quarters ending September 30, 2014
Debt Instrument [Line Items]
Maximum Leverage Ratio								475.00%
Ninth Amendment | Fiscal quarters ending December 31, 2014
Debt Instrument [Line Items]
Maximum Leverage Ratio								475.00%
Ninth Amendment | All quarters thereafter
Debt Instrument [Line Items]
Maximum Leverage Ratio								400.00%
Ninth Amendment | Last day of each fiscal quarter in 2014
Debt Instrument [Line Items]
Maximum Leverage Ratio								275.00%
Revolving credit facility
Debt Instrument [Line Items]
Line of credit, borrowing base	$ 275,000,000
Borrowing base reduced	$ 5,000,000
Percentage of additional principal loan amount reduction to borrowing base	20.00%
Claw back provision previously in effect	90.00%
Outstanding borrowings		$ 0					$ 0
Revolving credit facility interest rate terms							The London Interbank Offered Rate (“LIBOR”), plus a margin which varies from 1.50% to 2.50% or (b) the alternative Base Rate defined as the greater of (i) the Administrative Agent’s Prime Rate (ii) the Federal Funds effective Rate plus 0.5% or (iii) an adjusted London Interbank Offered Rate plus a margin which ranges from 0.50% to 1.50%.
Revolving credit facility | Twelfth Amendment
Debt Instrument [Line Items]
First lien leverage ratio	200.00%
Secured term loan facility
Debt Instrument [Line Items]
Potential additional secured term loan	$ 50,000,000
Maximum of second lien debt before step down of maximum first lien leverage ratio	$ 200,000,000
Option B, Option 3 | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						0.50%
Option B, Option 3 | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate						1.50%

Long Term Debt - Secured Term L

Long Term Debt - Secured Term Loan Agreement - Additional Information (Detail) - USD ($) $ in Thousands	1 Months Ended	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	May. 18, 2015
Debt Instrument [Line Items]
Outstanding borrowings under term loan facility	$ 150,000		$ 150,000
Proceeds from issuance of term loans after payment of transaction-related fees, expenses and discounts			135,000
Expiration period of term loan after credit facility expiration		6 months
Proceeds from issuance of term loans		$ 46,500	$ 139,500	$ 0
Percentage of mandatory net cash flow from sale of assets for prepayment of term loan with out premium		75.00%
Percentage of mandatory net cash flow from sale of securities for prepayment of term loan with premium		100.00%
Term loan prepayment period from closing date		36 months
Minimum debt ratio to invested capital for repayment of term loan		125.00%
Repayment of secured term loan with proceeds		$ 70,000
Revolving Credit Facility and Secured Term Loan Facility
Debt Instrument [Line Items]
Secured debt to EBITDA ratio maximum	350.00%	350.00%
Proved reserves to secured debt ratio, minimum	110.00%	110.00%
Proved reserves to secured debt ratio, minimum for quarter ending on or after December 31, 2015	150.00%	150.00%
Proved developed reserves to secured debt ratio, minimum	100.00%	100.00%
Secured Term Loan Agreement
Debt Instrument [Line Items]
Fixed interest rate on team loan facility		10.00%
Description of variable rate basis		Secured Term Loan Facility will generally bear interest at adjusted LIBOR plus 10%, with a 1% LIBOR floor.
Secured Term Loan Agreement | Fair Value, Inputs, Level 3
Debt Instrument [Line Items]
Long-term debt, fair value		$ 121,100
Secured Term Loan Agreement | Maximum
Debt Instrument [Line Items]
Percentage of Premium on prepayment of term loan		10.00%
Secured Term Loan Agreement | Minimum
Debt Instrument [Line Items]
Percentage of Premium on prepayment of term loan		2.00%
Secured Term Loan Agreement | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument floor rate		1.00%
Secured Term Loan Agreement | Incremental Term Loan
Debt Instrument [Line Items]
Outstanding borrowings under term loan facility					$ 50,000
Proceeds from issuance of term loans		$ 46,000

Long Term Debt - Senior Notes -

Long Term Debt - Senior Notes - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2012	Apr. 30, 2012
Debt Instrument [Line Items]
Principal amount	$ 528,303,000	$ 785,000,000
Senior Notes, redemption date	May 1, 2016
Maximum
Debt Instrument [Line Items]
Senior Notes, redemption notice period	60 days
Debt Instrument Redemption Period One
Debt Instrument [Line Items]
Senior Notes, redemption price percentage of principal	100.00%
Senior Notes
Debt Instrument [Line Items]
Principal amount	$ 400,000,000		$ 150,000,000	$ 250,000,000
Senior notes, due date	May 1, 2020
Debt instrument, interest rate	8.50%
Senior Notes, redemption price percentage of principal	101.00%
Senior Notes | Level 2
Debt Instrument [Line Items]
Long-term debt, fair value	$ 177,900,000
Senior Notes | Minimum
Debt Instrument [Line Items]
Senior Notes, redemption notice period	30 days

Components of Provision for Inc

Components of Provision for Income Taxes (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Current income tax benefit			$ 16
Deferred income tax benefit	$ 22,354	$ 4,140	64,663
Total income tax benefit	$ 22,354	$ 4,140	$ 64,679

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Taxes [Line Items]
U.S. federal income tax rate	35.00%	35.00%	35.00%
U.S. net operating loss carryforwards	$ 505,000,000
U.S. net operating loss carryforwards, beginning of expiration date	2,026
Deferred tax assets, valuation allowance	$ 253,592,000
Unrecognized tax benefits	0	$ 0	$ 0
Accrued interest or penalties related to uncertain tax positions	$ 0	$ 0	$ 0
Earliest Tax Year | Internal Revenue Service
Income Taxes [Line Items]
Tax years open to examination	2,011
Earliest Tax Year | State Taxing Authorities
Income Taxes [Line Items]
Tax years open to examination	2,010
Latest Tax Year | Internal Revenue Service
Income Taxes [Line Items]
Tax years open to examination	2,015
Latest Tax Year | State Taxing Authorities
Income Taxes [Line Items]
Tax years open to examination	2,015

Reconciliation of Provision for

Reconciliation of Provision for Income Taxes to Amount Provided by Applying Statutory United States Federal Income Tax Rate to Income Before Income Taxes (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Expected statutory income tax benefit	$ 267,621	$ 9,097	$ 62,470
State income tax benefit	13,394	480	3,254
Equity compensation	(4,822)	(4,273)	(2,031)
Non-deductible executive compensation		(468)	(54)
Prior Year True Up net	4	(163)	12
Valuation allowance	(253,592)
Other	(251)	(533)	1,028
Total income tax benefit	$ 22,354	$ 4,140	$ 64,679

Tax Effects of Temporary Differ

Tax Effects of Temporary Differences that Give Rise to Significant Portions of Deferred Income Tax Assets and Liabilities (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Deferred income tax assets (liabilities):
Derivative financial instruments	$ (35,481)	$ (41,645)
Net operating loss carryovers	183,964	97,022
Asset retirement obligation	7,118	11,596
Startup and organization costs	122	140
Deferred acquisition costs	45	45
Percentage depletion	1,360	1,341
Property and equipment costs, assets	91,937
Equity compensation	3,342	3,947
Other	1,185	579
Valuation allowance	(253,592)
Property and equipment costs, liabilities		(95,379)
Total long term liabilities	$ 0	(22,354)
Net deferred tax liability		$ (22,354)

Stockholders' Equity and Equi51

Stockholders' Equity and Equity Based Awards - Preferred Stock - Additional Information (Detail) - $ / shares	Dec. 31, 2015	Dec. 31, 2014
Equity [Abstract]
Preferred stock, shares authorized	1,000,000	1,000,000
Preferred stock, par value	$ 0.0001	$ 0.0001
Preferred stock, issued	0	0
Preferred stock, outstanding	0	0

Stockholders' Equity and Equi52

Stockholders' Equity and Equity Based Awards - Common Stock - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	Nov. 30, 2015	Jun. 30, 2013	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012	Jul. 31, 2015
Class Of Stock [Line Items]
Common stock, shares authorized			225,000,000	225,000,000
Common stock, shares issued			77,210,735	77,634,737
Common stock, shares outstanding			77,210,735	77,634,737
Number of votes per share of common stock			One vote for each share of common stock
Issuance of stock, net of underwriters discounts and commissions (in shares)		13,300,000
Issuance of common stock, price per share		$ 8
Proceeds from issuance of common stock, net of underwriters discounts and commissions		$ 101,800	$ 0	$ 0	$ 101,760
Warrants repurchased			0	0	0
Warrants Exercised			0	0		0
Warrants outstanding, shares				0
Common stock trading price below minimum price requirement of stock exchange			$ 1				$ 1
Trading price of common stock back up as per listing standard			$ 1
Average market capitalization below listing standard	$ 50,000
Number of trading days	30 days
Continued listing Period	18 months
Average market capitalization above listing standard			$ 50,000
Maximum
Class Of Stock [Line Items]
Average market capitalization below listing standard	$ 50,000

Stockholders' Equity and Equi53

Stockholders' Equity and Equity Based Awards - Long-Term Employee Incentive Plan - Additional Information (Detail)	Sep. 14, 2015Installment$ / shares	Jun. 08, 2015shares	May. 05, 2015USD ($)Installment$ / shares	Feb. 29, 2016USD ($)Installment$ / sharesshares	Dec. 31, 2015$ / shares
Stock Option Awards
Class Of Stock [Line Items]
Option exercise price | $ / shares					$ 1.28
Options granted, term					10 years
Vesting period					3 years
Time-based restricted cash awards
Class Of Stock [Line Items]
Vesting period					3 years
Time-based restricted cash awards | Non-Employee Directors
Class Of Stock [Line Items]
Vesting period					1 year
Performance-based restricted cash awards
Class Of Stock [Line Items]
Options granted, term					10 years
Vesting period					3 years
Long-term Employee Incentive Plan
Class Of Stock [Line Items]
Maximum number of shares of common stock to be issued under the Incentive Plan		12,257,744
Additional number of shares of common stock to be issued under the Incentive Plan		3,100,000
Number of installment for equity awards | Installment	3
Option exercise price | $ / shares	$ 0.42
Vesting period	10 years
Long-term Employee Incentive Plan | Stock Option Awards
Class Of Stock [Line Items]
Number of installment for equity awards | Installment			3
Option exercise price | $ / shares			$ 1.35
Options granted, term			10 years
Long-term Employee Incentive Plan | Stock Option Awards | Subsequent Event
Class Of Stock [Line Items]
Number of installment for equity awards | Installment				3
Vesting period				10 years
Options to purchase				3,700,000
Long-term Employee Incentive Plan | Stock Option Awards | Subsequent Event | Employees
Class Of Stock [Line Items]
Option exercise price | $ / shares				$ 0.53
Options to purchase				1,669,606
Long-term Employee Incentive Plan | Stock Option Awards | Subsequent Event | Non-Employee Directors
Class Of Stock [Line Items]
Option exercise price | $ / shares				$ 0.583
Options to purchase				2,030,394
Long-term Employee Incentive Plan | Time-based restricted cash awards
Class Of Stock [Line Items]
Unrecognized Compensation Expense | $			$ 5,200,000
Vesting period			3 years
Long-term Employee Incentive Plan | Time-based restricted cash awards | Subsequent Event
Class Of Stock [Line Items]
Number of installment for equity awards | Installment				3
Unrecognized Compensation Expense | $				$ 5,310,000
Long-term Employee Incentive Plan | Performance-based restricted cash awards
Class Of Stock [Line Items]
Unrecognized Compensation Expense | $			$ 2,900,000
Long-term Employee Incentive Plan | Cash-Settled Stock Appreciation Rights | Subsequent Event
Class Of Stock [Line Items]
Number of installment for equity awards | Installment				3
Vesting period				10 years
Number of shares cash-settled stock appreciation rights				8,514,381
Long-term Employee Incentive Plan | Cash-Settled Stock Appreciation Rights | Subsequent Event | Employees
Class Of Stock [Line Items]
Number of shares cash-settled stock appreciation rights				2,431,964
Cash-settled stock appreciation rights, base price | $ / shares				$ 0.53
Long-term Employee Incentive Plan | Cash-Settled Stock Appreciation Rights | Subsequent Event | Non-Employee Directors
Class Of Stock [Line Items]
Number of shares cash-settled stock appreciation rights				6,082,417
Cash-settled stock appreciation rights, base price | $ / shares				$ 0.583
Long-term Employee Incentive Plan | Non-vested restricted stock | Subsequent Event
Class Of Stock [Line Items]
Number of shares expected to vest				225,748

Expense Related to Incentive Pl

Expense Related to Incentive Plan (Detail) - Long-term Employee Incentive Plan - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Class Of Stock [Line Items]
Incentive Plan compensation expense	$ 13,509	$ 16,331	$ 14,924
Stock Option Awards
Class Of Stock [Line Items]
Incentive Plan compensation expense	365
Time-based restricted stock awards
Class Of Stock [Line Items]
Incentive Plan compensation expense	9,067	12,101	11,023
Stock appreciation awards
Class Of Stock [Line Items]
Incentive Plan compensation expense	45	240	751
TSR awards
Class Of Stock [Line Items]
Incentive Plan compensation expense	2,848	$ 3,990	$ 3,150
Time-based restricted cash awards
Class Of Stock [Line Items]
Incentive Plan compensation expense	959
Performance-based restricted cash awards
Class Of Stock [Line Items]
Incentive Plan compensation expense	$ 225

Unrecognized Compensation Expen

Unrecognized Compensation Expense and Weighted Average Period Related to Incentive Plan (Detail) - Long-term Employee Incentive Plan $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 8,308
Stock Option Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 5,320
Weighted Average Years Remaining	2 years 3 months 18 days
Time-based restricted stock awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 1,662
Weighted Average Years Remaining	10 months 24 days
TSR awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 1,326
Weighted Average Years Remaining	9 months 18 days

Stockholders' Equity and Equi56

Stockholders' Equity and Equity Based Awards - Equity Awards - Additional Information (Detail)	Nov. 30, 2015	May. 05, 2015	Dec. 31, 2015$ / sharesshares	Dec. 31, 2014InstallmentEntityshares	Dec. 31, 2013shares
Class Of Stock [Line Items]
Number of trading days	30 days
Stock Option Awards
Class Of Stock [Line Items]
Vesting period			3 years
Options granted, term			10 years
Estimated forfeiture rates		10.00%
Dividend yield			0.00%
Expected stock price volatility, minimum			63.00%
Expected stock price volatility, maximum			67.00%
Risk free rate, minimum			2.06%
Risk free rate, maximum			2.27%
Shares granted			2,043,002
Option exercise price | $ / shares			$ 1.28
Time-based restricted stock awards
Class Of Stock [Line Items]
Shares granted			160,500	1,595,535	1,570,393
Time-based restricted stock awards | Non-Employee Directors
Class Of Stock [Line Items]
Vesting period			1 year
Time-based restricted stock awards | Minimum
Class Of Stock [Line Items]
Vesting period			3 years
Estimated forfeiture rates			0.00%
Time-based restricted stock awards | Maximum
Class Of Stock [Line Items]
Vesting period			4 years
Estimated forfeiture rates			20.00%
Stock appreciation awards
Class Of Stock [Line Items]
Vesting period			4 years
Minimum appreciation over stock price for last year			10.00%
Number of trading days			20 days
Common Stock, Average stock price | $ / shares			$ 11.639
Expired, Shares			257,659	156,793	390,174
TSR awards
Class Of Stock [Line Items]
Shares granted				487,819	354,517
Number of Peer Companies | Entity				17
Number of installment for performance-Vested Shares vest | Installment				3
TSR awards | First Installment
Class Of Stock [Line Items]
Vesting period				1 year
TSR awards | Second Installment
Class Of Stock [Line Items]
Vesting period				2 years
TSR awards | Third Installment
Class Of Stock [Line Items]
Vesting period				3 years
TSR Awards and Stock Appreciation Awards
Class Of Stock [Line Items]
Estimated forfeiture rates			4.00%

Changes in Non-Vested Stock Opt

Changes in Non-Vested Stock Option Awards (Detail) - Stock Option Awards	12 Months Ended
	Dec. 31, 2015$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted, Shares | shares	2,043,002
Forfeited, Shares | shares	(60,500)
Non-vested, end of period, Shares | shares	1,982,502
Granted, Weighted Average Grant Date Fair Value | $ / shares	$ 0.92
Forfeited, Weighted Average Grant Date Fair Value | $ / shares	0.97
Non-vested, end of period, Weighted Average Grant Date Fair Value | $ / shares	$ 0.92

Changes in Non-Vested Time Base

Changes in Non-Vested Time Based Restricted Stock Awards (Detail) - Time-based restricted stock awards - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested, beginning of period, Shares	2,497,830	2,005,721	1,176,890
Granted, Shares	160,500	1,595,535	1,570,393
Vested, Shares	(1,110,683)	(819,615)	(559,763)
Forfeited, Shares	(118,673)	(283,811)	(181,799)
Non-vested, end of period, Shares	1,428,974	2,497,830	2,005,721
Non-vested, beginning of period, Weighted Average Grant Date Fair Value	$ 9.43	$ 10.62	$ 12
Granted, Weighted Average Grant Date Fair Value	1.35	8.86	10.31
Vested, Weighted Average Grant Date Fair Value	9.56	10.87	12.47
Forfeited, Weighted Average Grant Date Fair Value	8.80	9.65	11.15
Non-vested, end of period, Weighted Average Grant Date Fair Value	$ 8.42	$ 9.43	$ 10.62

Changes in Non-Vested Stock App

Changes in Non-Vested Stock Appreciation Awards (Detail) - Stock appreciation awards - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested, beginning of period, Shares	266,652	444,571	895,892
Forfeited, Shares	(8,993)	(21,126)	(61,147)
Expired, Shares	(257,659)	(156,793)	(390,174)
Non-vested, end of period, Shares		266,652	444,571
Non-vested, beginning of period, Weighted Average Grant Date Fair Value		$ 3.95	$ 7.60	$ 8.43
Forfeited, Weighted Average Grant Date Fair Value	$ 3.75	7.04	7.82
Expired, Weighted Average Grant Date Fair Value	$ 3.96	$ 13.89	$ 9.38

Valuation Model for Performance

Valuation Model for Performance-Based Awards (Detail) - Stock Performance Based Awards	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Average Expected Volatility	39.40%	35.00%
Dividend yield	0.00%	0.00%
Risk-Free Interest Rate	0.69%	0.42%

Changes in Non-Vested TSR Award

Changes in Non-Vested TSR Awards (Detail) - TSR awards - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested, beginning of period, Shares	764,598	340,166
Granted, Shares		487,819	354,517
Vested, Shares		(63,387)
Forfeited, Shares			(14,351)
Non-vested, end of period, Shares	764,598	764,598	340,166
Non-vested, beginning of period, Weighted Average Grant Date Fair Value	$ 14.26	$ 15.91
Granted, Weighted Average Grant Date Fair Value		13.32	$ 15.91
Vested, Weighted Average Grant Date Fair Value		15.91
Forfeited, Weighted Average Grant Date Fair Value			15.91
Non-vested, end of period, Weighted Average Grant Date Fair Value	$ 14.26	$ 14.26	$ 15.91

Stockholders' Equity and Equi62

Stockholders' Equity and Equity Based Awards - Liability Awards - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	Nov. 30, 2015	May. 31, 2015	Dec. 31, 2015	May. 05, 2015
Class Of Stock [Line Items]
Number of trading days	30 days
Time-based restricted cash awards
Class Of Stock [Line Items]
Vesting period			3 years
Estimated forfeiture rates			15.00%
Restricted cash award, fair value			$ 4.4
Restricted cash award, fair value accrued			$ 1
Performance-based restricted cash awards
Class Of Stock [Line Items]
Vesting period			3 years
Estimated forfeiture rates			5.00%
Restricted cash award, fair value			$ 0.6	$ 0.9
Restricted cash award, fair value accrued			$ 0.2
Number of trading days			60 days
Common stock, hurdle stock price		$ 2
Restricted cash award, term			10 years
Restricted cash award, average effective term			7 years
Performance-based restricted cash awards | Maximum
Class Of Stock [Line Items]
Common stock, hurdle stock price		$ 8
Non-Employee Directors | Time-based restricted cash awards
Class Of Stock [Line Items]
Vesting period			1 year

Asset Retirement Obligation - A

Asset Retirement Obligation - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2015
Minimum
Asset Retirement Obligations [Line Items]
Credit-adjusted risk-free discounted rate	7.00%
Maximum
Asset Retirement Obligations [Line Items]
Credit-adjusted risk-free discounted rate	12.00%

Reconciliation of Asset Retirem

Reconciliation of Asset Retirement Obligations (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period	$ 31,340	$ 31,989
Additional liability incurred / acquired	96	144
Accretion expense	2,740	2,576
Liabilities settled	(15,177)	(1,282)
Revisions to previous estimates	239	(2,087)
Asset retirement obligations at end of period	19,238	31,340
Less: current asset retirement obligations	(891)	(327)
Long-term asset retirement obligations	$ 18,347	$ 31,013

Derivative Instruments - Additi

Derivative Instruments - Additional Information (Detail) $ in Millions	Dec. 31, 2015USD ($)
Derivative [Line Items]
Maximum amount of loss in the event of all counterparties defaulting	$ 95.9
Level 2 | Commodity Contract
Derivative [Line Items]
Fair value of commodity derivatives net asset	$ 95.9

Oil and Gas Commodity Contracts

Oil and Gas Commodity Contracts (Detail)	12 Months Ended
	Dec. 31, 2015bblMMBTU$ / bbl$ / MMBTU
Oil (NYMEX WTI) | Jan – Dec 2016
Derivative [Line Items]
Bbl per Day | bbl	6,500
Weighted Average Swap Price per Bbl | $ / bbl	80.42
Oil (NYMEX WTI) | July – Dec 2016
Derivative [Line Items]
Bbl per Day | bbl	75
Weighted Average Swap Price per Bbl | $ / bbl	52.75
Oil (NYMEX WTI) | Jan – June 2017
Derivative [Line Items]
Bbl per Day | bbl	65
Weighted Average Swap Price per Bbl | $ / bbl	54.75
Gas (NYMEX HH) | July – Dec 2016
Derivative [Line Items]
MMBtu per Day | MMBTU	5,100
Weighted Average Swap Price per MMBtu | $ / MMBTU	2.975
Gas (NYMEX HH) | Jan – June 2017
Derivative [Line Items]
MMBtu per Day | MMBTU	2,400
Weighted Average Swap Price per MMBtu | $ / MMBTU	3.083

Commodity Collar Contracts (Det

Commodity Collar Contracts (Detail) - Commodity Contract - Oil (NYMEX WTI) - Three-Way Oil Collar - Jan – Dec 2017	Dec. 31, 2015bbl$ / bbl
Derivative [Line Items]
Bbl per Day | bbl	1,000
Weighted Average Short Put Price	45
Weighted Average Floor Price	60
Weighted Average Ceiling Price	71.73

Summary of Subsequent Additiona

Summary of Subsequent Additional Commodity Derivative Contracts (Detail)	12 Months Ended
	Dec. 31, 2015bblMMBTU$ / bbl$ / MMBTU
Apr - June 2016 | Gas (NYMEX HH) | Commodity Swap Contracts
Derivative [Line Items]
MMBtu per Day | MMBTU	4,600
Weighted Average Swap Price per MMBtu	1.805
Jan – Dec 2017 | Oil (NYMEX WTI) | Commodity Swap Contracts
Derivative [Line Items]
Bbl per Day | bbl	1,000
Weighted Average Swap Price per Bbl | $ / bbl	49
Jan - Mar 2017 | Gas (NYMEX HH) | Commodity Swap Contracts
Derivative [Line Items]
MMBtu per Day | MMBTU	1,600
Weighted Average Swap Price per MMBtu	2.488
Apr - June 2017 | Gas (NYMEX HH) | Commodity Swap Contracts
Derivative [Line Items]
MMBtu per Day | MMBTU	1,700
Weighted Average Swap Price per MMBtu	2.327
July - Sept 2017 | Gas (NYMEX HH) | Two-Way Collar
Derivative [Line Items]
MMBtu per Day | MMBTU	3,250
Weighted Average Floor Price per MMBtu	2.25
Weighted Average Ceiling Price per MMBtu	2.53
Oct - Dec 2017 | Gas (NYMEX HH) | Two-Way Collar
Derivative [Line Items]
MMBtu per Day | MMBTU	3,250
Weighted Average Floor Price per MMBtu	2.25
Weighted Average Ceiling Price per MMBtu	2.75
Jan - Dec 2018 | Oil (NYMEX WTI) | Oil Call Contract
Derivative [Line Items]
Bbl per Day | bbl	1,100
Sold Call Price | $ / bbl	50

Amount of Commodity Derivative

Amount of Commodity Derivative Instrument Gains Losses (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Commodity derivative settlement gains (losses)	$ 93,150	$ (4,988)	$ (35,812)
Mark-to-market gain	(16,658)	123,129	20,476
Commodity derivative instruments gain (loss)	$ 76,492	$ 118,141	$ (15,336)

Assets and Liabilities Required

Assets and Liabilities Required to be Measured at Fair Value on Recurring Basis (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Assets
Derivative instruments, current assets	$ 92,431	$ 72,753
Derivative instruments, long term assets	3,463	39,799
Fair Value Measurements Recurring Basis | Level 2 | Commodity
Assets
Derivative instruments, current assets	92,431	72,753
Derivative instruments, long term assets	3,463	39,799
Total assets	$ 95,894	$ 112,552

Future Minimum COTwo Purchase C

Future Minimum COTwo Purchase Commitments (Detail) - Co2 Kinder Morgan company $ in Thousands	Dec. 31, 2015USD ($)
Recorded Unconditional Purchase Obligation [Line Items]
2,016	$ 12,078
2,017	546
Total	$ 12,624

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Detail) $ in Millions	3 Months Ended	12 Months Ended
	Jun. 30, 2012	Dec. 31, 2015USD ($)Agreement	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
NNOGC
Commitment And Contingencies [Line Items]
Percentage of interest that each purchase options entitles to purchase		10.00%
NNOGC | Aneth Field Properties
Commitment And Contingencies [Line Items]
Percentage of ownership interest sold	10.00%
NNOGC | Chevron Properties
Commitment And Contingencies [Line Items]
Number of purchase options | Agreement		3
Office facilities
Commitment And Contingencies [Line Items]
Rental expense, net		$ 1.1	$ 1.6	$ 2
Compressors and Other Oilfield Equipment
Commitment And Contingencies [Line Items]
Rental expense, net		1.9	$ 2.6	$ 2.9
Escrow Funding Agreement
Commitment And Contingencies [Line Items]
Funding amount in 2016		1.6
Aggregate funding commitment		26
Annual contractual amount funded		1.6
Escrow Funding Agreement | Additional Payments Per Year Until 2031
Commitment And Contingencies [Line Items]
Aggregate funding commitment		$ 0.9

Schedule of Future Payment Oper

Schedule of Future Payment Operating Leases Agreements (Detail) $ in Thousands	Dec. 31, 2015USD ($)
Operating Leases Future Minimum Payments Due [Abstract]
2,016	$ 7,380
2,017	3,320
2,018	1,667
2019 and thereafter	4,400
Total	16,767
Office Lease Rentals
Operating Leases Future Minimum Payments Due [Abstract]
2,016	1,832
2,017	1,699
2,018	1,560
2019 and thereafter	4,390
Total	9,481
Field Equipment Rentals
Operating Leases Future Minimum Payments Due [Abstract]
2,016	4,782
2,017	1,275
Total	6,057
Vehicle Lease Rentals
Operating Leases Future Minimum Payments Due [Abstract]
2,016	766
2,017	346
2,018	107
2019 and thereafter	10
Total	$ 1,229

Costs Incurred in Oil and Gas P

Costs Incurred in Oil and Gas Property Acquisition Exploration and Development Activities (Detail) - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Acquisition costs
Proved				$ 155,958
Unproved		$ 6,583	$ 7,007	121,362
Exploration costs		13,764	111,769	150,072
Development costs	[1]	39,883	50,291	97,308
Total		$ 60,230	$ 169,067	$ 524,700
[1]	*Includes $8.9 million, $16.3 million and $20.0 million of acquired CO2 during 2015, 2014 and 2013, respectively

Costs Incurred in Oil and Gas75

Costs Incurred in Oil and Gas Property Acquisition Exploration and Development Activities (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Extractive Industries [Abstract]
Acquired CO2	$ 8.9	$ 16.3	$ 20

Net Capitalized Costs Related t

Net Capitalized Costs Related to Resolute's Oil and Gas Producing Activities (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Property Plant And Equipment [Abstract]
Proved oil and gas properties	$ 1,732,707	$ 1,706,847
Unevaluated oil and gas properties, not subject to amortization	21,264	270,375
Accumulated depletion, depreciation and amortization	(1,534,479)	(738,979)
Oil and gas properties, net	$ 219,492	$ 1,238,243

Changes in Estimated Reserves (

Changes in Estimated Reserves (Detail) bbl in Thousands, MMcf in Thousands, Boe in Thousands		12 Months Ended
		Dec. 31, 2015BoebblMMcf	Dec. 31, 2014BoebblMMcf	Dec. 31, 2013BoebblMMcf
Oil Equivalent
Reserve Quantities [Line Items]
Proved reserves, beginning balance | Boe	[1]	74,218	59,394	78,774
Purchase of minerals in place | Boe	[1]			7,818
Production | Boe	[1]	(4,535)	(4,647)	(4,467)
Extensions, discoveries and other additions | Boe	[1],[2]	4,602	28,800	5,805
Sales of minerals in place | Boe	[1]	(12,072)	(224)	(5,906)
Revisions of previous estimates | Boe	[1]	(29,093)	(9,105)	(22,630)	[3]
Proved reserves, ending balance | Boe	[1]	33,120	74,218	59,394
Proved developed reserves | Boe	[1]	27,874	41,446	46,842
Proved undeveloped reserves | Boe	[1]	5,246	32,772	12,552
Oil
Reserve Quantities [Line Items]
Proved reserves, beginning balance		63,715	47,511	62,557
Purchase of minerals in place				4,592
Production		(3,270)	(3,489)	(3,499)
Extensions, discoveries and other additions	[2]	1,965	25,756	4,038
Sales of minerals in place		(5,289)	(215)	(5,124)
Revisions of previous estimates		(28,373)	(5,848)	(15,053)	[3]
Proved reserves, ending balance		28,748	63,715	47,511
Proved developed reserves		25,672	34,359	38,791
Proved undeveloped reserves		3,076	29,356	8,720
Gas
Reserve Quantities [Line Items]
Proved reserves, beginning balance | MMcf		36,798	42,389	47,721
Purchase of minerals in place | MMcf				10,821
Production | MMcf		(5,193)	(6,942)	(4,565)
Extensions, discoveries and other additions | MMcf	[2]	8,208	10,128	6,128
Sales of minerals in place | MMcf		(23,674)	(26)	(3,379)
Revisions of previous estimates | MMcf		(2,279)	(8,751)	(14,337)	[3]
Proved reserves, ending balance | MMcf		13,860	36,798	42,389
Proved developed reserves | MMcf		7,098	25,775	29,488
Proved undeveloped reserves | MMcf		6,761	11,023	12,901
NGL
Reserve Quantities [Line Items]
Proved reserves, beginning balance		4,370	4,817	8,264
Purchase of minerals in place				1,422
Production		(400)		(207)
Extensions, discoveries and other additions	[2]	1,269	1,357	746
Sales of minerals in place		(2,837)	(5)	(219)
Revisions of previous estimates		(341)	(1,799)	(5,189)	[3]
Proved reserves, ending balance		2,061	4,370	4,817
Proved developed reserves		1,019	2,791	3,136
Proved undeveloped reserves		1,043	1,579	1,681
[1]	In accordance with SEC and Financial Accounting Standards Board (“FASB”) requirements, our estimated net proved reserves and standardized measure at December 31, 2015, 2014 and 2013, utilized prices (subsequently adjusted for quality and basis differentials) of an average NYMEX West Texas Intermediate oil price of $50.28, $94.99 and $96.94 per Bbl for the Aneth Properties and Plains Marketing, L.P. posted West Texas Intermediate oil price of $46.79, $91.48 and $93.42 per Bbl for the Permian Properties, and an average Henry Hub spot market gas price of $2.59, $4.35 and $3.67 per one MMBtu of gas, respectively.
[2]	Extensions, discoveries and other additions in 2015 are associated with the Permian drilling program in Reeves County resulting in 576 MBoe added to proved developed producing reserves from drilling proved locations, and 970 MBoe from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 3,632 MBoe reserves. Extensions, discoveries and other additions in 2014 were primarily associated with reinstatement of CO2 enhanced recovery projects that were removed for year-end 2013 reporting to comply with the SEC five-year rule pertaining to undeveloped reserves. Approximately 21.1 MMBoe had been reinstated as proved undeveloped all comprised of four named CO2 injection projects identified in the Aneth Field Properties: 8.9 MMBoe for Aneth Unit Phase 4 CO2 injection, 3.0 MMBoe for McElmo Unit DCIIC CO2 injection, 4.9 MMBoe for Ratherford DCIA CO2 injection and 4.3 MMBoe for Ratherford DCIIC CO2 injection. Additionally, the Permian Basin and Powder River Basin properties held active drilling programs in 2014 resulting in 1.7 MMBoe added to proved developed producing from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 6.0 MMBoe reserves.
[3]	Decreases in proved reserves associated with revisions of previous estimates resulted primarily from reduced product pricing. Deferral of the Aneth CO2 projects decreased proved undeveloped reserves by approximately 22,786 MBoe, offset by approximately 4,602 MBoe converted to proved during 2015 in the Permian. The deferred projects will again be eligible as proved undeveloped reserves in the future, at such time as management adopts a definitive plan to complete the projects and improved product pricing renders them economic under SEC rules. In 2014 decreases in proved reserves associated with revisions of previous estimates resulted from management’s decision to allocate more of its 2014 capital expenditures towards exploitation drilling of higher rate-of-return horizontal wells in the Permian Basin and less capital towards development projects in Aneth Field. Deferral of these projects to 2015 and beyond decreased proved undeveloped reserves by approximately 25 MMBoe, as these projects were no longer expected to be converted to developed reserves within five years after their initial recognition as proved reserves as required under SEC rules, offset by approximately 3 MMBoe converted to proved developed during 2013.

Changes in Estimated Reserves78

Changes in Estimated Reserves (Parenthetical) (Detail) Boe in Thousands	3 Months Ended	12 Months Ended
	Dec. 31, 2013Boe	Dec. 31, 2015Boe$ / bbl	Dec. 31, 2014Boe$ / bbl	Dec. 31, 2013$ / bbl
Proved undeveloped reserves
Reserve Quantities [Line Items]
Reinstatements (additions) of estimated proved developed reserves			21,100
Period for converting proved undeveloped locations to proved developed properties			5 years
Proved developed and undeveloped reserves extensions discoveries reductions	25,000	22,786
Proved developed and undeveloped reserves extensions discoveries additions	3,000	4,602
Oil | NYMEX West Texas
Reserve Quantities [Line Items]
Average oil and gas market price | $ / bbl		50.28	94.99	96.94
Oil | Plains Marketing, L.P. West Texas
Reserve Quantities [Line Items]
Average oil and gas market price | $ / bbl		46.79	91.48	93.42
Gas | Henry Hub
Reserve Quantities [Line Items]
Average oil and gas market price | $ / bbl		2.59	4.35	3.67
Permian drilling program
Reserve Quantities [Line Items]
Reinstatements (additions) of estimated proved developed reserves		576
Reinstatements (additions) from non-proved location		970
Additional proved undeveloped offset locations | Proved undeveloped reserves
Reserve Quantities [Line Items]
Reinstatements (additions) of estimated proved developed reserves		3,632	6,000
Aneth Unit Phase 4 CO2 injection | Proved undeveloped reserves
Reserve Quantities [Line Items]
Reinstatements (additions) of estimated proved developed reserves			8,900
McElmo Unit DCIIC CO2 injection | Proved undeveloped reserves
Reserve Quantities [Line Items]
Reinstatements (additions) of estimated proved developed reserves			3,000
Ratherford DCIA CO2 injection | Proved undeveloped reserves
Reserve Quantities [Line Items]
Reinstatements (additions) of estimated proved developed reserves			4,900
Ratherford DCIIC CO2 injection | Proved undeveloped reserves
Reserve Quantities [Line Items]
Reinstatements (additions) of estimated proved developed reserves			4,300
Permian and Powder River Basin | Proved undeveloped reserves
Reserve Quantities [Line Items]
Reinstatements (additions) of estimated proved developed reserves			1,700

Supplemental Oil and Gas Info79

Supplemental Oil and Gas Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Extractive Industries [Abstract]
Discount factor	10.00%	10.00%	10.00%

Future Net Cash Flows Relating

Future Net Cash Flows Relating to Proved Oil and Gas Reserves (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Extractive Industries [Abstract]
Future cash inflows	$ 1,293,000	$ 5,858,000	$ 4,647,000
Future production costs	(774,000)	(2,719,000)	(2,050,000)
Future development costs	(180,000)	(1,008,000)	(547,000)
Future income taxes		(412,000)	(398,000)
Future net cash flows	339,000	1,719,000	1,652,000
10% annual discount for estimated timing of cash flows	(140,000)	(886,000)	(759,000)
Standardized measure of discounted future net cash flows	$ 199,000	$ 833,000	$ 893,000	$ 872,000

Future Net Cash Flows Relatin81

Future Net Cash Flows Relating to Proved Oil and Gas Reserves (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Extractive Industries [Abstract]
Discount factor	10.00%	10.00%	10.00%

Principal Sources of Change in

Principal Sources of Change in Standardized Measure of Discounted Future Net Cash Flows (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Extractive Industries [Abstract]
Standardized measure, beginning of year	$ 833,000	$ 893,000	$ 872,000
Sales of oil and gas produced, net of production costs	(181,000)	(196,000)	(206,000)
Net changes in prices and production costs	(917,000)	(191,000)	61,000
Purchases of minerals in place			106,000
Sales of minerals in place	(134,000)	(6,000)	(84,000)
Previously estimated development costs incurred during the year	33,000	49,000	89,000
Extensions, discoveries and improved recovery	13,000	207,000	111,000
Changes in estimated future development costs	119,000	(13,000)	(64,000)
Revisions of previous quantity estimates	196,000	(16,000)	(203,000)
Accretion of discount	70,000	89,000	79,000
Net change in income taxes	104,000	44,000	67,000
Changes in timing and other	63,000	(27,000)	65,000
Standardized measure, end of year	$ 199,000	$ 833,000	$ 893,000

Quarterly Financial Data (unaud

Quarterly Financial Data (unaudited) (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Quarterly Financial Data [Abstract]
Revenue	$ 28,498	$ 36,617	$ 48,396	$ 41,133	$ 65,932	$ 84,102	$ 88,459	$ 90,878
Operating expenses	(122,104)	(253,484)	(270,291)	(285,469)	(199,331)	(81,384)	(81,527)	(79,803)	$ (931,348)	$ (442,045)	$ (483,647)
Loss from operations	(93,606)	(216,867)	(221,895)	(244,336)	(133,399)	2,718	6,932	11,075	(776,704)	(112,674)	(133,868)
Net income (loss)	$ (92,180)	$ (182,770)	$ (259,107)	$ (208,222)	$ (17,148)	$ 14,966	$ (16,120)	$ (3,548)	$ (742,279)	$ (21,850)	$ (113,806)
Earnings (loss) per common share:
Basic	$ (1.23)	$ (2.44)	$ (3.46)	$ (2.80)	$ (0.23)	$ 0.20	$ (0.22)	$ (0.05)
Diluted	$ (1.23)	$ (2.44)	$ (3.46)	$ (2.80)	$ (0.23)	$ 0.20	$ (0.22)	$ (0.05)
Weighted average common shares outstanding:
Basic	74,897	74,857	74,826	74,284	73,917	73,886	73,843	73,540	74,932	73,798	68,260
Diluted	74,897	74,857	74,826	74,284	73,917	74,050	73,843	73,540	74,932	73,798	68,260