Cimarex Resolute (REN) 10-K 13 Mar 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Feb. 28, 2017	Jun. 30, 2016
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
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	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		22,437,470
Entity Public Float			$ 42.4

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Current assets:
Cash and cash equivalents	$ 133,089	$ 9,297
Accounts receivable	55,228	37,100
Commodity derivative instruments	218	92,431
Prepaid expenses and other current assets	3,249	1,387
Total current assets	191,784	140,215
Property and equipment, at cost:
Oil and gas properties, full cost method of accounting, Unproved	121,375	21,264
Oil and gas properties, full cost method of accounting, Proved	1,889,111	1,732,707
Other property and equipment	9,754	9,648
Accumulated depletion, depreciation and amortization	(1,647,120)	(1,540,447)
Net property and equipment	373,120	223,172
Other assets:
Restricted cash	23,137	21,497
Commodity derivative instruments		3,463
Other assets	332	2,636
Total assets	588,373	390,983
Current liabilities:
Accounts payable	8,675	7,101
Accrued expenses	57,308	44,414
Accrued interest payable	5,784	5,764
Asset retirement obligations	895	891
Commodity derivative instruments	8,014
Accrued cash-settled incentive awards	27,158	1,082
Secured term loan facility	122,139
Total current liabilities	229,973	59,252
Long term liabilities:
Revolving credit facility	8,821
Secured term loan facility		118,944
Senior notes	397,154	396,051
Asset retirement obligations	19,457	18,347
Commodity derivative instruments	4,104
Other long term liabilities	4,611	1,670
Total liabilities	664,120	594,264
Commitments and contingencies
Stockholders’ deficit:
Convertible preferred stock, $0.0001 par value; 1,000,000 shares authorized; issued and outstanding 62,500 and 0 shares at December 31, 2016 and 2015, respectively; $62.5 million liquidation preference
Common stock, $0.0001 par value; 45,000,000 shares authorized; issued and outstanding 21,932,842 and 15,442,147 shares at December 31, 2016 and 2015, respectively	2	2
Additional paid-in capital	948,380	659,124
Accumulated deficit	(1,024,129)	(862,407)
Total stockholders’ deficit	(75,747)	(203,281)
Total liabilities and stockholders’ deficit	$ 588,373	$ 390,983

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
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	62,500	0
Preferred stock, outstanding	62,500	0
Preferred stock, liquidation preference	$ 62.5
Common stock, par value	$ 0.0001	$ 0.0001
Common stock, shares authorized	45,000,000	45,000,000
Common stock, issued	21,932,842	15,442,147
Common stock, outstanding	21,932,842	15,442,147

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Revenue:
Oil	$ 148,336	$ 137,893	$ 293,970
Gas	10,661	12,628	26,254
Natural gas liquids	5,481	4,123	9,147
Total revenue	164,478	154,644	329,371
Operating expenses:
Lease operating	63,699	79,393	112,683
Production and ad valorem taxes	16,270	19,985	37,216
Depletion, depreciation, amortization, and asset retirement obligation accretion	50,462	94,338	132,154
Impairment of proved oil and gas properties	58,000	705,000	120,000
General and administrative	32,627	31,447	39,992
Cash-settled incentive awards	34,926	1,185	0
Total operating expenses	255,984	931,348	442,045
Loss from operations	(91,506)	(776,704)	(112,674)
Other income (expense):
Interest expense, net	(50,684)	(64,358)	(31,489)
Commodity derivative instruments gain (loss)	(19,784)	76,492	118,141
Other income (expense)	343	(63)	32
Total other income (expense)	(70,125)	12,071	86,684
Loss before income taxes	(161,631)	(764,633)	(25,990)
Income tax benefit (expense)	(91)	22,354	4,140
Net loss	$ (161,722)	$ (742,279)	$ (21,850)
Net loss per common share:
Basic and diluted	$ (10.33)	$ (49.55)	$ (1.50)
Weighted average common shares outstanding:
Basic and diluted	15,767	14,986	14,760

Consolidated Statements of Stoc

Consolidated Statements of Stockholders' Equity (Deficit) - USD ($) shares in Thousands, $ in Thousands	Total	Common Stock	Preferred Stock	Additional Paid-in Capital	Accumulated Deficit
Beginning Balance at Dec. 31, 2013	$ 533,552	$ 2		$ 631,828	$ (98,278)
Beginning Balance (in shares) at Dec. 31, 2013		15,246
Issuance of stock, restricted stock and share-based compensation	16,651			16,651
Issuance of stock, restricted stock and share-based compensation (in shares)		416
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations	(1,735)			(1,735)
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations (in shares)		(135)
Net loss	(21,850)				(21,850)
Ending Balance at Dec. 31, 2014	526,618	$ 2		646,744	(120,128)
Ending Balance (in shares) at Dec. 31, 2014		15,527
Issuance of stock, restricted stock and share-based compensation	12,556			12,556
Issuance of stock, restricted stock and share-based compensation (in shares)		32
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)		(117)
Net loss	(742,279)				(742,279)
Ending Balance at Dec. 31, 2015	(203,281)	$ 2		659,124	(862,407)
Ending Balance (in shares) at Dec. 31, 2015		15,442
Issuance of stock, restricted stock and share-based compensation	6,423			6,423
Issuance of stock, restricted stock and share-based compensation (in shares)		93
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations	(122)			(122)
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations (in shares)		(109)
Exercise of stock options	98			98
Exercise of stock options (in shares)		22
Issuance of preferred stock, net of underwriters discounts	59,677			59,677
Issuance of preferred stock, net of underwriters discounts (in shares)			63
Issuance of common stock to Firewheel	62,293			62,293
Issuance of common stock to Firewheel (in shares)		2,115
Issuance of common stock, net of underwriters discounts	160,887			160,887
Issuance of common stock, net of underwriters discounts (in shares)		4,370
Net loss	(161,722)				(161,722)
Ending Balance at Dec. 31, 2016	$ (75,747)	$ 2		$ 948,380	$ (1,024,129)
Ending Balance (in shares) at Dec. 31, 2016		21,933	63

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating activities:
Net loss	$ (161,722)	$ (742,279)	$ (21,850)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion, depreciation, amortization, and asset retirement obligation accretion	50,462	94,338	132,154
Impairment of proved oil and gas properties	58,000	705,000	120,000
Amortization of deferred financing costs and long-term debt premium and discount	5,240	11,578	2,337
Share-based compensation	6,315	12,148	16,331
Commodity derivative instruments loss (gain)	19,784	(76,492)	(118,141)
Commodity derivative settlement gains (losses)	88,010	93,150	(4,988)
Deferred income tax benefit		(22,354)	(4,140)
Change in operating assets and liabilities:
Accounts receivable	(18,019)	21,216	36,768
Other current assets	109	322	(706)
Accounts payable and accrued expenses	35,520	(27,173)	(14,297)
Accrued interest payable	20	25
Net cash provided by operating activities	83,719	69,479	143,468
Investing activities:
Oil and gas exploration and development expenditures	(128,340)	(67,636)	(183,565)
Purchase of oil and gas properties	(95,940)
Proceeds from sale of oil and gas properties and other	35,477	268,773	11,122
Purchase of other property and equipment	(106)	(124)	(1,925)
Restricted cash	(1,640)	(1,489)	(1,639)
Other	82	59	114
Net cash provided by (used in) investing activities	(190,467)	199,583	(175,893)
Financing activities:
Proceeds from bank borrowings	156,500	183,000	433,500
Repayments of bank borrowings	(146,500)	(418,000)	(533,500)
Proceeds from issuance of common stock, net of underwriters discounts and commissions	160,887
Proceeds from issuance of preferred stock, net of underwriters discounts and commissions	59,677
Proceeds from issuance of term loans		46,500	139,500
Repayment of term loans		(71,697)
Payment of financing costs		(3,744)	(1,007)
Redemption of restricted stock for employee income taxes	(122)	(176)	(1,735)
Proceeds from exercise of employee options to purchase common stock	98
Net cash provided by (used in) financing activities	230,540	(264,117)	36,758
Net increase in cash and cash equivalents	123,792	4,945	4,333
Cash and cash equivalents at beginning of period	9,297	4,352	19
Cash and cash equivalents at end of period	133,089	9,297	4,352
Cash paid during the period for:
Interest, net of amounts capitalized	50,684	64,364	31,890
Supplemental schedule of non-cash investing and financing activities:
Issuance of common stock for purchase of oil and gas properties	62,293
Capital expenditures financed through current liabilities	18,440	10,482	17,651
Increase (decrease) to asset retirement obligations	412	333	(2,012)
Asset retirement obligations assumed	587
Asset retirement obligations sold	$ 1,081	$ 14,985	$ 157

Organization and Nature of Busi

Organization and Nature of Business	12 Months Ended
	Dec. 31, 2016
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 operating assets are comprised primarily of properties in the Delaware Basin in west Texas (the “Permian Properties” or “Permian Basin Properties”) and Aneth Field located in the Paradox Basin in southeast Utah (the “Aneth Field Properties” or “Aneth Field”). 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, 2016
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 condensed 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 condensed 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; cash-settled long-term incentive 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 (defined in Note 5) has a recorded value that approximates its fair market value. The fair value of $123.4 million under the second lien secured term loan due March 2018 (the “Secured Term Loan Facility”) approximates the principal less the unamortized discount. Lastly, the fair value of $407.3 million under the senior notes due May 1, 2020 (the “Senior Notes” or the “Notes”) is 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, 2016 2015 Trade receivables $ 14,898 $ 14,224 Revenue receivables 32,817 12,967 Derivative receivables 5,695 9,759 Other receivables 1,818 150 Total accounts receivable $ 55,228 $ 37,100 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, 2016 and 2015, the Company had no allowance for doubtful accounts recorded. Deferred Financing Costs Deferred financing costs are amortized over the estimated life of the related obligation and it is our policy to net these costs against the related debt. The Company incurred $0 in deferred financing costs in 2016, $0 in 2015 and $4.8 million in 2014, and amortized $3.1 million, $5.0 million and $2.5 million to interest expense during 2016, 2015 and 2014, 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 $4.1 million, $6.0 million and $14.9 million during 2016, 2015 and 2014, 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 47%, 27% and 13% of its total 2016 revenue from Western Refining, Inc. (“Western”), Plains Marketing LP and Holly Frontier LLC, respectively; 58% and 14% of its total 2015 revenue from Western and Holly Frontier LLC, respectively and 62% and 14% of its total 2014 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 counterparties are current or former lenders under Resolute’s Revolving Credit Facility (defined in 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 $5.7 million during 2016, $6.3 million during 2015 and $9.8 million during 2014. 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 play in the Delaware Basin in Texas. The Company expects to evaluate these locations for the existence of proved reserves in the next two years, although volatility in commodity prices may affect 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 2016, 2015 and 2014, the Company recorded $58 million, $705 million and $120 million, respectively, non-cash impairments 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, 2016, 2015 and 2014. 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 $23.1 million located on the Company’s consolidated balance sheet in non-current other assets at December 31, 2016, is contractually 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. Long-term Employee Incentive 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). Cash-settled incentive award expense is measured quarterly using a cash-or-nothing valuation model. The Company estimates forfeitures in calculating the cost related to share-based compensation and cash-settled incentive awards expense 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 company early adopted Accounting Standards Update (ASU) No. 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. Recent Accounting Pronouncements In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers, In May 2016, the FASB issued ASU 2016-12 : Revenue from Contracts with Customers (Topic 606): Narrow Scope Improvements and Practical Expedients In February 2016 the FASB issued new authoritative guidance related to the accounting of leases. The main provisions require that lessees recognize both a lease liability and a right-of-use asset at the commencement date. This authoritative accounting guidance is effective for the annual period beginning after December 15, 2018, and interim periods within annual periods beginning after December 15, 2018. The Company is currently evaluating the provisions of this guidance and assessing its impact on the Company’s financial statements and disclosures.

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2016
Business Combinations [Abstract]
Acquisitions and Divestitures	Note 3 — Acquisitions and Divestitures Acquisition of Reeves County Properties in the Delaware Basin On October 4, 2016, Resolute and Resolute Southwest entered into a Purchase and Sale Agreement (the “Firewheel Purchase Agreement”) with Firewheel Energy, LLC (“Firewheel”) pursuant to which Resolute Southwest agreed to acquire certain oil and gas interests in the Delaware Basin in Reeves County, Texas (the “Firewheel Properties”), for consideration to Firewheel consisting of $90 million in cash and 2,114,523 shares of common stock of the Company, par value $0.0001 per share, issued to Firewheel upon the closing of the purchase of the Firewheel Properties (the “Delaware Basin Firewheel Acquisition”). The closing of the Delaware Basin Firewheel Acquisition (the “Closing”) occurred on October 7, 2016. The Company acquired the Firewheel Properties for $153.2 million. Revenue and expenses related to the acquired properties are included in the consolidated statement of operations on the closing date of the transaction. The Delaware Basin Firewheel Acquisition was 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 purchase price allocation of the Delaware Basin Firewheel Acquisition at December 31, 2016, based on the fair values of assets acquired and liabilities assumed (in thousands): 2016 Proved oil and gas properties $ 40,900 Unproved oil and gas properties 112,800 Asset retirement obligations assumed (500 ) Total purchase price $ 153,200 Divestitures Divestiture of Midstream Assets in the Delaware Basin In July 2016 Resolute Natural Resources Southwest, LLC (“Resolute Southwest”), a wholly owned subsidiary of Resolute, entered into a definitive Purchase and Sale Agreement (the “Mustang Agreement”) with Caprock Permian Processing LLC and Caprock Field Services LLC, as buyers (collectively, “Caprock”) pursuant to which Resolute Southwest and an existing minority interest holder (collectively, the “Sellers”) agreed to sell certain gas gathering and produced water handling and disposal systems owned by them in the Mustang project area in Reeves County, Texas, (“Mustang”) for a cash payment of $35 million, plus certain earn-out payments described below. In July 2016 Resolute Southwest also entered into a definitive Purchase and Sale Agreement (the “Appaloosa Agreement”) with Caprock, pursuant to which Resolute Southwest agreed to sell certain gas gathering and produced water handling and disposal systems owned by Resolute Southwest in the Appaloosa project area in Reeves County, Texas, (“Appaloosa”) for a cash payment of $15 million, plus certain earn-out payments described below. In August 2016 Resolute Southwest closed the transactions contemplated by the Mustang Agreement and the Appaloosa Agreement. Resolute Southwest received aggregate consideration of approximately $36 million (including earn-out payments earned as of the closing), of which approximately $2 million was placed in an escrow account for a period of time to secure Resolute’s indemnity obligations under the Mustang Agreement and the Appaloosa Agreement. As the sale did not significantly alter the relationship between capital costs and proved reserves, no gain or loss was recognized. The net proceeds of the midstream sale were used to repay amounts outstanding under the Company’s Revolving Credit Facility (defined in Note 5) and for general corporate purposes. In July 2016, in connection with the Appaloosa Agreement and the Mustang Agreement, Resolute Southwest also entered into a definitive Earn-out Agreement (the “Earn-out Agreement”), pursuant to which Resolute Southwest will be entitled to receive certain earn-out payments based on drilling and completion activity in Appaloosa and Mustang through 2020 that will deliver gas and produced water into the system. Earn-out payments for each qualifying well will vary depending on the lateral length of the well and the year in which the well is drilled and completed. On March 10, 2017 the Earn-out Agreement was amended by the parties to provide for an increase in earn-out payments for wells drilled and completed in 2017. Earn-out payments are contingent on future drilling, and therefore will be recognized when received. In connection with the closing of the transactions contemplated by the Appaloosa Agreement and the Mustang Agreement, Resolute Southwest entered into fifteen year commercial agreements with Caprock for gas gathering and processing services and water handling and disposal services for all current and future gas and water produced by Resolute Southwest in Mustang and Appaloosa in exchange for customary fees based on the volume of gas and water produced and delivered. Resolute Southwest has agreed to dedicate and deliver all gas and water produced from its acreage in Mustang and Appaloosa to Caprock for gathering, processing, compression and disposal services for a term of fifteen years. Divestiture of Gardendale Properties in the Midland Basin In December 2015 the Company sold its Gardendale properties in the Midland Basin in Midland and Ector counties, Texas, for approximately $172 million (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 in Note 5). As part of the sale, the Company was 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 this sale were used to pay down amounts outstanding under the revolving credit facility (as defined in Note 5). As a part of the sale, the Company was 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 this sale were used to pay down amounts outstanding under the revolving credit facility (as defined in Note 5). As part of the sale, the Company was no longer liable for asset retirement obligations of $1.3 million at December 31, 2015. Pro Forma Financial Information The unaudited pro forma financial information for the years ended December 31, 2016 and 2015, respectively, reflects Resolute’s results as if the Delaware Basin Firewheel Acquisition and the sale of the Delaware Basin Midstream Assets, Gardendale, Hilight Field, and Howard and Martin County properties had occurred on January 1, 2015 (in thousands, except per share amounts): Year ended December 31, 2016 2015 Revenue $ 171,195 $ 131,520 Loss from operations (93,411 ) (778,268 ) Net loss available to common stockholders (165,397 ) (733,119 ) Basic and diluted net income (loss) per share $ (10.49 ) $ (42.87 ) 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 these acquisitions or divestitures 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.

Earnings per Share

Earnings per Share	12 Months Ended
	Dec. 31, 2016
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. Net income (loss) available to common stockholders is computed by deducting both the dividends declared in the period on preferred and the dividends accumulated for the period on cumulative preferred stock from net income. 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, 2016 2015 2014 Potential dilutive restricted stock 1,112 356 595 Anti-dilutive securities 3,365 980 5,505 The following table sets forth the 2016, 2015 and 2014 computation of basic and diluted net income (loss) per share of common stock for the periods presented (in thousands, except per share amounts): 2016 2015 2014 Net loss available to common stockholders $ (162,907 ) $ (742,279 ) $ (21,850 ) Basic weighted average common shares outstanding 15,767 14,986 14,760 Add: dilutive effect of non-vested restricted stock — — — Diluted weighted average common shares outstanding 15,767 14,986 14,760 Basic and diluted net loss per common share $ (10.33 ) $ (49.55 ) $ (1.50 )

Long Term Debt

Long Term Debt	12 Months Ended
	Dec. 31, 2016
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, 2016 Revolving credit facility $ 10,000 $ — $ (1,179 ) $ 8,821 Secured term loan facility 128,303 (4,882 ) (1,282 ) 122,139 8.50% senior notes 400,000 985 (3,831 ) 397,154 Total $ 538,303 $ (3,897 ) $ (6,292 ) $ 528,114 Current portion of secured term loan facility 128,303 (4,882 ) (1,282 ) 122,139 Long-term debt $ 410,000 $ 985 $ (5,010 ) $ 405,975 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 Unamortized deferred financing costs associated with the revolving credit facility at December 31, 2015, have been included in other assets due to the $0 principal balance. For the years ended December 31, 2016, 2015, and 2014, the Company incurred interest expense on long-term debt of $50.7 million, $70.3 million and $46.4 million, respectively. The Company capitalized $4.1 million, $6.0 million and $14.9 million of interest expense during the years ended December 31, 2016, 2015 and 2014, respectively. Revolving Credit Facility Resolute’s prior revolving credit facility was with a syndicate of banks (the “Revolving Credit Facility”). As a result of the amendment entered on February 17, 2017 (refer to Note 12) the syndicate banks are now led by Bank of Montreal, as Administrative Agent, Capital One, National Association, as syndication agent, and Barclays Bank PLC, ING Capital LLC and SunTrust Bank, as co-documentation agents. The Revolving Credit Facility specifies a maximum borrowing base as determined by the lenders which has initially been set at $150 million. 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 February 2021 unless there is a maturity of material indebtedness prior to such date. The Revolving Credit Facility includes covenants that require, among other things, that Resolute maintains a ratio of current assets to current liabilities of no less than 1.0 to 1.0 and a ratio of funded debt to EBITDA of no more than 4.0 to 1.0. The Revolving Credit Facility prohibits the Company from entering into derivative arrangements for more than (i) 85% of our anticipated production from proved properties in the next 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 (not to exceed a term of 60 months for any such derivative arrangement). The Revolving Credit Facility also includes customary additional terms and covenants that place limitations on certain types of activities, the payment of dividends, and that require satisfaction of certain financial tests. In September 2016 the Company entered into the thirteenth amendment to the Revolving Credit Facility to amend the restricted payment In October 2016 the Company completed its fall borrowing base redetermination, and the borrowing base was re-affirmed at $105 million. In addition, the Company made other administrative amendments to the Revolving Credit Facility. As of December 31, 2016, outstanding borrowings under the Revolving Credit Facility were $10 million with a weighted average interest rate of 2.27%, under a borrowing base of $105 million. The borrowing base availability had been reduced by $3.7 million in conjunction with letters of credit issued at December 31, 2016. 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 that ranges from 3.0% to 4.0% 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 that ranges from 2.0% to 3.0%. Each such margin is based on the level of utilization under the borrowing base. Resolute was in compliance with the terms and covenants of the Revolving Credit Facility at December 31, 2016. 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. Under the original agreement, the Secured Term Loan Facility was to mature on the date that was six months after the maturity of the Company’s existing Revolving Credit Facility, but in no event later than November 1, 2019. However, on January 3, 2017, in conjunction with the repayment of all outstanding amounts, this agreement was terminated. Refer to discussion regarding prepayment below. 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 were 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 generally bore interest at adjusted LIBOR plus 10%, with a 1% LIBOR floor. The covenants in the Secured Term Loan Facility required, 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 1.5, 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, 2016. The Company could have prepaid all or a portion of the Secured Term Loan Facility at any time. The Secured Term Loan Facility was 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 were not subject to prepayment premiums. Mandatory repayments were required of 100% of the net cash proceeds of certain debt or equity issuances. Such prepayments were 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 paid off principal amounts under the second lien facility should have included an additional payment sufficient to ensure that the lenders achieved a 1.25 to 1.0 minimum multiple of their invested capital. During December 2015, the Company retired $70 million of the amount outstanding under the Secured Term Loan Facility following the sale of the Gardendale properties 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, 2016, was estimated to be $123.4 million, which approximates the principal less the unamortized discount. On January 3, 2017, the Company repaid approximately $132 million constituting all amounts due under the Term Loan Facility (including prepayment fees), with a portion of the proceeds from its previously announced common stock offering that closed on December 23, 2016. The Secured Term Loan Facility was terminated in connection with the repayment. Senior Notes In 2012 the Company consummated two private placements of senior notes with principal totaling $400 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 and the Company’s existing subsidiaries (the “Guarantors”) 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 Senior Notes for publically registered Senior 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 certain types of 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, 2016. 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 not less than 30 or more than 60 days’ prior notice, at redemption prices set forth in the Indenture. If a change of control occurs, each holder of the Senior Notes will have the right to require that the Company purchase all of such holder’s Senior Notes in an amount equal to 101% of the principal of such Senior Notes, plus accrued and unpaid interest, if any, to the date of the purchase. As previously disclosed in its Current Report on Form 8-K filed on April 28, 2016, during the month of February 2016, the Company was approached by certain holders of the Senior Notes to engage in discussions with the Company regarding a potential debt exchange, financing or other transaction involving the Senior Notes. The Company and the noteholders did not reach an agreement on such a transaction and the Company has terminated all discussions with noteholders regarding any such transaction but may engage in other such discussions in the future. The fair value of the Senior Notes at December 31, 2016, was estimated to be $407.3 million based upon data from independent market makers (Level 2 fair value measurement).

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Note 6 — Income Taxes The following table summarizes the components of the provision for income taxes (in thousands): 2016 2015 2014 Current income tax (expense) $ (91 ) $ — $ — Deferred income tax benefit — 22,354 4,140 Total income tax benefit (expense) $ (91 ) $ 22,354 $ 4,140 The provision for income taxes for the years ended December 31, 2016, 2015 and 2014 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): 2016 2015 2014 Expected statutory income tax benefit $ 56,571 $ 267,621 $ 9,097 State income tax benefit 3,087 13,394 480 Equity compensation (2,761 ) (4,822 ) (4,273 ) Non-deductible executive compensation (690 ) — (468 ) Valuation allowance (56,005 ) (253,592 ) — Other (293 ) (247 ) (696 ) Total income tax benefit (expense) $ (91 ) $ 22,354 $ 4,140 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, 2016 2015 Deferred income tax assets (liabilities): Derivative financial instruments 4,403 (35,481 ) Net operating loss carryovers 206,663 183,964 Asset retirement obligation 7,530 7,118 Startup and organization costs 104 122 Deferred acquisition costs 45 45 Percentage depletion 1,335 1,360 Property and equipment costs 75,267 91,937 Equity compensation 2,267 3,342 Other 11,983 1,185 Valuation allowance (309,597 ) (253,592 ) Total long term assets (liabilities) — — Net deferred tax asset (liability) $ — $ — The Company has U.S. net operating loss carry forwards of $567 million at December 31, 2016, 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, 2016 and 2015 a valuation allowance should be established against the Company's deferred tax asset. The Company recorded a valuation allowance as of December 31, 2016 and 2015 of $309.6 million and $253.6 million, respectively, 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 2016, 2015 or 2014 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, 2016, 2015 or 2014. The Company early adopted ASU No. 2016-09, Compensation – Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting, which simplifies key components of the accounting for share-based payments under current GAAP requirements. 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 2013 through 2016. The tax years that remain open to examination by state taxing authorities are 2012 through 2016.

Stockholders' Equity and Equity

Stockholders' Equity and Equity Based Awards	12 Months Ended
	Dec. 31, 2016
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. At December 31, 2016, the Company had 62,500 shares of preferred stock issued and outstanding. No shares were issued or outstanding on December 31, 2015. On October 4, 2016, the Company entered into a Purchase Agreement (the “Preferred Stock Purchase Agreement”) with BMO Capital Markets Corp. (“Initial Purchaser”), pursuant to which the Company agreed to issue and sell to Initial Purchaser 55,000 shares (the “Firm Securities”) of the Company’s 8⅛% Series B Cumulative Perpetual Convertible Preferred Stock, par value $0.0001 per share (the “Convertible Preferred Stock”) and, at Initial Purchaser’s option, up to 7,500 additional shares of Convertible Preferred Stock (together with the Firm Securities, collectively, the “Securities”). On October 6, 2016, Initial Purchaser exercised its over-allotment option to purchase the additional 7,500 shares of Convertible Preferred Stock in full, bringing the total shares of Convertible Preferred Stock purchased by Initial Purchaser to 62,500, for an aggregate net consideration of $60 million, before offering expenses. Each holder has the right at any time, at its option, to convert, any or all of such holder’s shares of Convertible Preferred Stock at an initial conversion rate of 33.8616 shares of fully paid and nonassessable shares of Common Stock, per share of Convertible Preferred Stock. Additionally, at any time on or after October 15, 2021, the Company shall have the right, at its option, to elect to cause all, and not part, of the outstanding shares of Convertible Preferred Stock to be automatically converted into that number of shares of Common Stock for each share of Convertible Preferred Stock equal to the conversion rate in effect on the mandatory conversion date as such terms are defined in the Certificate of Designation. As of December 31, 2016, the Company had accumulated preferred dividends of $1.2 million. A total dividend of $1.4 million was declared on January 15, 2017 and paid on January 17, 2017. Common Stock The authorized common stock of the Company consists of 45,000,000 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, 2016 and 2015, the Company had 21,932,842 and 15,442,147 shares of common stock issued and outstanding, respectively. In May 2016, Resolute adopted a stockholder rights plan and in connection with such plan declared a dividend of one preferred share purchase right (a “Right”) for each outstanding share of common stock, par value $0.0001 per share. The Rights trade with, and are inseparable from, the common stock until such time as they become exercisable on the distribution date. The Rights are evidenced only by certificates that represent shares of common stock and not by separate certificates. New Rights will accompany any new shares of common stock we issue after May 27, 2016, until the earlier of the distribution date and the redemption or expiration of the rights. Each Right allows its holder to purchase from the Company one one-thousandth of a share of Series A Junior Participating Preferred Stock In June 2016 Resolute filed a certificate of amendment to its certificate of incorporation to effect the previously-announced reverse stock split of the Company’s common stock, par value $0.0001 per share, at a ratio of 1-for-5 (the “Reverse Stock Split”). The certificate of amendment also reduced the number of authorized shares of common stock from 225,000,000 to 45,000,000. The Reverse Stock Split, including the certificate of amendment, was approved by stockholders at the Company’s 2016 annual meeting of stockholders and by the Company’s Board of Directors. As a result, the Company is now in compliance with the $1.00 per share minimum price requirement of the New York Stock Exchange (the “NYSE”). All historical share amounts disclosed have been retroactively adjusted to reflect this Reverse Stock Split. During the fourth quarter 2016, the Company issued 4.4 million shares of common stock in a public offering at $38.00 per share for net proceeds of $160.9 million, after deducting fees and estimated expenses. The net proceeds were used to repay outstanding borrowings under the Secured Term Loan Facility and Revolving Credit Facility. Long-Term Employee Incentive Plan The Company accounts for share-based compensation in accordance with FASB ASC Topic 718, Stock Compensation In July 2009 the Company adopted the 2009 Long Term Performance Incentive Plan (“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 3,451,548 (which includes the additional 620,000 shares under Amendment No. 2 to the incentive plan approved by the Company’s stockholders in June 2015 and the 1,000,000 share under Amendment No. 3 in the incentive plan approved by the Company’s stockholders in May 2016). In May 2015 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 $6.75 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. In September 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 $2.10 per share and a ten year term. In February 2016 the Board and its Compensation Committee 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 with a ten-year term, vesting in three equal annual installments on March 8 of 2017, 2018 and 2019 for employees and one installment on March 8, 2017, for non-employee directors, (ii) cash-settled stock appreciation rights with a ten-year term, vesting in three equal annual installments on March 8 of 2017, 2018 and 2019 for employees and in one installment on March 8 of 2017 for non-employee directors, (iii) time-vested restricted cash awards, vesting in three equal annual installments on March 8 of 2017, 2018 and 2019, and (iv) restricted stock vesting on March 8, 2017. For the years ended December 31, 2016, 2015 and 2014, the Company recorded expense related to the Incentive Plan as follows (in thousands): Year Ended December 31, 2016 2015 2014 Time-based restricted stock awards $ 4,359 $ 9,067 $ 12,101 TSR awards 996 2,848 3,990 Stock appreciation awards — 45 240 Stock option awards 936 365 — Time-based restricted cash awards 3,409 959 — Performance-based restricted cash awards 13,780 225 — Cash-settled stock appreciation awards 17,737 — — Total Incentive Plan compensation expense $ 41,217 $ 13,509 $ 16,331 As of December 31, 2016, 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 Time-based restricted stock awards $ 926 0.7 TSR awards 666 0.2 Stock option awards 1,723 1.9 Total unrecognized compensation expense $ 3,315 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 estimated forfeiture rates between 0% and 15%, no dividends, expected stock price volatility ranging from 63% to 67% and a risk free rate ranging between 1.75% and 2.27%. The following table summarizes the changes in non-vested option awards for the period presented: 2016 Weighted Average Aggregate Weighted Remaining Intrinsic Average Contractual Value Shares Exercise Price Term (in thousands) Outstanding, beginning of period 396,440 $ 6.40 Granted 741,450 2.80 Exercised (22,777 ) 5.77 Forfeited (62,600 ) 3.79 Outstanding, end of period 1,052,513 $ 4.03 8.9 $ 39,110 Exercisable, end of period 106,513 $ 6.53 8.4 $ 3,692 The weighted average grant date fair value of options granted during the years ended December 31, 2016 and 2015 was $1.93 and $4.60, respectively. The total intrinsic value for options exercised during the year ended December 31, 2016, was $0.5 million. No options were exercised during the year ended December 31, 2015, and therefore, there is no related intrinsic value. Time-Based Restricted Stock Awards Shares of time-based restricted stock issued to employees generally vest in three equal annual installments at specified dates based on continued employment. Shares issued to non-employee directors vest in one year based on continued service. 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 15% which are updated periodically based on actual employee turnover. During the year ended December 31, 2016, the Company granted 92,648 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 period presented: 2016 Weighted Average Grant Date Shares Fair Value Non-vested, beginning of period 285,704 $ 42.10 Granted 92,648 4.48 Vested (196,680 ) 41.26 Forfeited (29,891 ) 17.46 Non-vested, end of period 151,781 $ 25.07 The weighted average grant date fair value of shares granted during the years ended December 31, 2016, 2015 and 2014 was $4.48, $6.75 and $44.30, respectively. 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. 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 and 2014, 51,532 and 31,359 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. At December 31, 2016, no stock appreciation awards remain outstanding. TSR Awards In 2014 the Compensation Committee and Board awarded performance-based restricted shares 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 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 2014 39.4% 0% 0.69% The following table summarized changes in non-vested TSR Awards for the period presented: 2016 Weighted Average Grant Date Shares Fair Value Non-vested, beginning of period 152,916 $ 71.29 Granted — — Vested — — Forfeited (55,355 ) 79.55 Non-vested, end of period 97,561 $ 66.60 There were no TSR awards granted in the years ended December 31, 2016 and 2015. The weighted average fair grant date fair value of TSR awards granted during the yar ended December 31, 2014 was $66.60. Liability Awards Liability awards consist of awards that are settled in cash instead of shares, as discussed below. Cash-settled Stock Appreciation Rights A stock appreciation right is the right to receive an amount in cash equal to the excess, if any, of the fair market value of a share of common stock on the date on which the right is exercised over its base price. The February 2016 grants of cash-settled stock appreciation rights hold base prices of $2.65 per share (as to 486,373 rights) and $2.915 per share (as to 1,216,479 rights). The awards granted to employees vest in three equal annual installments and have a ten-year term. The awards granted to non-employee directors vest in one year based on continued service and also have a ten-year term. The compensation expense to be recognized for the cash-settled stock appreciation rights was measured utilizing estimated forfeiture rates between 0% and 15% which will be updated periodically based on actual employee turnover. The fair value of the cash-settled stock appreciation rights as of December 31, 2016, was $64.5 million, of which $17.7 million has been expensed. 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 vests in one year based on continued service. The compensation expense to be recognized for the time-based restricted cash awards was measured utilizing estimated forfeiture rates between 0% and 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, 2016, was $9.9 million, of which $4.4 million has been expensed. 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 was at $10.00 at which the award would be payable at 1x, and the highest stock price hurdle would be $40.00 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. As of December 31, 2016, the $10.00, $13.00, $16.00, $19.00, $22.00, $25.00, $28.00 and $31.00 stock price hurdles had been met. Subsequent to December 31, 2016, the remaining stock price hurdles up to $40.00 were also met. The performance-based cash awards have a ten year term ( i.e. The estimated fair value of the performance-based restricted cash awards as of December 31, 2016 was $16.4 million of which $13.1 million has been expensed 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 less than one year. 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, 2016
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 and facilities 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, 2016 2015 Asset retirement obligations at beginning of period $ 19,238 $ 31,340 Additional liability incurred / acquired 587 96 Accretion expense 1,790 2,740 Liabilities settled / sold (1,088 ) (15,177 ) Revisions to previous estimates (175 ) 239 Asset retirement obligations at end of period 20,352 19,238 Less: current asset retirement obligations (895 ) (891 ) Long-term asset retirement obligations $ 19,457 $ 18,347

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2016
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, 2016, the fair value of the Company’s commodity derivatives was a net liability of $11.9 million (Level 2 fair value measurement). The following table represents Resolute’s commodity swap contracts as of December 31, 2016: Oil (NYMEX WTI) Gas (NYMEX Henry Hub) NGL (Mont Belvieu) Remaining Term Bbl per Day Weighted Average Swap Price per Bbl MMBtu per Day Weighted Average Swap Price per MMBtu Bbl per Day Weighted Average Swap Price per Bbl Jan – Dec 2017 1,528 $ 51.10 2,008 $ 2.807 300 $ 19.53 The following table represents Resolute’s two-way commodity collar contracts as of December 31, 2016: Oil (NYMEX WTI) Gas (NYMEX Henry Hub) Remaining Term Bbl per Day Weighted Average Floor Price per Bbl Weighted Average Ceiling Price per Bbl MMBtu per Day Weighted Average Floor Price per MMBtu Weighted Average Ceiling Price per MMBtu Jan – Dec 2017 3,684 $ 46.80 $ 57.63 8,080 $ 2.566 $ 3.433 The following table represents Resolute’s three-way oil collar contracts as of December 31, 2016: Oil (NYMEX WTI) Remaining Term Bbl per Day Weighted Average Short Put Price per Bbl Weighted Average Floor Price per Bbl Weighted Average Ceiling Price per Bbl Jan – Dec 2017 1,130 $ 40.00 $ 50.00 $ 60.10 The following table represents Resolute’s three-way gas collar contracts as of December 31, 2016: Gas (NYMEX Henry Hub) Remaining Term MMBtu per Day Weighted Average Short Put Price per MMBtu Weighted Average Floor Price per MMBtu Weighted Average Ceiling Price per MMBtu Jan – Dec 2017 1,505 $ 2.692 $ 3.192 $ 3.746 The following table represents Resolute’s commodity option contract as of December 31, 2016: Oil (NYMEX WTI) Remaining Term Bbl per Day Sold Call Price Jan – Dec 2018 1,100 $ 50.00 Subsequent to December 31, 2016, Resolute entered into additional commodity derivative contracts as summarized below: Oil (NYMEX WTI) Commodity Swap Bbl per Day Weighted Apr – June 2017 1,000 $ 55.45 July – Dec 2017 1,000 $ 56.30 July – Dec 2017 1,000 $ 56.50 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, 2016 and 2015. The table below summarizes the location and amount of commodity derivative instrument gains and losses reported in the consolidated statements of income (in thousands): 2016 2015 2014 Other income (expense): Commodity derivative settlements $ 88,010 $ 93,150 $ (4,988 ) Mark-to-market gain (loss) (107,794 ) (16,658 ) 123,129 Commodity derivative instruments gain (loss) $ (19,784 ) $ 76,492 $ 118,141 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 current or former 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. As all of the derivative contracts were in a net liability position as of December 31, 2016, the maximum amount of loss in the event of all counterparties defaulting is $0.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2016
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, 2016, 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, 2016, and December 31, 2015 (in thousands): Level 2 December 31, 2016 December 31, 2015 Assets Derivative instruments, current $ 218 $ 92,431 Derivative instruments, long term — 3,463 Total assets $ 218 $ 95,894 Liabilities Derivative instruments, current $ 8,014 $ — Derivative instruments, long term 4,104 — Total liabilities $ 12,118 $ —

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2016
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 2017 5,671 2018 5,671 Total $ 11,342 The terms of the CO 2 2 2 Operating Leases Rental payments expensed under operating leases for office facilities were approximately $3.0 million, $1.1 million and $1.6 million during 2016, 2015 and 2014, respectively. Net rental payments expensed under operating leases for compressors and other oilfield equipment were approximately $1.7 million, $1.9 million and $2.6 million during 2016, 2015 and 2014, respectively. Future payments for the Company’s office facilities, equipment leases and vehicle leases under these operating lease agreements, as of December 31, 2016, are as follows (in thousands): Year Office Lease Rentals Field Equipment Rentals Vehicle Lease Rentals Total 2017 $ 1,892 $ 1,629 $ 383 $ 3,904 2018 1,698 — 73 1,771 2019 1,324 — 2 1,326 2020 and thereafter 3,138 — — 3,138 Total $ 8,052 $ 1,629 $ 458 $ 10,139 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, 2016 and 2015. In 2016, the agreement with ExxonMobil was evaluated as part of the normal course of business. It was determined that the current escrow balance in the account was overfunded. As such, Resolute and NNOGC are due to receive a refund totaling $2.5 million. The Company is required to make additional deposits to the escrow account annually. Resolute must fund payments averaging approximately $0.3 million per year until 2031. Total contributions from the date of acquisition through 2031 will aggregate $17.6 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, 2016, the Company has funded the 2016 annual contractual amount required to meet its future obligation. Cooperative Agreement with Navajo Nation Oil and Gas Company Resolute is party to a cooperative agreement with Navajo Nation Oil and Gas Company (“NNOGC”) related to the Aneth Field Properties (the “Cooperative Agreement”). Pursuant to the Cooperative Agreement, NNOGC holds an option to purchase an additional 10% of Resolute’s interest in the Aneth Field Properties. The option is exercisable in July 2017 at the then-current fair market value of such interest at that time.

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2016
Subsequent Events [Abstract]
Subsequent Events	Note 12 — Subsequent Events Repayment of all amounts outstanding under and termination of the Secured Term Loan Agreement On January 3, 2017, the Company repaid approximately $132 million constituting all amounts due under the Term Loan Facility (including prepayment fees), with a portion of the proceeds from its previously announced common stock offering that closed on December 23, 2016. The Term Loan Facility was terminated in connection with the repayment. Long-term incentive award grant In February 2017, the Board and its Compensation Committee approved long-term incentive awards to employees and non-employee directors for 2017 consisting of a combination of time-vesting restricted stock, performance-vesting shares, and outperformance-vesting shares under the Incentive Plan. The 2017 long-term incentive awards to employees and non-employee directors consisted of grants of (i) 11,556 shares of time-vesting restricted stock to employees vesting in three equal annual installments on February 1 of 2018, 2019 and 2020, (ii) 15,736 shares of time-vesting restricted stock to non-employee directors vesting in one installments on February 7, 2018, (iii) 343,391 shares of time-vesting restricted stock to employees vesting in three equal installments on March 8 of 2018, 2019 and 2020, (iv) 131,391 shares of performance-vesting awards vesting in three equal installments on March 8 of 2018, 2019 and 2020, and (v) 131,379 shares of outperformance awards vesting in three equal installments on March 8 of 2018, 2019 and 2020. Amended and Restated Revolving Credit Facility On February 17, 2017, the Company entered into the Third Amended and Restated Credit Agreement with a syndicate of banks led by Bank of Montreal, as Administrative Agent, Capital One, National Association, as syndication agent, and Barclays Bank PLC, ING Capital LLC and SunTrust Bank, as co-documentation agents. In connection with entering into the Revolving Credit Facility, the Company repaid all amounts outstanding under the Second Amended and Restated Credit Agreement, dated as of April 15, 2015, by and among Resolute Energy Corporation, as Borrower, certain subsidiaries of Resolute Energy Corporation, as Guarantors, Wells Fargo Bank, National Association, as administrative agent, and the lenders party thereto, as amended, and terminated that agreement. The Revolving Credit Facility is guaranteed by all of our subsidiaries and is collateralized by substantially all of the assets of the Company’s Aneth Field and Delaware Basin assets held by Resolute Aneth, LLC and Resolute Natural Resources Southwest, LLC, which are wholly-owned subsidiaries of the Company. The Revolving Credit Facility specifies a maximum borrowing base as determined by the lenders in their sole discretion, which has initially been set at $150 million. The borrowing base is re-determined semi-annually, and the amount available for borrowing under the Revolving Credit Facility could be increased or decreased as a result of such redeterminations. Under certain circumstances, either the Company or the lenders may request an interim redetermination of the borrowing base. The Revolving Credit Facility matures in February 2021, unless there is an earlier maturity of material Company indebtedness. Each borrowing under the Revolving Credit Facility accrues interest at either (a) the London Interbank Offered Rate (“LIBOR”), plus a margin that ranges from 3.0% to 4.0% or (b) the Alternate 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 LIBOR, plus a margin for the Alternate Base Rate that ranges from 2.0% to 3.0%. Each such margin is based on the level of utilization under the borrowing base. The Revolving Credit Facility includes covenants that require, among other things, that Resolute maintains a ratio of current assets to current liabilities of no less than 1.0 to 1.0 and a ratio of funded debt to EBITDA of no more than 4.0 to 1.0. The Revolving Credit Facility prohibits us from entering into derivative arrangements for more than (i) 85% of our anticipated production from proved properties in the next 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 (not to exceed a term of 60 months for any such derivative arrangement). The Revolving Credit Facility also includes customary additional terms and covenants that place limitations on certain types of activities, the payment of dividends, and that require satisfaction of certain financial tests. Divestiture of Southeast New Mexico Properties in the Permian Basin On February 22, 2017 the Company closed on the sale of its Denton and South Knowles properties in the Northwest Shelf project area in Lea County, New Mexico, for approximately $14.5 million, subject to customary purchase price adjustments (the “New Mexico Sale”). The effective date of this sale is October 1, 2016. The proceeds of the sale will be used to reduce amounts outstanding under the Company’s Revolving Credit Facility or for other corporate purposes. Declaration of Preferred Dividend On January 15, 2017, the Company declared a dividend in the amount of $1.4 million on its Preferred Stock, which was paid out to preferred shareholders on January 17, 2017. Delaware Basin Orla Acquisition Purchase and Sale Agreement On March 3, 2017, Resolute Natural Resources Southwest, LLC (“Buyer”), a wholly-owned subsidiary of the Company, entered into a Purchase and Sale Agreement (the “Purchase Agreement”) with undisclosed private sellers (“Sellers”) pursuant to which Buyer agreed to acquire certain producing and undeveloped oil and gas properties in the Delaware Basin in Reeves County, Texas (the “Delaware Basin Orla Acquisition”). Consideration for the acquisition will be $160 million in cash, subject to customary purchase price adjustments. The closing of the acquisition is expected to occur on or about May 15, 2017 and is subject to the satisfaction or waiver of certain customary conditions, including the material accuracy of the representations and warranties of Buyer and Sellers, and performance of covenants. The Delaware Basin Orla Acquisition has an effective date of May 1, 2017. The Purchase Agreement contains terms and conditions customary to transactions of this type. Subject to the right of Buyer to be indemnified for certain liabilities for a limited period of time and for breaches of representations, warranties and covenants, Buyer will assume substantially all liabilities associated with the acquired properties. The Purchase Agreement also contains certain customary termination rights for each of Buyer and Sellers. The properties to be acquired include approximately 4,600 net acres in Reeves County, Texas, consisting of 2,187 net acres adjacent to the Company’s existing operating area in Reeves County and 2,405 net acres in southern Reeves County. In addition, the Company will acquire interests in (i) two operated 4,500 foot lateral horizontal Wolfcamp wells that currently produce approximately 800 net Boe per day, (ii) six operated drilled but uncompleted Wolfcamp wells, four of which have lateral lengths of approximately 4,500 feet and two with approximately 7,500 foot laterals; and (iii) one non-operated 10,000 foot lateral Wolfcamp A well that is currently drilling. Commitment Letter The Company is evaluating the optimal financing for the Delaware Basin Orla Acquisition, and anticipates that the ultimate financing may have components of long-term debt and equity. In the interim, however, the Company entered into a commitment letter on March 3, 2017 for a $100 million unsecured bridge financing facility with BMO Capital Markets (the “Commitment Letter”). The Commitment Letter provides the Company with the ability to borrow up to $100 million, subject to satisfaction or waiver of customary conditions to closing, for the consummation of the Delaware Basin Orla Acquisition. In the event that the Bridge Commitment is not drawn in connection with the Delaware Basin Orla Acquisition, then the obligations of the parties under the Commitment Letter terminate. Together with borrowing availability under the Company’s Revolving Credit Facility, the bridge facility allows the Company to close the acquisition without an immediate long-term debt or equity issuance.

Supplemental Oil and Gas Inform

Supplemental Oil and Gas Information	12 Months Ended
	Dec. 31, 2016
Extractive Industries [Abstract]
Supplemental Oil and Gas Information	Note 13 — Supplemental Oil and Gas Information (unaudited) Costs Incurred in Oil and Gas Property Acquisition, Exploration, and Development Activities Costs incurred during 2016, 2015 and 2014 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): 2016 2015 2014 Acquisition costs Proved $ 41,830 $ — $ — Unproved 120,851 6,583 7,007 Exploration costs 101,719 13,764 111,769 Development costs* 31,057 39,883 50,291 Total $ 295,457 $ 60,230 $ 169,067 * Includes $5.9 million, $8.9 million and $16.3 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, 2016 and December 31, 2015 were as follows (in thousands): 2016 2015 Proved oil and gas properties $ 1,889,111 $ 1,732,707 Unevaluated oil and gas properties, not subject to amortization 121,375 21,264 Accumulated depletion, depreciation and amortization (1,640,279 ) (1,534,479 ) Oil and gas properties, net $ 370,207 $ 219,492 Oil and Gas Reserve Quantities The reserve data as of December 31, 2016, 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, 2014 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 (3) (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 Purchase of minerals in place 1,492 5,810 863 3,323 Production (3,821 ) (4,811 ) (559 ) (5,182 ) Extensions, discoveries and other additions (2) 21,427 41,151 6,257 34,543 Sales of minerals in place — — — — Revisions of previous estimates (3) (4,042 ) (3,562 ) (900 ) (5,537 ) Proved reserves as of December 31, 2016 43,804 52,448 7,722 60,267 Proved developed reserves: As of December 31, 2016 30,026 24,209 3,595 37,656 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 Proved undeveloped reserves: As of December 31, 2016 13,778 28,238 4,127 22,611 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 1) 2) Extensions, discoveries and other additions in 2016 are largely due to the Reeves County drilling program which, together with the acquisition of additional interests in Mustang, resulted in 14.8 MMBoe added to net proved developed producing from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 17.9 MMBoe net reserves. Additionally, 4.5 MMBoe of net proved developed non-producing and proved undeveloped reserves were added to Aneth Field in connection with newly identified compression and well deepening projects. 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 from drilling proved locations, plus an additional 970 MBoe from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 3.6 MMBoe reserves. 3) Decreases in proved reserves associated with revisions of previous estimates resulted primarily from reduced product pricing. 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, 2016. 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, 2016. 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 (based on the first day of the month) 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, 2016 2015 2014 (in thousands) Future cash inflows $ 1,800,000 $ 1,293,000 $ 5,858,000 Future production costs (934,000 ) (774,000 ) (2,719,000 ) Future development costs (288,000 ) (180,000 ) (1,008,000 ) Future income taxes (1,000 ) — (412,000 ) Future net cash flows 577,000 339,000 1,719,000 10% annual discount for estimated timing of cash flows (233,000 ) (140,000 ) (886,000 ) Standardized measure of discounted future net cash flows $ 344,000 $ 199,000 $ 833,000 The principal sources of change in the standardized measure of discounted future net cash flows are: December 31, 2016 2015 2014 (in thousands) Standardized measure, beginning of year $ 199,000 $ 833,000 $ 893,000 Sales of oil and gas produced, net of production costs (82,000 ) (181,000 ) (196,000 ) Net changes in prices and production costs (106,000 ) (917,000 ) (191,000 ) Purchases of minerals in place 10,000 — — Sales of minerals in place — (134,000 ) (6,000 ) Previously estimated development costs incurred during the year 22,000 33,000 49,000 Extensions, discoveries and improved recovery 268,000 13,000 207,000 Changes in estimated future development costs 12,000 119,000 (13,000 ) Revisions of previous quantity estimates (3,000 ) 196,000 (16,000 ) Accretion of discount 20,000 70,000 89,000 Net change in income taxes — 104,000 44,000 Changes in timing and other 4,000 63,000 (27,000 ) Standardized measure, end of year $ 344,000 $ 199,000 $ 833,000

Quarterly Financial Data

Quarterly Financial Data	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Data	Note 14 — Quarterly Financial Data (unaudited) The following is a summary of the unaudited financial data for each quarter for the years ended December 31, 2016 and 2015 (in thousands except per share data): Three Months Ended March 31, June 30, September 30, December 31, 2016 2016 2016 2016 Year Ended December 31, 2016 Revenue $ 19,002 $ 35,390 $ 47,419 $ 62,667 Operating expenses (95,086 ) (39,767 ) (57,089 ) (64,042 ) Loss from operations (76,084 ) (4,377 ) (9,670 ) (1,375 ) Net Loss (85,312 ) (36,906 ) (18,856 ) (20,648 ) Loss per common share: Basic and Diluted $ (5.65 ) $ (2.44 ) $ (1.24 ) $ (1.23 ) Weighted average common shares outstanding: Basic and Diluted 15,036 15,155 15,173 17,690 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 ) Loss from operations (244,336 ) (221,895 ) (216,867 ) (93,606 ) Net Loss (208,222 ) (259,107 ) (182,770 ) (92,180 ) Loss per common share: Basic and Diluted $ (14.00 ) $ (17.30 ) $ (12.20 ) $ (6.15 ) Weighted average common shares outstanding: Basic and Diluted 14,857 14,965 14,971 14,979

Basis of Presentation and Sum21

Basis of Presentation and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
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 condensed 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 condensed 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; cash-settled long-term incentive 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 (defined in Note 5) has a recorded value that approximates its fair market value. The fair value of $123.4 million under the second lien secured term loan due March 2018 (the “Secured Term Loan Facility”) approximates the principal less the unamortized discount. Lastly, the fair value of $407.3 million under the senior notes due May 1, 2020 (the “Senior Notes” or the “Notes”) is 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, 2016 2015 Trade receivables $ 14,898 $ 14,224 Revenue receivables 32,817 12,967 Derivative receivables 5,695 9,759 Other receivables 1,818 150 Total accounts receivable $ 55,228 $ 37,100 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, 2016 and 2015, the Company had no allowance for doubtful accounts recorded.
Deferred Financing Costs	Deferred Financing Costs Deferred financing costs are amortized over the estimated life of the related obligation and it is our policy to net these costs against the related debt. The Company incurred $0 in deferred financing costs in 2016, $0 in 2015 and $4.8 million in 2014, and amortized $3.1 million, $5.0 million and $2.5 million to interest expense during 2016, 2015 and 2014, 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 $4.1 million, $6.0 million and $14.9 million during 2016, 2015 and 2014, 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 47%, 27% and 13% of its total 2016 revenue from Western Refining, Inc. (“Western”), Plains Marketing LP and Holly Frontier LLC, respectively; 58% and 14% of its total 2015 revenue from Western and Holly Frontier LLC, respectively and 62% and 14% of its total 2014 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 counterparties are current or former lenders under Resolute’s Revolving Credit Facility (defined in 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 $5.7 million during 2016, $6.3 million during 2015 and $9.8 million during 2014. 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 play in the Delaware Basin in Texas. The Company expects to evaluate these locations for the existence of proved reserves in the next two years, although volatility in commodity prices may affect 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 2016, 2015 and 2014, the Company recorded $58 million, $705 million and $120 million, respectively, non-cash impairments 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, 2016, 2015 and 2014.
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 $23.1 million located on the Company’s consolidated balance sheet in non-current other assets at December 31, 2016, is contractually 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.
Long-term Employee Incentive Expense	Long-term Employee Incentive 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). Cash-settled incentive award expense is measured quarterly using a cash-or-nothing valuation model. The Company estimates forfeitures in calculating the cost related to share-based compensation and cash-settled incentive awards expense 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 company early adopted Accounting Standards Update (ASU) No. 2016-09, Compensation - Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting.
Recent Accounting Pronouncements	Recent Accounting Pronouncements In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers, In May 2016, the FASB issued ASU 2016-12 : Revenue from Contracts with Customers (Topic 606): Narrow Scope Improvements and Practical Expedients In February 2016 the FASB issued new authoritative guidance related to the accounting of leases. The main provisions require that lessees recognize both a lease liability and a right-of-use asset at the commencement date. This authoritative accounting guidance is effective for the annual period beginning after December 15, 2018, and interim periods within annual periods beginning after December 15, 2018. The Company is currently evaluating the provisions of this guidance and assessing its impact on the Company’s financial statements and disclosures.

Basis of Presentation and Sum22

Basis of Presentation and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Accounts Receivable	The Company’s accounts receivable consist of the following for the periods indicated (in thousands): December 31, 2016 2015 Trade receivables $ 14,898 $ 14,224 Revenue receivables 32,817 12,967 Derivative receivables 5,695 9,759 Other receivables 1,818 150 Total accounts receivable $ 55,228 $ 37,100

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2016
Business Combinations [Abstract]
Purchase Price Allocation of Delaware Basin Firewheel Acquisitions	The Company has completed its assessment of the fair values of the assets acquired and liabilities assumed. Accordingly, the following table presents the purchase price allocation of the Delaware Basin Firewheel Acquisition at December 31, 2016, based on the fair values of assets acquired and liabilities assumed (in thousands): 2016 Proved oil and gas properties $ 40,900 Unproved oil and gas properties 112,800 Asset retirement obligations assumed (500 ) Total purchase price $ 153,200
Unaudited Pro Forma Financial Information on Properties Acquired and Sold	The unaudited pro forma financial information for the years ended December 31, 2016 and 2015, respectively, reflects Resolute’s results as if the Delaware Basin Firewheel Acquisition and the sale of the Delaware Basin Midstream Assets, Gardendale, Hilight Field, and Howard and Martin County properties had occurred on January 1, 2015 (in thousands, except per share amounts): Year ended December 31, 2016 2015 Revenue $ 171,195 $ 131,520 Loss from operations (93,411 ) (778,268 ) Net loss available to common stockholders (165,397 ) (733,119 ) Basic and diluted net income (loss) per share $ (10.49 ) $ (42.87 )

Earnings per Share (Tables)

Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2016
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, 2016 2015 2014 Potential dilutive restricted stock 1,112 356 595 Anti-dilutive securities 3,365 980 5,505
Computation of Basic and Diluted Net Income (Loss) per Share of Common Stock	The following table sets forth the 2016, 2015 and 2014 computation of basic and diluted net income (loss) per share of common stock for the periods presented (in thousands, except per share amounts): 2016 2015 2014 Net loss available to common stockholders $ (162,907 ) $ (742,279 ) $ (21,850 ) Basic weighted average common shares outstanding 15,767 14,986 14,760 Add: dilutive effect of non-vested restricted stock — — — Diluted weighted average common shares outstanding 15,767 14,986 14,760 Basic and diluted net loss per common share $ (10.33 ) $ (49.55 ) $ (1.50 )

Long Term Debt (Tables)

Long Term Debt (Tables)	12 Months Ended
	Dec. 31, 2016
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, 2016 Revolving credit facility $ 10,000 $ — $ (1,179 ) $ 8,821 Secured term loan facility 128,303 (4,882 ) (1,282 ) 122,139 8.50% senior notes 400,000 985 (3,831 ) 397,154 Total $ 538,303 $ (3,897 ) $ (6,292 ) $ 528,114 Current portion of secured term loan facility 128,303 (4,882 ) (1,282 ) 122,139 Long-term debt $ 410,000 $ 985 $ (5,010 ) $ 405,975 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

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Components of Provision for Income Taxes	The following table summarizes the components of the provision for income taxes (in thousands): 2016 2015 2014 Current income tax (expense) $ (91 ) $ — $ — Deferred income tax benefit — 22,354 4,140 Total income tax benefit (expense) $ (91 ) $ 22,354 $ 4,140
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, 2016, 2015 and 2014 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): 2016 2015 2014 Expected statutory income tax benefit $ 56,571 $ 267,621 $ 9,097 State income tax benefit 3,087 13,394 480 Equity compensation (2,761 ) (4,822 ) (4,273 ) Non-deductible executive compensation (690 ) — (468 ) Valuation allowance (56,005 ) (253,592 ) — Other (293 ) (247 ) (696 ) Total income tax benefit (expense) $ (91 ) $ 22,354 $ 4,140
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, 2016 2015 Deferred income tax assets (liabilities): Derivative financial instruments 4,403 (35,481 ) Net operating loss carryovers 206,663 183,964 Asset retirement obligation 7,530 7,118 Startup and organization costs 104 122 Deferred acquisition costs 45 45 Percentage depletion 1,335 1,360 Property and equipment costs 75,267 91,937 Equity compensation 2,267 3,342 Other 11,983 1,185 Valuation allowance (309,597 ) (253,592 ) Total long term assets (liabilities) — — Net deferred tax asset (liability) $ — $ —

Stockholders' Equity and Equi27

Stockholders' Equity and Equity Based Awards (Tables)	12 Months Ended
	Dec. 31, 2016
Expense Related to Incentive Plan	For the years ended December 31, 2016, 2015 and 2014, the Company recorded expense related to the Incentive Plan as follows (in thousands): Year Ended December 31, 2016 2015 2014 Time-based restricted stock awards $ 4,359 $ 9,067 $ 12,101 TSR awards 996 2,848 3,990 Stock appreciation awards — 45 240 Stock option awards 936 365 — Time-based restricted cash awards 3,409 959 — Performance-based restricted cash awards 13,780 225 — Cash-settled stock appreciation awards 17,737 — — Total Incentive Plan compensation expense $ 41,217 $ 13,509 $ 16,331
Unrecognized Compensation Expense and Weighted Average Period Related to Incentive Plan	As of December 31, 2016, 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 Time-based restricted stock awards $ 926 0.7 TSR awards 666 0.2 Stock option awards 1,723 1.9 Total unrecognized compensation expense $ 3,315
Changes in Non-Vested Stock Option Awards	The following table summarizes the changes in non-vested option awards for the period presented: 2016 Weighted Average Aggregate Weighted Remaining Intrinsic Average Contractual Value Shares Exercise Price Term (in thousands) Outstanding, beginning of period 396,440 $ 6.40 Granted 741,450 2.80 Exercised (22,777 ) 5.77 Forfeited (62,600 ) 3.79 Outstanding, end of period 1,052,513 $ 4.03 8.9 $ 39,110 Exercisable, end of period 106,513 $ 6.53 8.4 $ 3,692
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 2014 39.4% 0% 0.69%
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 period presented: 2016 Weighted Average Grant Date Shares Fair Value Non-vested, beginning of period 285,704 $ 42.10 Granted 92,648 4.48 Vested (196,680 ) 41.26 Forfeited (29,891 ) 17.46 Non-vested, end of period 151,781 $ 25.07
TSR awards
Changes in Non-Vested Awards	The following table summarized changes in non-vested TSR Awards for the period presented: 2016 Weighted Average Grant Date Shares Fair Value Non-vested, beginning of period 152,916 $ 71.29 Granted — — Vested — — Forfeited (55,355 ) 79.55 Non-vested, end of period 97,561 $ 66.60

Asset Retirement Obligation (Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2016
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, 2016 2015 Asset retirement obligations at beginning of period $ 19,238 $ 31,340 Additional liability incurred / acquired 587 96 Accretion expense 1,790 2,740 Liabilities settled / sold (1,088 ) (15,177 ) Revisions to previous estimates (175 ) 239 Asset retirement obligations at end of period 20,352 19,238 Less: current asset retirement obligations (895 ) (891 ) Long-term asset retirement obligations $ 19,457 $ 18,347

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2016
Derivative [Line Items]
Commodity Contracts and Swaps	The following table represents Resolute’s commodity option contract as of December 31, 2016: Oil (NYMEX WTI) Remaining Term Bbl per Day Sold Call Price Jan – Dec 2018 1,100 $ 50.00
Summary of Subsequent Additional Commodity Derivative Contracts	Subsequent to December 31, 2016, Resolute entered into additional commodity derivative contracts as summarized below: Oil (NYMEX WTI) Commodity Swap Bbl per Day Weighted Apr – June 2017 1,000 $ 55.45 July – Dec 2017 1,000 $ 56.30 July – Dec 2017 1,000 $ 56.50
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): 2016 2015 2014 Other income (expense): Commodity derivative settlements $ 88,010 $ 93,150 $ (4,988 ) Mark-to-market gain (loss) (107,794 ) (16,658 ) 123,129 Commodity derivative instruments gain (loss) $ (19,784 ) $ 76,492 $ 118,141
Two Way Commodity Collar Contract
Derivative [Line Items]
Commodity Contracts and Swaps	The following table represents Resolute’s two-way commodity collar contracts as of December 31, 2016: Oil (NYMEX WTI) Gas (NYMEX Henry Hub) Remaining Term Bbl per Day Weighted Average Floor Price per Bbl Weighted Average Ceiling Price per Bbl MMBtu per Day Weighted Average Floor Price per MMBtu Weighted Average Ceiling Price per MMBtu Jan – Dec 2017 3,684 $ 46.80 $ 57.63 8,080 $ 2.566 $ 3.433
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, 2016: Oil (NYMEX WTI) Remaining Term Bbl per Day Weighted Average Short Put Price per Bbl Weighted Average Floor Price per Bbl Weighted Average Ceiling Price per Bbl Jan – Dec 2017 1,130 $ 40.00 $ 50.00 $ 60.10
Three Way Gas Collar Contract
Derivative [Line Items]
Commodity Contracts and Swaps	The following table represents Resolute’s three-way gas collar contracts as of December 31, 2016: Gas (NYMEX Henry Hub) Remaining Term MMBtu per Day Weighted Average Short Put Price per MMBtu Weighted Average Floor Price per MMBtu Weighted Average Ceiling Price per MMBtu Jan – Dec 2017 1,505 $ 2.692 $ 3.192 $ 3.746
Commodity Swap Contracts
Derivative [Line Items]
Commodity Contracts and Swaps	The following table represents Resolute’s commodity swap contracts as of December 31, 2016: Oil (NYMEX WTI) Gas (NYMEX Henry Hub) NGL (Mont Belvieu) Remaining Term Bbl per Day Weighted Average Swap Price per Bbl MMBtu per Day Weighted Average Swap Price per MMBtu Bbl per Day Weighted Average Swap Price per Bbl Jan – Dec 2017 1,528 $ 51.10 2,008 $ 2.807 300 $ 19.53

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2016
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, 2016, and December 31, 2015 (in thousands): Level 2 December 31, 2016 December 31, 2015 Assets Derivative instruments, current $ 218 $ 92,431 Derivative instruments, long term — 3,463 Total assets $ 218 $ 95,894 Liabilities Derivative instruments, current $ 8,014 $ — Derivative instruments, long term 4,104 — Total liabilities $ 12,118 $ —

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2016
Commitments And Contingencies Disclosure [Abstract]
Future Minimum CO2 Purchase Commitments	Future minimum CO 2 CO 2 Year Commitments 2017 5,671 2018 5,671 Total $ 11,342
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, 2016, are as follows (in thousands): Year Office Lease Rentals Field Equipment Rentals Vehicle Lease Rentals Total 2017 $ 1,892 $ 1,629 $ 383 $ 3,904 2018 1,698 — 73 1,771 2019 1,324 — 2 1,326 2020 and thereafter 3,138 — — 3,138 Total $ 8,052 $ 1,629 $ 458 $ 10,139

Supplemental Oil and Gas Info32

Supplemental Oil and Gas Information (Tables)	12 Months Ended
	Dec. 31, 2016
Extractive Industries [Abstract]
Costs Incurred in Oil and Gas Property Acquisition Exploration and Development Activities	Costs incurred during 2016, 2015 and 2014 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): 2016 2015 2014 Acquisition costs Proved $ 41,830 $ — $ — Unproved 120,851 6,583 7,007 Exploration costs 101,719 13,764 111,769 Development costs* 31,057 39,883 50,291 Total $ 295,457 $ 60,230 $ 169,067 * Includes $5.9 million, $8.9 million and $16.3 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, 2016 and December 31, 2015 were as follows (in thousands): 2016 2015 Proved oil and gas properties $ 1,889,111 $ 1,732,707 Unevaluated oil and gas properties, not subject to amortization 121,375 21,264 Accumulated depletion, depreciation and amortization (1,640,279 ) (1,534,479 ) Oil and gas properties, net $ 370,207 $ 219,492
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, 2014 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 (3) (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 Purchase of minerals in place 1,492 5,810 863 3,323 Production (3,821 ) (4,811 ) (559 ) (5,182 ) Extensions, discoveries and other additions (2) 21,427 41,151 6,257 34,543 Sales of minerals in place — — — — Revisions of previous estimates (3) (4,042 ) (3,562 ) (900 ) (5,537 ) Proved reserves as of December 31, 2016 43,804 52,448 7,722 60,267 Proved developed reserves: As of December 31, 2016 30,026 24,209 3,595 37,656 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 Proved undeveloped reserves: As of December 31, 2016 13,778 28,238 4,127 22,611 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 1) 2) Extensions, discoveries and other additions in 2016 are largely due to the Reeves County drilling program which, together with the acquisition of additional interests in Mustang, resulted in 14.8 MMBoe added to net proved developed producing from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 17.9 MMBoe net reserves. Additionally, 4.5 MMBoe of net proved developed non-producing and proved undeveloped reserves were added to Aneth Field in connection with newly identified compression and well deepening projects. 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 from drilling proved locations, plus an additional 970 MBoe from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 3.6 MMBoe reserves. 3) Decreases in proved reserves associated with revisions of previous estimates resulted primarily from reduced product pricing.
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, 2016 2015 2014 (in thousands) Future cash inflows $ 1,800,000 $ 1,293,000 $ 5,858,000 Future production costs (934,000 ) (774,000 ) (2,719,000 ) Future development costs (288,000 ) (180,000 ) (1,008,000 ) Future income taxes (1,000 ) — (412,000 ) Future net cash flows 577,000 339,000 1,719,000 10% annual discount for estimated timing of cash flows (233,000 ) (140,000 ) (886,000 ) Standardized measure of discounted future net cash flows $ 344,000 $ 199,000 $ 833,000
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, 2016 2015 2014 (in thousands) Standardized measure, beginning of year $ 199,000 $ 833,000 $ 893,000 Sales of oil and gas produced, net of production costs (82,000 ) (181,000 ) (196,000 ) Net changes in prices and production costs (106,000 ) (917,000 ) (191,000 ) Purchases of minerals in place 10,000 — — Sales of minerals in place — (134,000 ) (6,000 ) Previously estimated development costs incurred during the year 22,000 33,000 49,000 Extensions, discoveries and improved recovery 268,000 13,000 207,000 Changes in estimated future development costs 12,000 119,000 (13,000 ) Revisions of previous quantity estimates (3,000 ) 196,000 (16,000 ) Accretion of discount 20,000 70,000 89,000 Net change in income taxes — 104,000 44,000 Changes in timing and other 4,000 63,000 (27,000 ) Standardized measure, end of year $ 344,000 $ 199,000 $ 833,000

Quarterly Financial Data (Table

Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2016
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, 2016 and 2015 (in thousands except per share data): Three Months Ended March 31, June 30, September 30, December 31, 2016 2016 2016 2016 Year Ended December 31, 2016 Revenue $ 19,002 $ 35,390 $ 47,419 $ 62,667 Operating expenses (95,086 ) (39,767 ) (57,089 ) (64,042 ) Loss from operations (76,084 ) (4,377 ) (9,670 ) (1,375 ) Net Loss (85,312 ) (36,906 ) (18,856 ) (20,648 ) Loss per common share: Basic and Diluted $ (5.65 ) $ (2.44 ) $ (1.24 ) $ (1.23 ) Weighted average common shares outstanding: Basic and Diluted 15,036 15,155 15,173 17,690 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 ) Loss from operations (244,336 ) (221,895 ) (216,867 ) (93,606 ) Net Loss (208,222 ) (259,107 ) (182,770 ) (92,180 ) Loss per common share: Basic and Diluted $ (14.00 ) $ (17.30 ) $ (12.20 ) $ (6.15 ) Weighted average common shares outstanding: Basic and Diluted 14,857 14,965 14,971 14,979

Basis of Presentation and Sum34

Basis of Presentation and Summary of Significant Accounting Policies - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016USD ($)Segment	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Number of Operating Segments | Segment	1
Allowance for doubtful accounts	$ 0	$ 0
Deferred financing cost	0	0	$ 4,800,000
Deferred financing cost amortization interest expense	3,100,000	5,000,000	2,500,000
Capitalized Interest	4,100,000	6,000,000	14,900,000
Capitalized general and administrative and operating costs	$ 5,700,000	$ 6,300,000	$ 9,800,000
Unproved properties, evaluation time for existence of proved reserves	2 years
Discount factor	10.00%	10.00%	10.00%
Impairment of proved oil and gas properties	$ 58,000,000	$ 705,000,000	$ 120,000,000
Provisions for impairment of long-lived assets other than oil and gas properties	0	$ 0	$ 0
Restricted cash	$ 23,100,000
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	47.00%	58.00%	62.00%
Revenue | Plains Marketing LP | Customer Concentration Risk
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Concentration of credit risk percentage	27.00%		14.00%
Revenue | Holly Frontier LLC | Customer Concentration Risk
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Concentration of credit risk percentage	13.00%	14.00%
Senior Notes
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Long-term debt, fair value	$ 407,300,000
Debt instrument, maturity date	May 1, 2020
Secured term loan facility | Second Lien
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Long-term debt, fair value	$ 123,400,000
Debt instrument, maturity date	Mar. 31, 2018

Accounts Receivable (Detail)

Accounts Receivable (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Receivables [Abstract]
Trade receivables	$ 14,898	$ 14,224
Revenue receivables	32,817	12,967
Derivative receivables	5,695	9,759
Other receivables	1,818	150
Total accounts receivable	$ 55,228	$ 37,100

Acquisitions and Divestitures -

Acquisitions and Divestitures - Additional Information (Detail) - USD ($)	Mar. 10, 2017	Oct. 07, 2016	Aug. 31, 2016	Jul. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Jun. 30, 2016	Oct. 31, 2015	May 31, 2015
Business Disposition [Line Items]
Common stock, par value					$ 0.0001	$ 0.0001	$ 0.0001
Asset Retirement Obligation Liabilities Settled					$ 1,088,000	$ 15,177,000
Firewheel Energy, LLC
Business Disposition [Line Items]
Transaction date					Oct. 4, 2016
Cash consideration		$ 90,000,000
Common stock shares, issued		2,114,523
Common stock, par value		$ 0.0001
Purchase agreement purchase price of properties		$ 153,200,000
Mustang Agreement
Business Disposition [Line Items]
Transaction date					Jul. 31, 2016
Purchase agreement purchase price of properties				$ 35,000,000
Purchase and Sale Agreement with Caprock (Appaloosa Agreement)
Business Disposition [Line Items]
Transaction date					Jul. 31, 2016
Purchase agreement purchase price of properties				$ 15,000,000
Appaloosa And Mustang Agreement
Business Disposition [Line Items]
Transaction date					Aug. 31, 2016
Sale of properties			$ 36,000,000
Sale proceeds held in escrow			2,000,000
Recognized gain (loss) on sale			$ 0
Earn-out Agreement date				Jul. 31, 2016
Period of agreement					15 years
Appaloosa And Mustang Agreement | Scenario, Forecast
Business Disposition [Line Items]
Earn-out agreement amendment date	Mar. 10, 2017
Gardendale Properties
Business Disposition [Line Items]
Transaction date					Dec. 22, 2015
Sale of properties						172,000,000
Purchase and sale agreement, effective date					Sep. 1, 2015
Asset Retirement Obligation Liabilities Settled						5,600,000
Hilight Field
Business Disposition [Line Items]
Transaction date					Oct. 6, 2015
Sale of properties								$ 55,000,000
Purchase and sale agreement, effective date					Jul. 1, 2015
Asset Retirement Obligation Liabilities Settled						8,100,000
Howard and Martin County
Business Disposition [Line Items]
Transaction date					May 1, 2015
Sale of properties									$ 42,000,000
Purchase and sale agreement, effective date					Mar. 1, 2015
Asset Retirement Obligation Liabilities Settled						$ 1,300,000

Purchase Price Allocation of De

Purchase Price Allocation of Delaware Basin Firewheel Acquisitions (Detail) - Delaware Basin Firewheel Acquisition $ in Thousands	Dec. 31, 2016USD ($)
Business Acquisition [Line Items]
Asset retirement obligations assumed	$ (500)
Total purchase price	153,200
Proved oil and gas properties
Business Acquisition [Line Items]
Oil and gas properties	40,900
Unproved oil and gas properties
Business Acquisition [Line Items]
Oil and gas properties	$ 112,800

Unaudited Pro Forma Financial I

Unaudited Pro Forma Financial Information on Properties Acquired and Sold (Detail) - Delaware Basin Firewheel Acquisition and Sale of Delaware Basin Midstream Assets, Gardendale, Hilight Field, and Howard and Martin County Properties - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Revenue	$ 171,195	$ 131,520
Loss from operations	(93,411)	(778,268)
Net loss available to common stockholders	$ (165,397)	$ (733,119)
Basic and diluted net income (loss) per share	$ (10.49)	$ (42.87)

Weighted Average Dilutive and A

Weighted Average Dilutive and Anti-Dilutive Securities (Detail) - shares shares in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Earnings Per Share [Abstract]
Potential dilutive restricted stock	1,112	356	595
Anti-dilutive securities	3,365	980	5,505

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, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Earnings Per Share Diluted [Line Items]
Net loss available to common stockholders									$ (162,907)	$ (742,279)	$ (21,850)
Basic weighted average common shares outstanding									15,767	14,986	14,760
Diluted weighted average common shares outstanding									15,767	14,986	14,760
Basic and diluted net loss per common share	$ (1.23)	$ (1.24)	$ (2.44)	$ (5.65)	$ (6.15)	$ (12.20)	$ (17.30)	$ (14)	$ (10.33)	$ (49.55)	$ (1.50)

Long-term Debt (Detail)

Long-term Debt (Detail) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Principal	$ 538,303,000	$ 528,303,000
Unamortized premium/ (discount)	(3,897,000)	(5,990,000)
Unamortized deferred financing costs	(6,292,000)	(9,439,000)
Total long-term debt	528,114,000	512,874,000
Current portion of secured term loan facility	122,139,000
Principal, noncurrent	410,000,000
Unamortized premium/ (discount), noncurrent	985,000
Unamortized deferred financing costs, noncurrent	(5,010,000)
Long-term debt	405,975,000
Revolving credit facility
Debt Instrument [Line Items]
Principal	10,000,000
Unamortized deferred financing costs	(1,179,000)	(2,121,000)
Total long-term debt	8,821,000
Deferred Finance Costs, Noncurrent, Net		(2,121,000)
Secured term loan facility
Debt Instrument [Line Items]
Principal	128,303,000	128,303,000
Unamortized premium/ (discount)	(4,882,000)	(7,223,000)
Unamortized deferred financing costs	(1,282,000)	(2,136,000)
Total long-term debt	122,139,000	118,944,000
Principal, current	128,303,000
Unamortized premium/ (discount), current	(4,882,000)
Unamortized deferred financing costs, current	(1,282,000)
Current portion of secured term loan facility	122,139,000
8.50% senior notes
Debt Instrument [Line Items]
Principal	400,000,000	400,000,000
Unamortized premium/ (discount)	985,000	1,233,000
Unamortized deferred financing costs	(3,831,000)	(5,182,000)
Total long-term debt	$ 397,154,000	$ 396,051,000

Long-term Debt (Parenthetical)

Long-term Debt (Parenthetical) (Detail)	Dec. 31, 2016	Dec. 31, 2015
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 ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Interest Expense on Long-term debt	$ 50,700,000	$ 70,300,000	$ 46,400,000
Interest expense capitalized	$ 4,100,000	6,000,000	$ 14,900,000
Revolving credit facility
Debt Instrument [Line Items]
Principal		$ 0

Long Term Debt - Revolving Cred

Long Term Debt - Revolving Credit Facility - Additional Information (Detail) - USD ($)	Feb. 17, 2017	Sep. 30, 2016	Dec. 31, 2016	Oct. 31, 2016
Debt Instrument [Line Items]
Line of credit, borrowing base			$ 105,000,000	$ 105,000,000
Revolving credit facility outstanding borrowings			8,821,000
Borrowing base reduced			$ 3,700,000
Borrowing base adjustment period			120 days
Federal Funds Effective Swap Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			0.50%
Minimum | Option A | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			3.00%
Maximum | Option A | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			4.00%
Third Amendment | Subsequent Event
Debt Instrument [Line Items]
Revolving credit facility, maximum borrowing	$ 150,000,000
Revolving credit facility, maturity date	Feb. 28, 2021
Revolving credit facility
Debt Instrument [Line Items]
Revolving Credit Facility covenant description			covenants that require, among other things, that Resolute maintains a ratio of current assets to current liabilities of no less than 1.0 to 1.0 and a ratio of funded debt to EBITDA of no more than 4.0 to 1.0. The Revolving Credit Facility prohibits the Company from entering into derivative arrangements for more than (i) 85% of our anticipated production from proved properties in the next 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 (not to exceed a term of 60 months for any such derivative arrangement). The Revolving Credit Facility also includes customary additional terms and covenants that place limitations on certain types of activities, the payment of dividends, and that require satisfaction of certain financial tests.
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
Projected proved developed producing properties			2 years
Aggregate preferred stock dividend allowed		$ 20,000,000
Line of credit facility additional covenant aggregate amount		20,000,000
Revolving credit facility outstanding borrowings			$ 10,000,000
Weighted average interest rate			2.27%
Revolving credit facility interest rate terms			The London Interbank Offered Rate (“LIBOR”), plus a margin that ranges from 3.0% to 4.0% 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 that ranges from 2.0% to 3.0%.
Revolving credit facility | Minimum
Debt Instrument [Line Items]
Current assets to current liabilities ratio			100.00%
Revolving credit facility | Maximum
Debt Instrument [Line Items]
Secured debt to EBITDA ratio maximum			400.00%
Projected proved developed producing properties			60 months
Annual preferred stock dividend allowed		5,000,000
Line of credit facility additional covenant amount		$ 5,000,000
Option B | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.00%
Option B | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			3.00%

Long Term Debt - Secured Term L

Long Term Debt - Secured Term Loan Agreement - Additional Information (Detail) - USD ($) $ in Thousands	Jan. 03, 2017	May 18, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Outstanding borrowings under term loan facility					$ 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
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
Repayments of debt				$ 71,697
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 generally bore interest at adjusted LIBOR plus 10%, with a 1% LIBOR floor.
Secured debt to EBITDA ratio maximum			350.00%
Proved reserves to secured debt ratio, minimum			150.00%
Proved developed reserves to secured debt ratio, minimum			100.00%
Secured Term Loan Agreement | Subsequent Event
Debt Instrument [Line Items]
Repayments of debt	$ 132,000
Secured Term Loan Agreement | Fair Value, Inputs, Level 3
Debt Instrument [Line Items]
Long-term debt, fair value			$ 123,400
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]
Incremental 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) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2012USD ($)PrivatePlacement	May 31, 2012USD ($)
Maximum
Debt Instrument [Line Items]
Senior Notes, redemption notice period	60 days
Senior Notes
Debt Instrument [Line Items]
Principal amount	$ 400	$ 150	$ 250
Debt instrument, maturity date	May 1, 2020
Debt instrument, interest rate	8.50%
Senior Notes, redemption price percentage of principal	101.00%
Long-term debt, fair value	$ 407.3
Senior Notes | Level 2
Debt Instrument [Line Items]
Long-term debt, fair value	$ 407.3
Senior Notes | Minimum
Debt Instrument [Line Items]
Senior Notes, redemption notice period	30 days
Senior Notes | Private Placement
Debt Instrument [Line Items]
Number of private placement transactions | PrivatePlacement		2

Components of Provision for Inc

Components of Provision for Income Taxes (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Current income tax (expense)	$ (91)
Deferred income tax benefit		$ 22,354	$ 4,140
Total income tax benefit (expense)	$ (91)	$ 22,354	$ 4,140

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Taxes [Line Items]
U.S. federal income tax rate	35.00%	35.00%	35.00%
U.S. net operating loss carryforwards	$ 567,000,000
U.S. net operating loss carryforwards, beginning of expiration date	2,026
Deferred tax assets, valuation allowance	$ 309,597,000	$ 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	2,013
Earliest Tax Year | State Taxing Authorities
Income Taxes [Line Items]
Tax years open to examination	2,012
Latest Tax Year | Internal Revenue Service
Income Taxes [Line Items]
Tax years open to examination	2,016
Latest Tax Year | State Taxing Authorities
Income Taxes [Line Items]
Tax years open to examination	2,016

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, 2016	Dec. 31, 2015	Dec. 31, 2014
Income Tax Disclosure [Abstract]
Expected statutory income tax benefit	$ 56,571	$ 267,621	$ 9,097
State income tax benefit	3,087	13,394	480
Equity compensation	(2,761)	(4,822)	(4,273)
Non-deductible executive compensation	(690)		(468)
Valuation allowance	(56,005)	(253,592)
Other	(293)	(247)	(696)
Total income tax benefit (expense)	$ (91)	$ 22,354	$ 4,140

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, 2016	Dec. 31, 2015
Deferred income tax assets (liabilities):
Derivative financial instruments, assets	$ 4,403
Derivative financial instruments, liabilities		$ (35,481)
Net operating loss carryovers	206,663	183,964
Asset retirement obligation	7,530	7,118
Startup and organization costs	104	122
Deferred acquisition costs	45	45
Percentage depletion	1,335	1,360
Property and equipment costs	75,267	91,937
Equity compensation	2,267	3,342
Other	11,983	1,185
Valuation allowance	$ (309,597)	$ (253,592)

Stockholders' Equity and Equi51

Stockholders' Equity and Equity Based Awards - Preferred Stock - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	Oct. 06, 2016	Oct. 04, 2016	Dec. 31, 2016	Dec. 31, 2015
Class Of Stock [Line Items]
Preferred stock, shares authorized			1,000,000	1,000,000
Preferred stock, par value			$ 0.0001	$ 0.0001
Preferred stock, issued			62,500	0
Preferred stock, outstanding			62,500	0
Preferred Stock Purchase Agreement | BMO Capital Markets Corp. | 8.125% Series B Cumulative Perpetual Convertible Preferred Stock
Class Of Stock [Line Items]
Preferred stock, par value		$ 0.0001
Preferred stock to be issued and sold		55,000
Preferred stock, dividend rate		8.125%
Initial Purchaser option to purchase additional shares		7,500
Total shares of Convertible Preferred Stock purchased by Initial Purchaser	62,500
Total shares of Convertible Preferred Stock purchased by Initial Purchaser, aggregate net consideration, before offering expenses	$ 60
Convertible Preferred Stock, conversion rate	33.8616
Convertible preferred stock conversion terms			At any time on or after October 15, 2021, the Corporation shall have the right, at its option, to elect to cause all, and not part, of the outstanding shares of Series B Preferred Stock to be automatically converted into that number of shares of Common Stock for each share of Series B Preferred Stock equal to the Conversion Rate in effect on the Mandatory Conversion Date.
Accumulated preferred dividends			$ 1.2
Dividends payable			$ 1.4
Date of dividends declared			Jan. 15, 2017
Date of dividends payable			Jan. 17, 2017
Preferred Stock Purchase Agreement | BMO Capital Markets Corp. | 8.125% Series B Cumulative Perpetual Convertible Preferred Stock | Over-Allotment Option
Class Of Stock [Line Items]
Number of additional shares purchased by Initial Purchaser	7,500

Stockholders' Equity and Equi52

Stockholders' Equity and Equity Based Awards - Common Stock - Additional Information (Detail) $ / shares in Units, $ in Thousands	1 Months Ended		3 Months Ended	12 Months Ended
	Jun. 30, 2016$ / sharesshares	May 31, 2016$ / shares	Dec. 31, 2016USD ($)$ / sharesshares	Dec. 31, 2016USD ($)$ / sharesshares	Dec. 31, 2015$ / sharesshares
Class Of Stock [Line Items]
Common stock, shares authorized | shares	45,000,000		45,000,000	45,000,000	45,000,000
Common stock, shares issued | shares			21,932,842	21,932,842	15,442,147
Common stock, shares outstanding | shares			21,932,842	21,932,842	15,442,147
Number of votes per share of common stock				One vote for each share of common stock
Common stock, par value | $ / shares	$ 0.0001		$ 0.0001	$ 0.0001	$ 0.0001
Reverse stock split ratio	0.2
Common stock trading price minimum price requirement of stock exchange | $ / shares	$ 1
Issuance of stock, net of deductible fees and estimated expenses (in shares) | shares			4,400,000
Issuance of common stock, price per share | $ / shares			$ 38	$ 38
Proceeds from issuance of common stock, net of deductible fees and estimated expenses | $			$ 160,900	$ 160,887
Scenario Previously Reported
Class Of Stock [Line Items]
Common stock, shares authorized | shares	225,000,000
Stockholder Rights Plan
Class Of Stock [Line Items]
Dividend declaration ratio of preferred share purchase right for outstanding share of common stock		100.00%
Common stock, par value | $ / shares		$ 0.0001
Stockholder Rights Plan | Series A Junior Participating Preferred Stock
Class Of Stock [Line Items]
Percentage of Shareholders right to purchase preferred stock		0.10%
Purchase price of preferred share | $ / shares		$ 4.50
Beneficial ownership percentage of acquiring person		20.00%
Preferred share purchase rights exercisable starting period		10 days

Stockholders' Equity and Equi53

Stockholders' Equity and Equity Based Awards - Long-Term Employee Incentive Plan - Additional Information (Detail) $ / shares in Units, $ in Millions	1 Months Ended					12 Months Ended
	May 31, 2016shares	Feb. 29, 2016Installment	Sep. 30, 2015Installment$ / shares	Jun. 30, 2015shares	May 31, 2015USD ($)Installment$ / shares	Dec. 31, 2016$ / sharesshares
Stock Option Awards
Class Of Stock [Line Items]
Option exercise price | $ / shares						$ 2.80
Cash-Settled Stock Appreciation Rights | Non-Employee Directors
Class Of Stock [Line Items]
Grant date term						10 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 | shares						3,451,548
Additional number of shares of common stock to be issued under the Incentive Plan | shares	1,000,000			620,000
Long-term Employee Incentive Plan | Stock Option Awards
Class Of Stock [Line Items]
Number of installment for equity awards		3	3		3
Option exercise price | $ / shares			$ 2.10		$ 6.75
Grant date term		10 years	10 years		10 years
Long-term Employee Incentive Plan | Stock Option Awards | Non-Employee Directors
Class Of Stock [Line Items]
Number of installment for equity awards		1
Long-term Employee Incentive Plan | Time-based restricted cash awards
Class Of Stock [Line Items]
Number of installment for equity awards		3
Unrecognized Compensation Expense | $					$ 5.2
Vesting period other than option					3 years
Long-term Employee Incentive Plan | Performance-based restricted cash awards
Class Of Stock [Line Items]
Unrecognized Compensation Expense | $					$ 2.9
Long-term Employee Incentive Plan | Cash-Settled Stock Appreciation Rights
Class Of Stock [Line Items]
Number of installment for equity awards		3
Grant date term		10 years
Long-term Employee Incentive Plan | Cash-Settled Stock Appreciation Rights | Non-Employee Directors
Class Of Stock [Line Items]
Number of installment for equity awards		1

Expense Related to Incentive Pl

Expense Related to Incentive Plan (Detail) - Long-term Employee Incentive Plan - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	$ 41,217	$ 13,509	$ 16,331
Time-based restricted stock awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	4,359	9,067	12,101
TSR awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	996	2,848	3,990
Stock appreciation awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense		45	$ 240
Stock Option Awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	936	365
Time-based restricted cash awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	3,409	959
Performance-based restricted cash awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	13,780	$ 225
Cash-settled stock appreciation awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	$ 17,737

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, 2016USD ($)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 3,315
Stock Option Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 1,723
Weighted Average Years Remaining	1 year 10 months 24 days
Time-based restricted stock awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 926
Weighted Average Years Remaining	8 months 12 days
TSR awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 666
Weighted Average Years Remaining	2 months 12 days

Stockholders' Equity and Equi56

Stockholders' Equity and Equity Based Awards - Equity Awards - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016USD ($)$ / sharesshares	Dec. 31, 2015USD ($)$ / sharesshares	Dec. 31, 2014InstallmentEntity$ / sharesshares
Stock Option Awards
Class Of Stock [Line Items]
Vesting period	3 years
Options granted, term	10 years
Dividend yield	0.00%
Expected stock price volatility, minimum	63.00%
Expected stock price volatility, maximum	67.00%
Risk free rate, minimum	1.75%
Risk free rate, maximum	2.27%
Weighted average grant date fair value of options granted | $ / shares	$ 1.93	$ 4.60
Total intrinsic value for options exercised | $	$ 500,000	$ 0
Exercise of stock options (in shares)	22,777	0
Time-based restricted stock awards
Class Of Stock [Line Items]
Vesting period	3 years
Shares granted	92,648
Weighted average grant date fair value of share granted | $ / shares	$ 4.48	$ 6.75	$ 44.30
Number of remaining outstanding awards	151,781	285,704
Time-based restricted stock awards | Non-Employee Directors
Class Of Stock [Line Items]
Vesting period	1 year
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
Expired, Shares		51,532	31,359
Number of remaining outstanding awards	0
TSR Awards
Class Of Stock [Line Items]
Estimated forfeiture rates	4.00%
Shares granted	0	0
Weighted average grant date fair value of share granted | $ / shares			$ 66.60
Number of remaining outstanding awards	97,561	152,916
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
Minimum | Stock Option Awards
Class Of Stock [Line Items]
Estimated forfeiture rates	0.00%
Minimum | Time-based restricted stock awards
Class Of Stock [Line Items]
Estimated forfeiture rates	0.00%
Maximum | Stock Option Awards
Class Of Stock [Line Items]
Estimated forfeiture rates	15.00%
Maximum | Time-based restricted stock awards
Class Of Stock [Line Items]
Estimated forfeiture rates	15.00%

Changes in Non-Vested Stock Opt

Changes in Non-Vested Stock Option Awards (Detail) - Stock Option Awards - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding, beginning of period, Shares	396,440
Granted, Shares	741,450
Exercised, Shares	(22,777)	0
Forfeited, Shares	(62,600)
Outstanding, end of period, Shares	1,052,513	396,440
Exercisable, end of period, Shares	106,513
Outstanding, beginning of period, Weighted Average Exercise Price	$ 6.40
Granted, Weighted Average Exercise Price	2.80
Exercised, Weighted Average Exercise Price	5.77
Forfeited, Weighted Average Exercise Price	3.79
Outstanding, end of period, Weighted Average Exercise Price	4.03	$ 6.40
Exercisable, end of period, Weighted Average Exercise Price	$ 6.53
Outstanding, Weighted Average Remaining Contractual Term	8 years 10 months 24 days
Exercisable, Weighted Average Remaining Contractual Term	8 years 4 months 24 days
Outstanding, Aggregate Intrinsic Value	$ 39,110
Exercisable, Aggregate Intrinsic Value	$ 3,692

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, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested, beginning of period, Shares	285,704
Granted, Shares	92,648
Vested, Shares	(196,680)
Forfeited, Shares	(29,891)
Non-vested, end of period, Shares	151,781	285,704
Non-vested, beginning of period, Weighted Average Grant Date Fair Value	$ 42.10
Granted, Weighted Average Grant Date Fair Value	4.48	$ 6.75	$ 44.30
Vested, Weighted Average Grant Date Fair Value	41.26
Forfeited, Weighted Average Grant Date Fair Value	17.46
Non-vested, end of period, Weighted Average Grant Date Fair Value	$ 25.07	$ 42.10

Valuation Model for Performance

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

Changes in Non-Vested TSR Award

Changes in Non-Vested TSR Awards (Detail) - TSR awards - $ / shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested, beginning of period, Shares	152,916
Granted, Shares	0	0
Forfeited, Shares	(55,355)
Non-vested, end of period, Shares	97,561	152,916
Non-vested, beginning of period, Weighted Average Grant Date Fair Value	$ 71.29
Granted, Weighted Average Grant Date Fair Value			$ 66.60
Forfeited, Weighted Average Grant Date Fair Value	79.55
Non-vested, end of period, Weighted Average Grant Date Fair Value	$ 66.60	$ 71.29

Stockholders' Equity and Equi61

Stockholders' Equity and Equity Based Awards - Liability Awards - Additional Information (Detail) $ / shares in Units, $ in Millions	Mar. 13, 2017$ / shares	Feb. 29, 2016$ / sharesshares	May 31, 2015$ / shares	Dec. 31, 2016USD ($)Installment$ / shares
Cash-Settled Stock Appreciation Rights
Class Of Stock [Line Items]
Cash-settled stock appreciation rights, fair value | $				$ 64.5
Cash-settled stock appreciation rights, fair value expensed | $				$ 17.7
Cash-Settled Stock Appreciation Rights | Employees
Class Of Stock [Line Items]
Cash-settled stock appreciation rights, base price		$ 2.65
Number of shares cash-settled stock appreciation rights | shares		486,373
Grant date term				10 years
Number of installment for equity awards | Installment				3
Cash-Settled Stock Appreciation Rights | Executives
Class Of Stock [Line Items]
Cash-settled stock appreciation rights, base price		$ 2.915
Number of shares cash-settled stock appreciation rights | shares		1,216,479
Cash-Settled Stock Appreciation Rights | Non-Employee Directors
Class Of Stock [Line Items]
Grant date term				10 years
Vesting period				1 year
Time-based restricted cash awards
Class Of Stock [Line Items]
Vesting period				3 years
Restricted cash award, fair value | $				$ 9.9
Restricted cash award, fair value expensed | $				$ 4.4
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]
Vesting period				3 years
Estimated forfeiture rates				5.00%
Restricted cash award, fair value | $				$ 16.4
Restricted cash award, fair value expensed | $				$ 13.1
Number of trading days				60 days
Common stock, hurdle stock price			$ 10
Restricted cash award, term				10 years
Performance-based restricted cash awards | Stock price one
Class Of Stock [Line Items]
Common stock, hurdle stock price				$ 10
Performance-based restricted cash awards | Stock price two
Class Of Stock [Line Items]
Common stock, hurdle stock price				13
Performance-based restricted cash awards | Stock price three
Class Of Stock [Line Items]
Common stock, hurdle stock price				16
Performance-based restricted cash awards | Stock price four
Class Of Stock [Line Items]
Common stock, hurdle stock price				19
Performance-based restricted cash awards | Stock price five
Class Of Stock [Line Items]
Common stock, hurdle stock price				22
Performance-based restricted cash awards | Stock price six
Class Of Stock [Line Items]
Common stock, hurdle stock price				25
Performance-based restricted cash awards | Stock price seven
Class Of Stock [Line Items]
Common stock, hurdle stock price				28
Performance-based restricted cash awards | Stock price eight
Class Of Stock [Line Items]
Common stock, hurdle stock price				$ 31
Performance-based restricted cash awards | Subsequent Event | Stock price nine
Class Of Stock [Line Items]
Common stock, hurdle stock price	$ 40
Minimum | Cash-Settled Stock Appreciation Rights
Class Of Stock [Line Items]
Estimated forfeiture rates				0.00%
Minimum | Time-based restricted cash awards
Class Of Stock [Line Items]
Estimated forfeiture rates				0.00%
Maximum | Cash-Settled Stock Appreciation Rights
Class Of Stock [Line Items]
Estimated forfeiture rates				15.00%
Maximum | Time-based restricted cash awards
Class Of Stock [Line Items]
Estimated forfeiture rates				15.00%
Maximum | Performance-based restricted cash awards
Class Of Stock [Line Items]
Common stock, hurdle stock price			$ 40
Restricted cash award, average effective term				1 year

Asset Retirement Obligation - A

Asset Retirement Obligation - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016
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, 2016	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period	$ 19,238	$ 31,340
Additional liability incurred / acquired	587	96
Accretion expense	1,790	2,740
Liabilities settled / sold	(1,088)	(15,177)
Revisions to previous estimates	(175)	239
Asset retirement obligations at end of period	20,352	19,238
Less: current asset retirement obligations	(895)	(891)
Long-term asset retirement obligations	$ 19,457	$ 18,347

Derivative Instruments - Additi

Derivative Instruments - Additional Information (Detail) $ in Millions	Dec. 31, 2016USD ($)
Derivative [Line Items]
Maximum amount of loss in the event of all counterparties defaulting	$ 0
Level 2 | Commodity Contract
Derivative [Line Items]
Fair value of commodity derivatives net liability	$ 11.9

Oil and Gas Commodity Contracts

Oil and Gas Commodity Contracts (Detail) - Jan – Dec 2017 Commodity Swap Contracts	12 Months Ended
	Dec. 31, 2016bblMMBTU$ / bbl$ / MMBTU
Oil (NYMEX WTI)
Derivative [Line Items]
Bbl per Day | bbl	1,528
Weighted Average Swap Price per Bbl | $ / bbl	51.10
Gas (NYMEX HH)
Derivative [Line Items]
MMBtu per Day | MMBTU	2,008
Weighted Average Swap Price per MMBtu | $ / MMBTU	2.807
NGL (Mont. Belvieu)
Derivative [Line Items]
Bbl per Day | bbl	300
Weighted Average Swap Price per Bbl | $ / bbl	19.53

Commodity Collar Contracts (Det

Commodity Collar Contracts (Detail)	Dec. 31, 2016bblMMBTU$ / bbl$ / MMBTU
Oil (NYMEX WTI) | Jan – Dec 2017 Two Way Commodity Collar Contracts
Derivative [Line Items]
Bbl per Day | bbl	3,684
Weighted Average Floor Price | $ / bbl	46.80
Weighted Average Ceiling Price | $ / bbl	57.63
Oil (NYMEX WTI) | Jan – Dec 2017 Three Way Oil Collar Contracts
Derivative [Line Items]
Bbl per Day | bbl	1,130
Weighted Average Ceiling Price | $ / bbl	60.10
Weighted Average Short Put Price | $ / bbl	40
Weighted Average Floor Price | $ / bbl	50
Gas (NYMEX HH) | Jan – Dec 2017 Two Way Commodity Collar Contracts
Derivative [Line Items]
Bbl per Day | MMBTU	8,080
Weighted Average Floor Price | $ / MMBTU	2.566
Weighted Average Ceiling Price | $ / MMBTU	3.433
Gas (NYMEX HH) | Jan – Dec 2017 Three Way Gas Collar Contracts
Derivative [Line Items]
Bbl per Day | MMBTU	1,505
Weighted Average Ceiling Price | $ / MMBTU	3.746
Weighted Average Short Put Price | $ / MMBTU	2.692
Weighted Average Floor Price | $ / MMBTU	3.192

Commodity Option Contract (Deta

Commodity Option Contract (Detail) - Oil (NYMEX WTI) - Jan – Dec 2018 Commodity Option Contract	Dec. 31, 2016bbl$ / bbl
Derivative [Line Items]
Bbl per Day | bbl	1,100
Weighted Average Sold Call Price per Bbl | $ / bbl	50

Summary of Subsequent Additiona

Summary of Subsequent Additional Commodity Derivative Contracts (Detail) - Oil (NYMEX WTI)	Dec. 31, 2016bbl$ / bbl
Apr – June 2017 Commodity Swap
Derivative [Line Items]
Bbl per Day | bbl	1,000
Weighted Average Swap Price per Bbl | $ / bbl	55.45
July – Dec 2017 Commodity Swap
Derivative [Line Items]
Bbl per Day | bbl	1,000
Weighted Average Swap Price per Bbl | $ / bbl	56.30
July – Dec 2017 Commodity Swap
Derivative [Line Items]
Bbl per Day | bbl	1,000
Weighted Average Swap Price per Bbl | $ / bbl	56.50

Amount of Commodity Derivative

Amount of Commodity Derivative Instrument Gains Losses (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Commodity derivative settlement gains (losses)	$ 88,010	$ 93,150	$ (4,988)
Mark-to-market gain (loss)	(107,794)	(16,658)	123,129
Commodity derivative instruments gain (loss)	$ (19,784)	$ 76,492	$ 118,141

Assets and Liabilities Required

Assets and Liabilities Required to be Measured at Fair Value on Recurring Basis (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Assets
Derivative instruments, current assets	$ 218	$ 92,431
Derivative instruments, long term assets		3,463
Liabilities
Derivative instruments, current liabilities	8,014
Derivative instruments, long term liabilities	4,104
Fair Value Measurements Recurring Basis | Level 2 | Commodity
Assets
Derivative instruments, current assets	218	92,431
Derivative instruments, long term assets		3,463
Total assets	218	$ 95,894
Liabilities
Derivative instruments, current liabilities	8,014
Derivative instruments, long term liabilities	4,104
Total liabilities	$ 12,118

Future Minimum COTwo Purchase C

Future Minimum COTwo Purchase Commitments (Detail) - Co2 Kinder Morgan company $ in Thousands	Dec. 31, 2016USD ($)
Recorded Unconditional Purchase Obligation [Line Items]
2,017	$ 5,671
2,018	5,671
Total	$ 11,342

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
NNOGC
Commitment And Contingencies [Line Items]
Percentage of interest that each purchase options entitles to purchase	10.00%
Office facilities
Commitment And Contingencies [Line Items]
Rental expense, net	$ 3,000,000	$ 1,100,000	$ 1,600,000
Compressors and Other Oilfield Equipment
Commitment And Contingencies [Line Items]
Rental expense, net	1,700,000	$ 1,900,000	$ 2,600,000
Escrow Funding Agreement
Commitment And Contingencies [Line Items]
Amount to be Refunded from Escrow	2,500,000
Aggregate funding commitment	17,600,000
Escrow Funding Agreement | Additional Payments Per Year Until 2031
Commitment And Contingencies [Line Items]
Aggregate funding commitment	300,000
Co2 Kinder Morgan company
Commitment And Contingencies [Line Items]
Fair value of embedded derivative	$ 0

Schedule of Future Payment Oper

Schedule of Future Payment Operating Leases Agreements (Detail) $ in Thousands	Dec. 31, 2016USD ($)
Operating Leases Future Minimum Payments Due [Abstract]
2,017	$ 3,904
2,018	1,771
2,019	1,326
2020 and thereafter	3,138
Total	10,139
Office Lease Rentals
Operating Leases Future Minimum Payments Due [Abstract]
2,017	1,892
2,018	1,698
2,019	1,324
2020 and thereafter	3,138
Total	8,052
Field Equipment Rentals
Operating Leases Future Minimum Payments Due [Abstract]
2,017	1,629
Total	1,629
Vehicle Lease Rentals
Operating Leases Future Minimum Payments Due [Abstract]
2,017	383
2,018	73
2,019	2
Total	$ 458

Subsequent Events - Additional

Subsequent Events - Additional Information (Detail)	Mar. 03, 2017USD ($)aWellBoeft	Feb. 17, 2017USD ($)	Jan. 15, 2017USD ($)	Jan. 03, 2017USD ($)	Feb. 28, 2017Installmentshares	Dec. 31, 2016	Dec. 31, 2015USD ($)	Feb. 22, 2017USD ($)
Subsequent Event [Line Items]
Repayments of debt							$ 71,697,000
Purchase Agreement
Subsequent Event [Line Items]
Transaction date						Mar. 3, 2017
Denton and South Knowles
Subsequent Event [Line Items]
Purchase and sale agreement, effective date						Oct. 1, 2016
Federal Funds Effective Swap Rate
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate						0.50%
Option A | London Interbank Offered Rate (LIBOR) | Minimum
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate						3.00%
Option A | London Interbank Offered Rate (LIBOR) | Maximum
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate						4.00%
Subsequent Event
Subsequent Event [Line Items]
Dividend declared date on preferred stock			Jan. 15, 2017
Dividend declared on preferred stock			$ 1,400,000
Dividend payable date on preferred stock			Jan. 17, 2017
Subsequent Event | Commitment Letter
Subsequent Event [Line Items]
Maximum borrowing base determined by lenders	$ 100,000,000
Subsequent Event | Purchase Agreement
Subsequent Event [Line Items]
Cash consideration	$ 160,000,000
Subsequent Event | Purchase Agreement | Texas
Subsequent Event [Line Items]
Area of properties acquired, net | a	4,600
Subsequent Event | Purchase Agreement | Reeves County, Texas
Subsequent Event [Line Items]
Area of properties acquired, net | a	2,187
Subsequent Event | Purchase Agreement | Southern Reeves County
Subsequent Event [Line Items]
Area of properties acquired, net | a	2,405
Subsequent Event | Denton and South Knowles
Subsequent Event [Line Items]
Sale of properties								$ 14,500,000
Subsequent Event | Wolfcamp | Purchase Agreement
Subsequent Event [Line Items]
Number of wells | Well	2
Length of foot acquired | ft	4,500
Production per day | Boe	800
Subsequent Event | Wolfcamp | Purchase Agreement | Uncompleted Wolfcamp Wells
Subsequent Event [Line Items]
Number of wells | Well	6
Subsequent Event | Wolfcamp | Purchase Agreement | Uncompleted Wolfcamp Wells One
Subsequent Event [Line Items]
Number of wells | Well	4
Length of foot acquired | ft	4,500
Subsequent Event | Wolfcamp | Purchase Agreement | Uncompleted Wolfcamp Wells Two
Subsequent Event [Line Items]
Number of wells | Well	2
Length of foot acquired | ft	7,500
Subsequent Event | Wolfcamp A | Purchase Agreement
Subsequent Event [Line Items]
Length of foot acquired | ft	10,000
Wells in Process of Drilling | Well	1
Subsequent Event | Long-term Employee Incentive Plan | Time Vesting Restricted Stock | Employees
Subsequent Event [Line Items]
Number of shares expected to vest | shares					11,556
Number of installment for equity awards | Installment					3
Subsequent Event | Long-term Employee Incentive Plan | Performance Vesting Shares
Subsequent Event [Line Items]
Number of shares expected to vest | shares					131,391
Number of installment for equity awards | Installment					3
Subsequent Event | Long-term Employee Incentive Plan | Performance Vesting Shares | Non-Employee Directors
Subsequent Event [Line Items]
Number of shares expected to vest | shares					15,736
Number of installment for equity awards | Installment					1
Subsequent Event | Long-term Employee Incentive Plan | Outperformance Vesting Shares
Subsequent Event [Line Items]
Number of shares expected to vest | shares					131,379
Number of installment for equity awards | Installment					3
Subsequent Event | Long-term Employee Incentive Plan | Outperformance Vesting Shares | Employees
Subsequent Event [Line Items]
Number of shares expected to vest | shares					343,391
Number of installment for equity awards | Installment					3
Secured Term Loan Agreement
Subsequent Event [Line Items]
Public offerings of common stock, closing date						Dec. 23, 2016
Secured debt to EBITDA ratio maximum						350.00%
Secured Term Loan Agreement | Subsequent Event
Subsequent Event [Line Items]
Repayments of debt				$ 132,000,000
Amended and Restated Revolving Credit Facility
Subsequent Event [Line Items]
Credit agreement, initiation date						Feb. 17, 2017
Revolving credit facility, maturity date						Feb. 28, 2021
Revolving credit facility interest rate terms						The London Interbank Offered Rate (“LIBOR”), plus a margin that ranges from 3.0% to 4.0% or (b) the Alternate 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 LIBOR, plus a margin for the Alternate Base Rate that ranges from 2.0% to 3.0%.
Revolving Credit Facility covenant description						covenants that require, among other things, that Resolute maintains a ratio of current assets to current liabilities of no less than 1.0 to 1.0 and a ratio of funded debt to EBITDA of no more than 4.0 to 1.0. The Revolving Credit Facility prohibits us from entering into derivative arrangements for more than (i) 85% of our anticipated production from proved properties in the next 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 (not to exceed a term of 60 months for any such derivative arrangement). The Revolving Credit Facility also includes customary additional terms and covenants that place limitations on certain types of activities, the payment of dividends, and that require satisfaction of certain financial tests.
Anticipated production from proved properties period						2 years
Projected proved developed producing properties						2 years
Amended and Restated Revolving Credit Facility | Maximum
Subsequent Event [Line Items]
Projected proved developed producing properties						60 months
Amended and Restated Revolving Credit Facility | Subsequent Event
Subsequent Event [Line Items]
Maximum borrowing base determined by lenders		$ 150,000,000
Current assets to current liabilities ratio		100.00%
Secured debt to EBITDA ratio maximum		400.00%
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%
Amended and Restated Revolving Credit Facility | Subsequent Event | Federal Funds Effective Swap Rate
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate		0.50%
Amended and Restated Revolving Credit Facility | Subsequent Event | Option A | London Interbank Offered Rate (LIBOR) | Minimum
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate		3.00%
Amended and Restated Revolving Credit Facility | Subsequent Event | Option A | London Interbank Offered Rate (LIBOR) | Maximum
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate		4.00%
Amended and Restated Revolving Credit Facility | Subsequent Event | Option B | Minimum
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate		2.00%
Amended and Restated Revolving Credit Facility | Subsequent Event | Option B | Maximum
Subsequent Event [Line Items]
Debt instrument, basis spread on variable rate		3.00%

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, 2016	Dec. 31, 2015	Dec. 31, 2014
Acquisition costs
Proved		$ 41,830
Unproved		120,851	$ 6,583	$ 7,007
Exploration costs		101,719	13,764	111,769
Development costs	[1]	31,057	39,883	50,291
Total		$ 295,457	$ 60,230	$ 169,067
[1]	*Includes $5.9 million, $8.9 million and $16.3 million of acquired CO2 during 2016, 2015 and 2014, respectively

Costs Incurred in Oil and Gas76

Costs Incurred in Oil and Gas Property Acquisition Exploration and Development Activities (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Extractive Industries [Abstract]
Acquired CO2	$ 5.9	$ 8.9	$ 16.3

Net Capitalized Costs Related t

Net Capitalized Costs Related to Resolute's Oil and Gas Producing Activities (Detail) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Property Plant And Equipment [Abstract]
Proved oil and gas properties	$ 1,889,111	$ 1,732,707
Unevaluated oil and gas properties, not subject to amortization	121,375	21,264
Accumulated depletion, depreciation and amortization	(1,640,279)	(1,534,479)
Oil and gas properties, net	$ 370,207	$ 219,492

Changes in Estimated Reserves (

Changes in Estimated Reserves (Detail) bbl in Thousands, MMcf in Thousands, Boe in Thousands		12 Months Ended
		Dec. 31, 2016BoebblMMcf		Dec. 31, 2015BoebblMMcf	Dec. 31, 2014BoebblMMcf
Oil Equivalent
Reserve Quantities [Line Items]
Proved reserves, beginning balance | Boe	[1]	33,120		74,218	59,394
Purchase of minerals in place | Boe	[1]	3,323
Production | Boe	[1]	(5,182)		(4,535)	(4,647)
Extensions, discoveries and other additions | Boe	[1],[2]	34,543		4,602	28,800
Sales of minerals in place | Boe	[1]			(12,072)	(224)
Revisions of previous estimates | Boe	[1]	(5,537)	[3]	(29,093)	(9,105)	[3]
Proved reserves, ending balance | Boe	[1]	60,267		33,120	74,218
Proved developed reserves | Boe	[1]	37,656		27,874	41,446
Proved undeveloped reserves | Boe	[1]	22,611		5,246	32,772
Oil
Reserve Quantities [Line Items]
Proved reserves, beginning balance		28,748		63,715	47,511
Purchase of minerals in place		1,492
Production		(3,821)		(3,270)	(3,489)
Extensions, discoveries and other additions	[2]	21,427		1,965	25,756
Sales of minerals in place				(5,289)	(215)
Revisions of previous estimates		(4,042)	[3]	(28,373)	(5,848)	[3]
Proved reserves, ending balance		43,804		28,748	63,715
Proved developed reserves		30,026		25,672	34,359
Proved undeveloped reserves		13,778		3,076	29,356
Gas
Reserve Quantities [Line Items]
Proved reserves, beginning balance | MMcf		13,860		36,798	42,389
Purchase of minerals in place | MMcf		5,810
Production | MMcf		(4,811)		(5,193)	(6,942)
Extensions, discoveries and other additions | MMcf	[2]	41,151		8,208	10,128
Sales of minerals in place | MMcf				(23,674)	(26)
Revisions of previous estimates | MMcf		(3,562)	[3]	(2,279)	(8,751)	[3]
Proved reserves, ending balance | MMcf		52,448		13,860	36,798
Proved developed reserves | MMcf		24,209		7,098	25,775
Proved undeveloped reserves | MMcf		28,238		6,761	11,023
NGL
Reserve Quantities [Line Items]
Proved reserves, beginning balance		2,061		4,370	4,817
Purchase of minerals in place		863
Production		(559)		(400)
Extensions, discoveries and other additions	[2]	6,257		1,269	1,357
Sales of minerals in place				(2,837)	(5)
Revisions of previous estimates		(900)	[3]	(341)	(1,799)	[3]
Proved reserves, ending balance		7,722		2,061	4,370
Proved developed reserves		3,595		1,019	2,791
Proved undeveloped reserves		4,127		1,043	1,579
[1]	In accordance with SEC and Financial Accounting Standards Board (“FASB”) requirements, our estimated net proved reserves and standardized measure at December 31, 2016, 2015 and 2014, utilized prices (subsequently adjusted for quality and basis differentials) of an average (based on the first day of the month) NYMEX West Texas Intermediate oil price of $42.75, $50.28 and $94.99 per Bbl for the Aneth Properties and Plains Marketing, L.P. posted West Texas Intermediate oil price of $39.25, $46.79 and $91.48 per Bbl for the Permian Properties, and an average Platts Gas Daily El Paso San Juan Basin spot gas price of $2.33, $2.46 and $4.31 per MMBtu for the Aneth Properties and Platts Gas Daily El Paso Permian Basin spot gas price of $2.31, $2.45, and $4.25 per MMBtu for the Permian Properties, respectively.
[2]	Extensions, discoveries and other additions in 2016 are largely due to the Reeves County drilling program which, together with the acquisition of additional interests in Mustang, resulted in 14.8 MMBoe added to net proved developed producing from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 17.9 MMBoe net reserves. Additionally, 4.5 MMBoe of net proved developed non-producing and proved undeveloped reserves were added to Aneth Field in connection with newly identified compression and well deepening projects. 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 from drilling proved locations, plus an additional 970 MBoe from successful drilling of non-proved locations. Furthermore, these successful wells created additional proved undeveloped offset locations carrying 3.6 MMBoe reserves.
[3]	Decreases in proved reserves associated with revisions of previous estimates resulted primarily from reduced product pricing.

Changes in Estimated Reserves79

Changes in Estimated Reserves (Parenthetical) (Detail) Boe in Thousands	12 Months Ended
	Dec. 31, 2016Boe$ / bbl$ / MMBTU	Dec. 31, 2015Boe$ / bbl$ / MMBTU	Dec. 31, 2014$ / bbl$ / MMBTU
Additional proved undeveloped offset locations
Reserve Quantities [Line Items]
Reinstatements (additions) of estimated proved developed reserves	17,900
Proved undeveloped reserves
Reserve Quantities [Line Items]
Reinstatements (additions) of estimated proved developed reserves	4,500
Oil | NYMEX West Texas
Reserve Quantities [Line Items]
Average oil and gas market price | $ / bbl	42.75	50.28	94.99
Oil | Plains Marketing, L.P. West Texas
Reserve Quantities [Line Items]
Average oil and gas market price | $ / bbl	39.25	46.79	91.48
Gas | Platts Gas Daily El Paso San Juan Basin spot
Reserve Quantities [Line Items]
Average oil and gas market price | $ / MMBTU	2.33	2.46	4.31
Gas | Platts Gas Daily El Paso Permian Basin spot
Reserve Quantities [Line Items]
Average oil and gas market price | $ / MMBTU	2.31	2.45	4.25
Reeves County drilling program
Reserve Quantities [Line Items]
Reinstatements (additions) of estimated proved developed reserves	14,800
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		3,600

Supplemental Oil and Gas Info80

Supplemental Oil and Gas Information - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
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, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Extractive Industries [Abstract]
Future cash inflows	$ 1,800,000	$ 1,293,000	$ 5,858,000
Future production costs	(934,000)	(774,000)	(2,719,000)
Future development costs	(288,000)	(180,000)	(1,008,000)
Future income taxes	(1,000)		(412,000)
Future net cash flows	577,000	339,000	1,719,000
10% annual discount for estimated timing of cash flows	(233,000)	(140,000)	(886,000)
Standardized measure of discounted future net cash flows	$ 344,000	$ 199,000	$ 833,000	$ 893,000

Future Net Cash Flows Relatin82

Future Net Cash Flows Relating to Proved Oil and Gas Reserves (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
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, 2016	Dec. 31, 2015	Dec. 31, 2014
Extractive Industries [Abstract]
Standardized measure, beginning of year	$ 199,000	$ 833,000	$ 893,000
Sales of oil and gas produced, net of production costs	(82,000)	(181,000)	(196,000)
Net changes in prices and production costs	(106,000)	(917,000)	(191,000)
Purchases of minerals in place	10,000
Sales of minerals in place		(134,000)	(6,000)
Previously estimated development costs incurred during the year	22,000	33,000	49,000
Extensions, discoveries and improved recovery	268,000	13,000	207,000
Changes in estimated future development costs	12,000	119,000	(13,000)
Revisions of previous quantity estimates	(3,000)	196,000	(16,000)
Accretion of discount	20,000	70,000	89,000
Net change in income taxes		104,000	44,000
Changes in timing and other	4,000	63,000	(27,000)
Standardized measure, end of year	$ 344,000	$ 199,000	$ 833,000

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, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Quarterly Financial Data [Abstract]
Revenue	$ 62,667	$ 47,419	$ 35,390	$ 19,002	$ 28,498	$ 36,617	$ 48,396	$ 41,133	$ 164,478	$ 154,644	$ 329,371
Operating expenses	(64,042)	(57,089)	(39,767)	(95,086)	(122,104)	(253,484)	(270,291)	(285,469)	(255,984)	(931,348)	(442,045)
Loss from operations	(1,375)	(9,670)	(4,377)	(76,084)	(93,606)	(216,867)	(221,895)	(244,336)	(91,506)	(776,704)	(112,674)
Net loss	$ (20,648)	$ (18,856)	$ (36,906)	$ (85,312)	$ (92,180)	$ (182,770)	$ (259,107)	$ (208,222)	$ (161,722)	$ (742,279)	$ (21,850)
Loss per common share:
Basic and Diluted	$ (1.23)	$ (1.24)	$ (2.44)	$ (5.65)	$ (6.15)	$ (12.20)	$ (17.30)	$ (14)	$ (10.33)	$ (49.55)	$ (1.50)
Weighted average common shares outstanding:
Basic and Diluted	17,690	15,173	15,155	15,036	14,979	14,971	14,965	14,857	15,767	14,986	14,760