Cimarex Resolute (REN) 10-K 12 Mar 18 2017 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Feb. 28, 2018	Jun. 30, 2017
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2,017
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	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		23,066,559
Entity Public Float			$ 629

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 3,762	$ 133,089
Accounts receivable	63,420	55,228
Prepaid expenses and other current assets	1,856	3,249
Total current assets	77,875	191,784
Property and equipment, at cost:
Oil and gas properties, full cost method of accounting, Unproved	248,059	121,375
Oil and gas properties, full cost method of accounting, Proved	2,030,316	1,889,111
Other property and equipment	12,879	9,754
Accumulated depletion, depreciation and amortization	(1,737,116)	(1,647,120)
Net property and equipment	554,138	373,120
Other assets:
Other assets	274	332
Restricted cash		23,137
Total assets	641,922	588,373
Current liabilities:
Accounts payable	16,077	8,675
Accrued expenses	53,214	37,507
Accrued revenue payable	28,255	19,801
Accrued cash-settled incentive awards	34,317	27,158
Accrued interest payable	7,574	5,784
Asset retirement obligations	540	895
Commodity derivative instruments	20,822	8,014
Secured term loan facility		122,139
Total current liabilities	160,799	229,973
Long term liabilities:
Revolving credit facility	27,487	8,821
Senior notes	523,240	397,154
Asset retirement obligations	2,247	19,457
Commodity derivative instruments	990	4,104
Other long term liabilities	1,568	4,611
Total liabilities	716,331	664,120
Commitments and contingencies
Stockholders’ deficit:
Convertible preferred stock, $0.0001 par value; 1,000,000 shares authorized; issued and outstanding 62,500 and 62,500 shares at December 31, 2017 and 2016, respectively; $62.5 million liquidation preference
Common stock, $0.0001 par value; 45,000,000 shares authorized; issued and outstanding 22,527,652 and 21,932,842 shares at December 31, 2017 and 2016, respectively	2	2
Additional paid-in capital	957,426	948,380
Accumulated deficit	(1,031,837)	(1,024,129)
Total stockholders’ deficit	(74,409)	(75,747)
Total liabilities and stockholders’ deficit	641,922	588,373
Contingent Payment Derivative Instrument
Current assets:
Derivative instruments current	8,311
Other assets:
Derivative instruments noncurrent	9,635
Commodity
Current assets:
Derivative instruments current	$ 526	$ 218

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
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	62,500
Preferred stock, outstanding	62,500	62,500
Preferred stock, liquidation preference	$ 62.5	$ 62.5
Common stock, par value	$ 0.0001	$ 0.0001
Common stock, shares authorized	45,000,000	45,000,000
Common stock, issued	22,527,652	21,932,842
Common stock, outstanding	22,527,652	21,932,842

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenue:
Oil	$ 254,606	$ 148,336	$ 137,893
Gas	25,572	10,661	12,628
Natural gas liquids	23,300	5,481	4,123
Total revenue	303,478	164,478	154,644
Operating expenses:
Lease operating	79,308	63,699	79,393
Production and ad valorem taxes	23,351	16,270	19,985
Depletion, depreciation, amortization, and asset retirement obligation accretion	92,089	50,462	94,338
Impairment of proved oil and gas properties	0	58,000	705,000
General and administrative	48,537	32,627	31,447
Cash-settled incentive awards	16,174	34,926	1,185
Total operating expenses	259,459	255,984	931,348
Income (loss) from operations	44,019	(91,506)	(776,704)
Other income (expense):
Interest expense, net	(43,449)	(50,684)	(64,358)
Commodity derivative instruments gain (loss)	(5,655)	(19,784)	76,492
Contingent payment derivative instrument gain	3,464
Other income (expense)	95	343	(63)
Total other income (expense)	(45,545)	(70,125)	12,071
Loss before income taxes	(1,526)	(161,631)	(764,633)
Income tax benefit (expense)	293	(91)	22,354
Net loss	(1,233)	(161,722)	(742,279)
Preferred stock dividends	(6,475)
Net loss available to common shareholders	$ (7,708)	$ (161,722)	$ (742,279)
Net loss per common share:
Basic and diluted	$ (0.35)	$ (10.33)	$ (49.55)
Weighted average common shares outstanding:
Basic and diluted	21,889	15,767	14,986

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, 2014	$ 526,618	$ 2		$ 646,744	$ (120,128)
Beginning 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 employee options to purchase common stock	98			98
Exercise of employee options to purchase common stock (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
Issuance of stock, restricted stock and share-based compensation	12,188			12,188
Issuance of stock, restricted stock and share-based compensation (in shares)		592
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations	(3,394)			(3,394)
Redemption of restricted stock for employee income tax restricted stock forfeitures and expirations (in shares)		(105)
Exercise of employee options to purchase common stock	252			252
Exercise of employee options to purchase common stock (in shares)		108
Preferred stock dividend	(6,475)				(6,475)
Net loss	(1,233)				(1,233)
Ending Balance at Dec. 31, 2017	$ (74,409)	$ 2		$ 957,426	$ (1,031,837)
Ending Balance (in shares) at Dec. 31, 2017		22,528	63

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating activities:
Net loss	$ (1,233)	$ (161,722)	$ (742,279)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion, depreciation, amortization, and asset retirement obligation accretion	92,089	50,462	94,338
Impairment of proved oil and gas properties	0	58,000	705,000
Amortization of deferred financing costs and long-term debt premium and discount	9,336	5,240	11,578
Share-based compensation	12,161	6,315	12,148
Commodity derivative instruments loss (gain)	5,655	19,784	(76,492)
Commodity derivative settlement gains	3,730	88,010	93,150
Unrealized contingent payment derivative instrument gain	(3,464)
Deferred income tax benefit			(22,354)
Change in operating assets and liabilities:
Accounts receivable	(7,592)	(18,019)	21,216
Other current assets	(577)	109	322
Accounts payable and accrued expenses	25,337	35,520	(27,173)
Accrued interest payable	1,790	20	25
Net cash provided by operating activities	137,232	83,719	69,479
Investing activities:
Oil and gas exploration and development expenditures	(306,073)	(128,340)	(67,636)
Purchase of oil and gas properties	(161,264)	(95,940)
Proceeds from sale of oil and gas properties and other	198,175	35,477	268,773
Purchase of other property and equipment	(3,402)	(106)	(124)
Restricted cash	1,044	(1,640)	(1,489)
Other long-term assets	31	82	59
Net cash provided by (used in) investing activities	(271,489)	(190,467)	199,583
Financing activities:
Proceeds from bank borrowings	381,000	156,500	183,000
Repayments of bank borrowings	(361,000)	(146,500)	(418,000)
Proceeds from issuance of senior notes	126,875
Repayment of term loans	(128,303)		(71,697)
Payment of preferred dividend	(5,205)
Payment of financing costs	(5,295)		(3,744)
Redemption of restricted stock for employee income taxes	(3,394)	(122)	(176)
Proceeds from exercise of employee options to purchase common stock	252	98
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
Net cash provided by (used in) financing activities	4,930	230,540	(264,117)
Net increase in cash and cash equivalents	(129,327)	123,792	4,945
Cash and cash equivalents at beginning of period	133,089	9,297	4,352
Cash and cash equivalents at end of period	3,762	133,089	9,297
Cash paid during the period for:
Interest, net of amounts capitalized	32,323	50,684	64,364
Income taxes	63
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	25,883	18,440	10,482
Increase (decrease) to asset retirement obligations	1,424	412	333
Asset retirement obligations assumed	23	587
Asset retirement obligations sold	$ 19,680	$ 1,081	$ 14,985

Organization and Nature of Busi

Organization and Nature of Business	12 Months Ended
	Dec. 31, 2017
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 of properties in the Delaware Basin in west Texas (the “Delaware Basin Properties”). As discussed in Note 3, the Company closed on the disposition of Aneth Field, located in the Paradox Basin in southeast Utah (the “Aneth Field Properties” or “Aneth Field”), on November 6, 2017. All periods presented include the results related to Aneth Field, prior to the disposition. 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. Its guarantees are full and unconditional and joint and several, and there are no subsidiaries of the parent company other than the Guarantors (defined below). 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, 2017
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; 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; and revenue and related receivables. 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 $535.1 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, 2017 2016 Trade receivables $ 18,079 $ 14,898 Revenue receivables 43,136 32,817 Derivative receivables 1,560 5,695 Other receivables 645 1,818 Total accounts receivable $ 63,420 $ 55,228 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 trade receivables are due between fifteen and thirty 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, 2017 and 2016, the Company had no allowance for doubtful accounts recorded. 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 50%, 24% and 15% of its total 2017 revenue from Plains Marketing L.P., Western Refining, Inc. (“Western”) and ETC Field Services, respectively; 47%, 27% and 13% of its total 2016 revenue from Western, Plains Marketing L.P. and Holly Frontier LLC, respectively and 58% and 14% of its total 2015 revenue from Western and Holly Frontier LLC, respectively. If Resolute was compelled to sell its oil and gas 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 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”). In Aneth Field (disposed of in November 2017), Resolute conducted 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 were capitalized at the time incurred. Development costs included 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 provided for improved recovery systems. Improved recovery systems included 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 were considered production costs and were expensed as incurred. These costs included, but were not limited to, compression, electricity, separation, re-injection of recovered CO 2 Capitalized general and administrative and operating costs include salaries, employee benefits, costs of consulting services and other specifically identifiable capital costs and do not include costs related to production operations, general corporate overhead or similar activities. Resolute capitalized general and administrative and operating costs related to its acquisition, exploration and development activities of $6.6 million during 2017, $5.7 million during 2016 and $6.3 million during 2015. 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 an exploration play in the Delaware Basin in Texas. 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, if any, 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. 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 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 2017, 2016 and 2015, the Company recorded $0, $58 million and $705 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 factor impacts 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 full cost ceiling impairment related to its oil and gas properties in such periods. 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. Capitalized interest totaled $15.8 million, $4.1 million and $6.0 million during 2017, 2016 and 2015, respectively. Business Combinations The Company accounts for all business combinations using the acquisition method which involves the use of significant judgment. Under the acquisition method, 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. 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 balance of $23.2 million previously located on the Company’s consolidated balance sheet was contractually restricted for the purpose of settling asset retirement obligations of Aneth Field. Due to the disposition of Aneth Field, this asset and these obligations were transferred to the purchaser and the associated restricted cash balance is $0 as of December 31, 2017. 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 operations. Cash flows from commodity 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. 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 $5.3 million in deferred financing costs in 2017, $0 in 2016 and $0 in 2015, and amortized $2.7 million, $3.1 million and $5.0 million to interest expense during 2017, 2016 and 2015, respectively. 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). The unique inputs of each of the equity awards are outlined as follows: • Stock option award expense – measured using a Black-Scholes pricing model, no dividends, and expected price volatility and risk-free rates relative to the expected term. • Time-based restricted stock award expense – measured based on the Company’s closing stock price on the date of grant. • TSR award expense – measured based on a Monte Carlo simulation model, no dividends, and expected price volatility and risk-free rates relative to the expected term. Cash-settled incentive award expense is measured quarterly and is amortized over the requisite service period (usually the vesting period). The unique inputs of each of the liability awards are outlined as follows: • Cash-settled stock appreciation rights – measured using a Black-Scholes pricing model, no dividends, and expected price volatility and risk-free rates relative to the expected term. • Time-based restricted cash awards – measured based on the cash value per unit ($1 per unit) on the date of grant. • Performance-based restricted cash awards – measured using a Black-Scholes cash-or-nothing valuation model, no dividends, and expected price volatility and risk-free rates relative to the expected term. The Company estimates forfeitures in calculating the cost related to share-based compensation expense and cash-settled incentive awards expense as opposed to recognizing these forfeitures and the corresponding reduction in expense as they occur. The Company calculates the respective award’s price volatility using an average of the Company’s peer group (as determined by our Total Stockholder Return awards) based on the date of grant or quarterly valuation date for the expected term. Rick-free rates are obtained directly from the U.S. Department of the Treasury. 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 Recent Accounting Pronouncements In January 2017 the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, Revenue from Contracts with Customers (Topic 606) Revenue Recognition During 2017, the Company completed its analysis of the impact of the standard on its contract types, and it does not believe that the adoption of ASU 2014-09 and ASU 2016-12 have material impact on its financial results. The Company has also modified current processes and controls to apply the requirements of the new standard. We do not believe such modifications are material to our internal controls over financial reporting. Additionally, we do not believe that adoption of the standard will impact our operational strategies and financial results. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which requires lessees to present nearly all leasing arrangements on the balance sheet as liabilities along with a corresponding right-of-use asset. The ASU will replace most existing lease guidance in GAAP when it becomes effective. The new standard becomes effective for the Company on January 1, 2019. Although early application is permitted, the Company does not plan to early adopt the ASU. The standard requires the use of the modified retrospective transition method. The Company is evaluating the effect that ASU 2016-02 will have on its consolidated financial statements and related disclosures. Currently, the Company is evaluating the standard’s applicability to our various contractual arrangements. We believe that adoption of the standard will result in increases to our assets and liabilities on our consolidated balance sheet. However, we have not yet determined the extent of the adjustments that will be required upon implementation of the standard. We continue to monitor relevant industry guidance regarding the implementation of ASU 2016-02 and will adjust our implementation strategies as necessary. We are in the process of evaluating the potential impact of adopting the new standard.

Acquisitions and Divestitures

Acquisitions and Divestitures	12 Months Ended
	Dec. 31, 2017
Business Combinations [Abstract]
Acquisitions and Divestitures	Note 3 — Acquisitions and Divestitures Acquisition of Reeves County Properties in the Delaware Basin Delaware Basin Bronco Acquisition In May 2017 Resolute Natural Resources Southwest, LLC (“Resolute Southwest”), a wholly owned subsidiary of the Company, closed on a Purchase and Sale Agreement with CP Exploration II, LLC and Petrocap CPX, LLC pursuant to which Resolute Southwest acquired certain undeveloped and developed oil and gas properties in the Delaware Basin in Reeves County, Texas (the “Delaware Basin Bronco Acquisition”). The acquisition was accounted for as an asset acquisition, and therefore, the properties were recorded based on the fair value of the total consideration transferred on the acquisition date and transaction costs were capitalized as a component of the cost of the assets acquired. The Company acquired these properties for $161.3 million, which it financed substantially with proceeds received from the offering of $125 million of 8.50% Senior Notes due 2020 (as defined in Note 5) that closed in May 2017. The Company recorded $144.8 million of the total consideration transferred as unproved oil and gas property. The properties acquired include approximately 4,600 net acres in Reeves County, Texas (the “Bronco Assets”), which were considered predominantly unproved, 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. Delaware Basin Firewheel Acquisition In October 2016, Resolute and Resolute Southwest closed on a Purchase and Sale Agreement with Firewheel Energy, LLC (“Firewheel”) pursuant to which Resolute Southwest acquired 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 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 as a business combination using the acquisition method. The Company 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 the indicated date below, 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 Divestiture of Aneth Field In November 2017, Resolute Energy Corporation and certain of its wholly-owned subsidiaries closed on a Purchase and Sale Agreement pursuant Resolute’s Under the terms of the Purchase and Sale Agreement, the buyer funded a performance deposit of $10 million which was creditable against the purchase price. In addition to the performance deposit, Resolute received cash consideration of $150 million at closing, subject to normal purchase price adjustments. Additionally, Resolute is entitled to receive additional cash consideration of up to $35 million if oil prices exceed certain levels in the three years after closing, as follows: buyer will pay Resolute $40,000 for each week day in the twelve months after closing that the WTI spot oil price exceeds $52.50 per barrel (up to $10 million); $50,000 for each week day in the twelve months following the first anniversary of closing that the oil price exceeds $55.00 per barrel (up to $10 million) and $60,000 for each week day in the twelve months following the second anniversary of closing that the oil price exceeds $60.00 per barrel (up to $15 million). As of closing, the fair value of the additional consideration was $16.0 million. The proceeds of the sale were used to reduce amounts outstanding under the Company’s Revolving Credit Facility (as defined in Note 5) and for other corporate purposes. retirement . As the sale did not significantly alter the relationship between capital costs and proved reserves, no gain or loss was recognized. In conjunction with the closing of the sale of Aneth Field, certain management members resigned from their positions effective January 1, 2018. In connection with their resignation, these individuals and the Company entered into separation agreements. The material terms of the separation agreements, including compensation payable thereunder and treatment of long-term incentive awards, are consistent with their respective employment agreements with the Company dated January 1, 2017 and various long-term incentive award agreements. As such, Resolute has accrued $2.2 million related to cash severance payments as of December 31, 2017. Effective January 1, 2018, all awards held were modified contemporaneously with the termination of their employment. Divestiture of Southeast New Mexico Properties in the Permian Basin In February 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 in cash, subject to customary purchase price adjustments. The proceeds of the sale were used to reduce amounts outstanding under the Company’s Revolving Credit Facility (as defined in Note 5) and for other corporate purposes. As part of the sale, the Company was also no longer liable for asset retirement obligations of $3.6 million at March 31, 2017. Divestiture of Midstream Assets in the Delaware Basin In July 2016 Resolute Southwest 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). As the sale did not significantly alter the relationship between capital costs and proved reserves, no gain or loss was recognized. 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. In March 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 earned. In 2017, we earned $25.6 million of earn-out payments. 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 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. In April 2017, Resolute Southwest entered into a Crude Oil Connection and Dedication Agreement with Caprock Permian Crude LLC (“Caprock Crude”), an affiliate of Caprock. Pursuant to the agreement, Caprock Crude has constructed the gathering systems, pipelines and other infrastructure for the gathering of crude oil from our Mustang and Appaloosa operating areas in exchange for customary fees based on the volume of crude oil produced and delivered. Resolute Southwest has agreed to dedicate and deliver all crude oil produced from its acreage in Mustang and Appaloosa to Caprock Crude for gathering for a term through July 31, 2031, coterminous with our other commercial agreements with Caprock. For the first five years of the agreement, the crude oil will be delivered to Midland Station under a joint tariff arrangement between Caprock Crude and Plains Pipeline, L.P. In April 2017, Resolute Southwest also entered into a Crude Oil Purchase Contract with Plains Marketing, L.P. (“Plains”) providing for the sale to Plains of substantially all of the crude oil produced from the Mustang and Appaloosa areas for a price equal to an indexed market price less a $1.75 differential that will cover the joint tariff payable to Caprock Crude under the Crude Oil Connection and Dedication Agreement. Pro Forma Financial Information The unaudited pro forma financial information for the years ended December 31, 2017 and 2016, respectively, gives effect to the divestiture of the Aneth Field, the Delaware Basin Firewheel Acquisition, and the sale of the Delaware Basin Midstream Assets as if each had occurred on January 1, 2016 (in thousands, except per share amounts): Year ended December 31, 2017 2016 Revenue $ 229,045 $ 92,711 Income/(loss) from operations 44,128 (86,341 ) Net loss available to common stockholders (8,261 ) (143,100 ) Basic and diluted net loss per share $ (0.38 ) $ (9.15 ) 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, 2017
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”) as well as common shares issuable upon the assumed conversion of the Convertible Preferred Stock (as defined in Note 7) The following table details the potential weighted average dilutive and anti-dilutive securities for the periods presented (in thousands): Twelve Months Ended December 31, 2017 2016 2015 Potential dilutive restricted stock 3,731 1,112 356 Anti-dilutive securities 3,731 3,365 980 The following table sets forth the 2017, 2016 and 2015 computation of basic and diluted net income (loss) per share of common stock for the periods presented (in thousands, except per share amounts): 2017 2016 2015 Net loss available to common stockholders $ (7,708 ) $ (161,722 ) $ (742,279 ) Accumulated undeclared dividends — (1,185 ) — Adjusted net loss available to common shareholders (7,708 ) (162,907 ) (742,279 ) Basic weighted average common shares outstanding 21,889 15,767 14,986 Add: dilutive effect of non-vested restricted stock — — — Diluted weighted average common shares outstanding 21,889 15,767 14,986 Basic and diluted net loss per common share $ (0.35 ) $ (10.33 ) $ (49.55 )

Long Term Debt

Long Term Debt	12 Months Ended
	Dec. 31, 2017
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, 2017 Revolving credit facility $ 30,000 $ — $ (2,513 ) $ 27,487 8.50% senior notes 525,000 2,222 (3,982 ) 523,240 Total long-term debt $ 555,000 $ 2,222 $ (6,495 ) $ 550,727 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 For the years ended December 31, 2017, 2016 and 2015, the Company incurred interest expense on long-term debt of $43.4 million, $50.7 million and $64.4 million, respectively. Approximately $9.7 million in interest expense was incurred in 2017 as a result of the extinguishment of the Secured Term Loan Facility (as defined below) on January 3, 2017. The Company capitalized $15.8 million, $4.1 million and $6.0 million of interest expense during the years ended December 31, 2017, 2016 and 2015, respectively. Revolving Credit Facility In February 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 The Revolving Credit Facility specifies a maximum borrowing base as determined by the lenders sole discretion. 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, Resolute to maintain 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 (as defined in the Revolving Credit Facility) of no more than 4.0 to 1.0. The Revolving Credit Facility also includes customary additional terms and covenants that place limitations on certain types of activities, hedging, the payment of dividends, and that require satisfaction of certain financial tests. In October 2017, the Company entered into the Second Amendment to the Third Amended and Restated Credit Agreement. The Second Amendment, among other things, amended the definition of EBITDA to include customary transaction costs and expenses incurred in connection with any material acquisition or disposition, provided for certain amendments to the calculation of EBITDA for purposes of the Revolving Credit Facility. Additionally, the amended covenants prohibit us from entering into derivative arrangements during which such derivative arrangements are in effect for more than (i) for the first year, the greater of 85% of anticipated projected production from proved properties or 75% of our anticipated projected production from properties, (ii) for the second year, 85% of anticipated projected production from proved properties and (iii) for the period after such two year period, the greater of 75% of our anticipated projected production from proved properties or 85% of our anticipated projected production from proved developed producing properties after such two year period (not to exceed a term of 60 months for any such derivative arrangement). As of December 31, 2017, outstanding borrowings under the Revolving Credit Facility were $30 million with a weighted average interest rate of 4.44%, under a borrowing base of $210 million. The borrowing base availability had been reduced by $2.8 million in conjunction with letters of credit issued at December 31, 2017. 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 within 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 assets of the Company and its wholly-owned subsidiaries. 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. Secured Term Loan Agreement In December 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 we borrowed $150 million (the “Secured Term Loan Facility”). In May 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 with Bank of Montreal, as administrative agent, and the lenders party thereto, pursuant to which we borrowed an additional $50 million of Incremental Term Loans under the Secured Term Loan Facility. In December 2015, the Company retired $70 million of the amount outstanding under the Secured Term Loan Facility following the sale of certain properties in the Midland Basin in accordance with mandatory prepayment provisions stipulated in the Secured Term Loan Facility. In January 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 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 “Original Senior Notes”). The Original Senior Notes are due May 1, 2020, and bear an annual interest rate of 8.50% with the interest on the Original Senior Notes payable semiannually in cash on May 1 and November 1 of each year. In May 2017, the Company consummated a private placement of senior notes totaling an additional $125 million aggregate principal amount of the Company’s 8.50% Senior Notes due 2020 (the “Incremental Senior Notes”), under the same Indenture (the “Indenture”) as the Original Senior Notes that were previously issued (collectively referred to as the “Senior Notes”). The net proceeds of the offering of the Incremental Senior Notes, after reflecting the purchasers’ discounts and commissions, and estimated offering expenses, were approximately $125.1 million. The closing of the Incremental Senior Notes occurred on May 12, 2017. The Senior Notes were issued under an Indenture among the Company and all of the Company’s subsidiaries, each of which is 100% owned by the Company (the “Guarantors”) in a private transaction not subject to the registration requirements of the Securities Act of 1933. In March 2013 and July 2017 the Company registered the exchange of the Original Senior Notes and the Incremental Senior Notes, respectively, with the Securities and Exchange Commission pursuant to registration statements on Form S-4 that enabled holders of the Senior Notes to exchange the privately placed Senior Notes for registered Senior Notes with substantially identical terms. All of the Original Senior Notes and Incremental Senior Notes have been exchanged for publically registered Senior Notes. 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, 2017. 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 a redemption price of 102.125%, reducing to 100.000% at May 1, 2018. 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. The fair value of the Senior Notes at December 31, 2017, was estimated to be $535.1 million based upon data from independent market makers (Level 2 fair value measurement).

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Income Taxes	Note 6 — Income Taxes The following table summarizes the components of the provision for income taxes (in thousands): 2017 2016 2015 Current income tax benefit (expense) $ 293 $ (91 ) $ — Deferred income tax benefit — — 22,354 Total income tax benefit (expense) $ 293 $ (91 ) $ 22,354 The provision for income taxes for the years ended December 31, 2017, 2016 and 2015 differs from the amount that would be provided by applying the statutory maximum U.S. federal corporate 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): 2017 2016 2015 Expected statutory income tax benefit $ 534 $ 56,571 $ 267,621 State income tax benefit (expense) (116 ) 3,087 13,394 Change in state tax rate (2,466 ) — — Equity compensation 34 (2,761 ) (4,822 ) Non-deductible executive compensation (3,825 ) (690 ) — Prior year true up 1,745 — — Tax credits 1,034 — — Other 1,636 (293 ) (247 ) Change in corporate tax rate (1) (114,786 ) — — Valuation allowance 116,503 (56,005 ) (253,592 ) Total income tax benefit (expense) $ 293 $ (91 ) $ 22,354 (1) The change in the statutory maximum U.S. federal corporate income tax rate was enacted in December 2017 by Public Law No. 115-97, commonly referred to as the Tax Cuts and Jobs Act (the “Tax Act”), effective for taxable years beginning on or after January 1, 2018. The Tax Act resulted in the Company generating a deferred tax expense primarily due to the reduction in the U.S. statutory corporate income tax rate from a maximum This deferred tax expense was offset by the valuation allowance placed on the Company's deferred tax assets. Based on the Company’s current interpretation and subject to the release of regulations promulgated by the U.S. Department of Treasury and any other future interpretive guidance relating to the Tax Act, the Company believes the effects of the change in U.S. federal income tax laws incorporated herein are substantially complete 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, 2017 2016 Deferred income tax assets (liabilities): Derivative financial instruments 4,683 4,403 Net operating loss carryovers 164,564 206,663 Asset retirement obligation 613 7,530 Startup and organization costs 51 104 Deferred acquisition costs 26 45 Percentage depletion 582 1,335 Property and equipment costs 12,323 75,267 Equity compensation 1,330 2,267 Tax credits 3,837 283 Other 5,084 11,700 Valuation allowance (193,093 ) (309,597 ) Total long term assets (liabilities) — — Net deferred tax asset (liability) $ — $ — The Company has U.S. net operating loss carry forwards of $723.2 million at December 31, 2017, 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, 2017 and 2016 a valuation allowance should be established against the Company's deferred tax asset. The Company recorded a valuation allowance as of December 31, 2017 and 2016 of $193.1 million and $309.6 million, respectively, on its deferred tax assets. 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, based on the technical merits of the position. In accordance with ASC 740-10, the Company performs 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 2017, 2016 and 2015 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, 2017, 2016 and 2015. 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 2014 through 2017. The tax years that remain open to examination by state taxing authorities are 2013 through 2017.

Stockholders' Equity and Equity

Stockholders' Equity and Equity Based Awards	12 Months Ended
	Dec. 31, 2017
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, 2017 and 2016, the Company had 62,500 shares of preferred stock issued and outstanding. In October 2016, the Company entered into a Purchase Agreement with BMO Capital Markets Corp. (“Initial Purchaser”), pursuant to which the Company agreed to issue and sell to Initial Purchaser 62,500 shares of the Company’s 8⅛% Series B Cumulative Perpetual Convertible Preferred Stock, par value $0.0001 per share (the “Convertible Preferred Stock”), which includes 7,500 additional shares of Convertible Preferred Stock issued pursuant to the exercise of the Initial Purchaser’s over-allotment option 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 During 2017, preferred dividends of $5.2 million were paid. A preferred dividend of $1.3 million was declared on December 19, 2017, and paid on January 16, 2018, to holders of record at the close of business on January 1, 2018. 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, 2017 and 2016, the Company had 22,527,652 and 21,932,842 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 a 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. 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 4,901,548 (which includes the additional 620,000 shares under Amendment No. 2 to the Incentive Plan approved by the Company’s stockholders in June 2015, the 1,000,000 shares under Amendment No. 3 to the Incentive Plan approved by the Company’s stockholders in May 2016 and the 1,450,000 shares under Amendment No. 4 to the Incentive Plan approved by the Company’s stockholders on May 2017). In December 2017, as a result of the Aneth Disposition, certain awards of employees of the Company whose jobs were related to Aneth Field, and who chose to accept employment with the buyer, were modified. Per an employee communication letter dated December 5, 2017, the employees were encouraged to continue employment with Resolute through December 31, 2017 and with the buyer of Aneth Field through March 16, 2018. Upon satisfying these conditions, the vesting terms of the outstanding long-term awards for such employees would be accelerated. Under modification accounting, the modified awards are deemed to be new awards and the original unvested awards’ expense was reversed and the new awards’ expense will be amortized from the date of modification through vest date, March 16, 2018. The modification of the awards resulted in the accelerated vesting of 47,057 time-based restricted shares, 26,177 stock appreciation rights, 47,998 stock options, $552,813 of time-based restricted cash and $31,296 of performance-based restricted cash. Furthermore, in January 2018, as a result of the Aneth Disposition, certain management members resigned from their positions effective January 1, 2018. In connection with their resignation, the individuals and the Company entered into separation agreements. All awards held were modified contemporaneously with the termination of their employment. See Note 12 for a description of the impact of the modification and long-term incentive award grants since December 31, 2017. For the years ended December 31, 2017, 2016 and 2015, the Company recorded expense related to the Incentive Plan as follows (in thousands): Year Ended December 31, 2017 2016 2015 Time-based restricted stock awards $ 5,800 $ 4,359 $ 9,067 TSR awards 5,106 996 2,848 Stock option awards 1,264 936 365 Stock appreciation awards — — 45 Total share-based compensation expense 12,170 6,291 12,325 Time-based restricted cash awards 2,716 3,409 959 Performance-based restricted cash awards 2,012 13,780 226 Cash-settled stock appreciation awards 11,776 17,737 — Total cash-based compensation expense 16,504 34,926 1,185 Total Incentive Plan compensation expense $ 28,674 $ 41,217 $ 13,510 As of December 31, 2017, 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 $ 10,443 2.1 TSR awards 5,112 2.2 Stock option awards 1,597 1.0 Total unrecognized compensation expense $ 17,152 Equity Awards Equity awards consist of time-based and performance-based restricted stock and stock options under the Incentive Plan. 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, 2017, the Company granted 397,967 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: 2017 Weighted Average Grant Date Shares Fair Value Non-vested, beginning of period 151,781 $ 25.07 Granted 397,967 43.04 Vested (126,931 ) 27.22 Forfeited (15,330 ) 33.90 Non-vested, end of period 407,487 $ 41.62 The weighted average TSR Awards In February 2017 the Board and its Compensation Committee awarded performance-based restricted shares to senior employees and 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 twelve 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 Board and its 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 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 estimated forfeiture rates between 0% and 2% which are 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 2017 49.07% - 108.21% 0% 0.83% - 1.45% The following table summarized changes in non-vested TSR Awards for the period presented: 2017 Weighted Average Grant Date Shares Fair Value Non-vested, beginning of period 97,561 $ 66.60 Granted 131,379 77.23 Vested (97,561 ) 66.60 Forfeited (935 ) 77.23 Non-vested, end of period 130,444 $ 77.23 In addition to the vested TSR awards above, 63,024 outperformance shares were also earned and vested during the year ended December 31, 2017, related to the TSR awards granted in 2014. 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: 2017 Weighted Average Aggregate Weighted Remaining Intrinsic Average Contractual Value Shares Exercise Price Term (in thousands) Outstanding, beginning of period 1,052,513 $ 4.03 Exercised (118,199 ) 4.76 Forfeited (16,060 ) 3.51 Outstanding, end of period 918,254 $ 3.95 7.9 $ 25,274 Exercisable, end of period 342,848 $ 4.58 7.8 $ 9,218 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. No options were granted during 2017. The total intrinsic value for options exercised during the years ended December 31, 2017 and 2016, was $3.6 million and $0.5 million, respectively. No options were exercisable during the year ended December 31, 2015. Liability Awards Liability awards consist of awards that are settled in cash instead of shares, as discussed below. The fair value of those instruments at a single point in time is not a forecast of what the estimate fair value of those instruments may be in the future. As the fair value of the liability awards is required to be re-measured at each period end, amounts recognized in future periods will vary. 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 appreciation no dividends and expected price volatility and risk-free rates relative to the expected term 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 based on the cash value per unit ($1 per unit) on the date of grant and utilized estimated forfeiture rates between 0% and 25% 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, 2017, was $9.6 million, of which $7.1 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 was payable at 1x, and the highest stock price hurdle was $40.00 at which the award was 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, 2017, all of the stock price hurdles up to $40.00 had previously been met. A time vesting element will apply to the performance-vested cash awards such that attained multiples will not be paid out earlier than upon satisfaction of a three-year vesting timetable from the date of grant. In order for an award to be paid, both the performance criteria and the time criteria would need to be satisfied. Once a time vesting date passes, the employee is entitled to be paid one third, two thirds or 100%, as applicable, of whatever multiples have been achieved provided the employee continues to be employed by the Company. The estimated fair value of the performance-based restricted cash awards as of December 31, 2017, was $16.6 million of which $16.0 million has been expensed, based upon the three year vesting. The fair value was estimated using Black-Scholes option pricing model for a cash or nothing call, an estimated forfeiture rate of 5%, an average effective term of less than one year, no dividends and expected price volatility and risk-free rates relative to the expected term.

Asset Retirement Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2017
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, 2017 2016 Asset retirement obligations at beginning of period $ 20,352 $ 19,238 Additional liability incurred / acquired 443 587 Accretion expense 1,367 1,790 Liabilities settled / sold (20,292 ) (1,088 ) Revisions to previous estimates 917 (175 ) Asset retirement obligations at end of period 2,787 20,352 Less: current asset retirement obligations (540 ) (895 ) Long-term asset retirement obligations $ 2,247 $ 19,457

Derivative Instruments

Derivative Instruments	12 Months Ended
	Dec. 31, 2017
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Derivative Instruments	Note 9 — Derivative Instruments Commodity 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, 2017, the fair value of the Company’s commodity derivatives was a net liability of $21.3 million (Level 2 fair value measurement). The following table represents Resolute’s commodity swap contracts as of December 31, 2017: Oil (NYMEX WTI) Remaining Term Bbl per Day Weighted Average Swap Price per Bbl Jan – Dec 2018 3,744 $ 51.10 The following table represents Resolute’s three-way commodity collar contracts as of December 31, 2017: 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 2018 3,252 $ 40.15 $ 49.38 $ 54.19 The following table represents Resolute’s commodity option contracts as of December 31, 2017: Oil (NYMEX WTI) Remaining Term Bbl per Day Sold Call Price Jan – Dec 2018 1,100 $ 55.00 Jan – Dec 2019 1,100 $ 62.85 The following table represents Resolute’s basis swap contract as of December 31, 2017: Gas (Permian Basin El Paso) Remaining Term MMBtu per Day Weighted Average Price Differential per MMBtu Jan – Dec 2018 18,000 $ 0.688 Subsequent to December 31, 2017, Resolute entered into additional commodity option contracts as summarized below: Oil (NYMEX WTI) Bought Call Bbl per Day Bought Call Price Feb – May 2018 1,100 $ 55.00 Oil (NYMEX WTI) Sold Call Bbl per Day Sold Call Price Jan – Dec 2019 1,330 $ 65.00 Resolute does not offset the fair value amounts of derivative assets and liabilities with the same counterparty for financial reporting purposes. See Note 10 for the location and fair value amounts of Resolute’s commodity derivative instruments reported in the consolidated balance sheets at December 31, 2017 and 2016. The table below summarizes the location and amount of commodity derivative instrument gains and losses reported in the consolidated statements of income (in thousands): 2017 2016 2015 Other income (expense): Commodity derivative settlements $ 3,730 $ 88,010 $ 93,150 Mark-to-market loss (9,385 ) (107,794 ) (16,658 ) Commodity derivative instruments gain (loss) $ (5,655 ) $ (19,784 ) $ 76,492 Contingent Payment Derivative Instrument In conjunction with the Aneth Disposition in November 2017, Resolute is entitled to receive additional cash consideration of up to $35 million if index pricing targets, as defined in the purchase and sale agreement, are achieved at specified future dates (see Note 3). The contingent consideration will be paid yearly if the pricing exceeds the thresholds pursuant to the purchase and sale agreement. We have evaluated the contract and concluded that it meets the definition and requirements for accounting treatment as a derivative instrument. As of December 31, 2017, the fair value of the additional consideration was $17.9 million. Fair value is determined through an application of mathematical models and Monte Carlo simulations designed to provide fair value estimates utilizing probability measures and the relevant market index . The fair value will be adjusted at each future reporting period . Changes in the fair value are included as a component of contingent payment derivative instrument gain (loss) on our consolidated statements of operations. 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 commodity derivative counterparties are current lenders under Resolute’s Revolving Credit Facility. Accordingly, Resolute is not required to provide any credit support to its commodity derivative counterparties other than cross collateralization with the properties securing the Revolving Credit Facility. Resolute’s commodity 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 commodity derivative contract liabilities. As all of the commodity derivative contracts by counterparty were in a net liability position as of December 31, 2017, the maximum amount of loss in the event of all counterparties defaulting is $0. Resolute is exposed to credit risk to the extent of nonperformance by the buyer with respect to the contingent payment derivative discussed above. The buyer is contractually obligated to pay Resolute the earned contingent payments pursuant to the purchase and sale agreement.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2017
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, 2017, 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. As of December 31, 2017, Resolute’s contingent payment derivative instrument was recorded at its discounted net present value, and will be re-measured each period end over the life of the instrument. Fair value is determined through an application of mathematical models and Monte Carlo simulations Changes in the fair value are included as a component of contingent payment derivative instrument gain (loss) on our Consolidated Statements of Operations. 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 or can be derived from observable data and are therefore designated as Level 2 within the valuation hierarchy. The following is a listing of Resolute’s commodity and contingent payment 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, 2017 and December 31, 2016 (in thousands): Level 2 December 31, 2017 December 31, 2016 Assets Commodity derivative instruments, current $ 526 $ 218 Contingent payment derivative instruments, current 8,311 — Contingent payment derivative instruments, long term 9,635 — Total assets $ 18,472 $ 218 Liabilities Commodity derivative instruments, current $ 20,822 $ 8,014 Commodity derivative instruments, long term 990 4,104 Total liabilities $ 21,812 $ 12,118

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
	Dec. 31, 2017
Commitments And Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 11 — Commitments and Contingencies Operating Leases Rental payments expensed under operating leases for office facilities were approximately $3.0 million, $3.0 million and $1.1 million during 2017, 2016 and 2015, respectively. Net rental payments expensed under operating leases were approximately $0.7 million, $1.7 million and $1.9 million during 2017, 2016 and 2015, respectively. Future payments for the Company’s office facilities and vehicle leases under these operating lease agreements, as of December 31, 2017, are as follows (in thousands): Year Office Lease Rentals Vehicle Lease Rentals Total 2018 $ 1,855 $ 303 $ 2,158 2019 1,403 250 1,653 2020 1,287 221 1,508 2021 1,308 181 1,489 2022 and thereafter 550 83 633 Total $ 6,403 $ 1,038 $ 7,441

Subsequent Events

Subsequent Events	12 Months Ended
	Dec. 31, 2017
Subsequent Events [Abstract]
Subsequent Events	Note 12 — Subsequent Events Long-term incentive award modification In January 2018, as a result of the Aneth Disposition, certain management members resigned from their positions effective January 1, 2018. In connection with their resignation, the individuals and the Company entered into separation agreements. The material terms of the separation agreements, including compensation payable thereunder and treatment of long-term incentive awards, are consistent with their respective employment agreements with the Company dated January 1, 2017 and various long-term incentive award agreements. All awards held were modified contemporaneously with the termination of their employment. Therefore, the awards were measured using the relevant inputs as of January 1, 2018. 2018 Long-term incentive award grant In February 2018, the Board and its Compensation Committee approved long-term incentive awards to employees and nonemployee directors for 2018 on terms generally consistent with the 2017 grant (see Note 7) consisting of a combination of time-vesting restricted stock, performance-vesting restricted stock, and outperformance awards under the Incentive Plan. The 2018 long-term incentive awards to employees and non-employee directors consisted of grants of (i) 332,561 shares of time-vesting restricted stock to employees vesting in three equal annual installments on March 8 of 2019, 2020 and 2021, (ii) 29,058 shares of time-vesting restricted stock to non-employee directors vesting in one installment on February 13, 2019, (iii) 184,657 shares of performance-vesting restricted stock to employees vesting in three equal installments on March 8 of 2019, 2020 and 2021, and (iv) outperformance awards entitling employees to earn up to 184,657 shares in the future and vesting in three equal installments on March 8 of 2019, 2020 and 2021.

Supplemental Oil and Gas Inform

Supplemental Oil and Gas Information	12 Months Ended
	Dec. 31, 2017
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 2017, 2016 and 2015 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): 2017 2016 2015 Acquisition costs Proved $ 20,590 $ 41,830 $ — Unproved 147,442 120,851 6,583 Exploration costs 175,254 101,719 13,764 Development costs* 133,066 31,057 39,883 Total $ 476,352 $ 295,457 $ 60,230 * Includes $3.3 million, $5.9 million and $8.9 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, 2017 and December 31, 2016 were as follows (in thousands): 2017 2016 Proved oil and gas properties $ 2,030,316 $ 1,889,111 Unevaluated oil and gas properties, not subject to amortization 248,059 121,375 Accumulated depletion, depreciation and amortization (1,730,204 ) (1,640,279 ) Oil and gas properties, net $ 548,171 $ 370,207 Oil and Gas Reserve Quantities The reserve data as of December 31, 2017, 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, 2015 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 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 21,427 41,151 6,257 34,543 Sales of minerals in place — — — — Revisions of previous estimates (4,042 ) (3,562 ) (900 ) (5,537 ) Proved reserves as of December 31, 2016 43,804 52,448 7,722 60,267 Purchase of minerals in place 171 704 73 362 Production (5,499 ) (12,101 ) (1,641 ) (9,156 ) Extensions, discoveries and other additions 14,170 60,330 7,394 31,619 Sales of minerals in place (22,821 ) (654 ) (96 ) (23,026 ) Revisions of previous estimates (4,506 ) (5,913 ) (1,143 ) (6,636 ) Proved reserves as of December 31, 2017 25,319 94,814 12,309 53,430 Proved developed reserves: As of December 31, 2017 12,274 46,827 6,136 26,215 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 Proved undeveloped reserves: As of December 31, 2017 13,045 47,987 6,173 27,215 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 (1) Boe is determined using one Bbl of oil or NGL to six Mcf of gas. In accordance with SEC and Financial Accounting Standards Board (“FASB”) requirements, our estimated net proved reserves and standardized measure at December 31, 2017, 2016 and 2015, were determined utilizing prices equal to the twelve-month unweighted arithmetic average using first day of the month prices, resulting in an average Plains Marketing, L.P. posted WTI oil price of $47.79, $39.25 and $46.79 per Bbl and an average Platts Gas Daily El Paso Permian Basin spot gas price of $2.62, $2.31, and $2.45 per MMBtu for the Permian Properties, respectively. Our estimated net proved reserves and standardized measure at December 31, 2016 and 2015 for the Aneth Properties, were determined utilizing prices equal to the respective twelve-month unweighted arithmetic average using the first day of the month prices, resulting in an average NYMEX WTI oil price of $42.75 and $50.28 per Bbl, and an average Platts Gas Daily El Paso San Juan Basin spot gas price of $2.33 and $2.46, respectively Purchase of minerals in place During 2017, purchases of minerals in place consisted of 362 MBoe net from 2 gross producing wells acquired in the Delaware Basin Bronco Acquisition, which closed in May 2017. During 2016, purchase of minerals in place of 3,323 MBoe net were a result of additional ownership in certain existing Permian Basin wells acquired in the Delaware Basin Firewheel acquisition. This number includes 169 MBoe of 2016 production. Production Of the 2017 amount, 20% of the oil equivalent production or 1,816 MBoe (1,734 MBbl oil and 489 MMcf gas) was from Aneth Field properties prior to the divestiture in November, and 80% or 7,341 MBoe (3,765 MBbl oil, 11,612 MMcf gas and 1,641 MBbl NGL) was from the Permian Basin properties. Of the 2016 amount, 44% of the oil equivalent production or 2,255 MBoe (2,132 MBbl oil and 739 MMcf gas) was from Aneth Field properties, and 56% or 2,927 MBoe (1,689 MBbl oil, 4,071 MMcf gas and 559 MBbl NGL) was from Permian Basin properties. Of the 2015 amount, 51% of the oil equivalent production or 2,292 MBoe (2,172 MBbl oil and 717 MMcf gas) was from Aneth Field properties, 39% or 1,782 MBoe (973 MBbl oil, 2,523 MMcf gas and 389 MBbl NGL) was from Permian Basin properties, and 10% or 462 MBoe (125 MBbl oil, 1,954 MMcf gas and 11 MBbl NGL) was from Powder River Basin properties, prior to their divestiture in October. Extensions, discoveries and other additions Extensions, discoveries and other additions in 2017 consisted primarily of 10,741 MBoe net from 16 gross newly drilled Permian wells and 2,722 MBoe net from 7 gross completions of drilled but uncompleted ("DUC") locations acquired in the Delaware Basin Bronco Acquisition together with 11,939 MBoe net from 15 gross immediate offset proved undeveloped Permian locations. These numbers include 2,469 MBoe net of 2017 production. Also included in additions are 6,217 MBoe net of proved undeveloped reserves from 9 gross offset locations to Permian wells drilled prior to 2017 which were uneconomic under previous reports' SEC pricing. Extensions, discoveries Extensions, discoveries Sales of minerals in place Sales of minerals in place during 2017 consisted of 431 MBoe net from 36 gross producing wells in the Denton and Knowles South Fields New Mexico, which were divested in February 2017, plus 22,595 MBoe net from 371 gross producing wells, and their associated injectors, in the divestiture of Aneth Field. These numbers are net of 1,847 MBoe net of 2017 production, 32 MBoe net in Denton and Knowles South Fields, and 1,816 MBoe net in Aneth Field. During 2015, sales of minerals in place of 12,072 MBoe net during 2015 consisted of 5,475 MBoe from 161 gross wells in the Powder River Basin, which was divested in October 2015, 1,698 MBoe from 54 gross wells in the Howard and Martin County properties, which was divested in May and 4,899 MBoe from 102 gross wells in the Gardendale Midland Basin, which was divested in December 2015. These numbers are net of 1,091 MBoe of 2015 production, 462 MBoe in the Powder River Basin, 86 MBoe in Howard and Martin counties, and 543 MBoe in Gardendale. Revisions of previous estimates Revisions of previous estimates of 6,636 MBoe during 2017 were a function of well performance resulting from interference between existing, mature producers and newly drilled wells. The 2018 development plan has been designed to minimize further interference. During 2016, decreased in proved reserves of 5,537 MBoe net was associated with revisions of previous estimates that were primarily a result of reduced product pricing. The average NYMEX West Texas Intermediate oil benchmark price fell 15% from $50.28 per Bbl at December 31, 2015 to $42.75 per Bbl at December 31, 2016. This decrease in product pricing resulted in the deferral of a number of Aneth Field development projects decreasing proved undeveloped reserves by 3,660 MBoe or 66% of the total 2016 revisions of previous estimates. During 2015, decreases in proved reserves of 29,093 MBoe net associated with revisions of previous estimates were primarily a result of reduced product pricing and management's decision to allocate more of its 2015 capital expenditures toward exploitation drilling of higher than expected rates-of-return horizontal wells in the Permian Basin and less capital towards development projects in Aneth Field. The average NYMEX West Texas Intermediate oil benchmark price fell 47% from $94.99 per Bbl at December 31, 2014 to $50.28 per Bbl at December 31, 2015. This decrease in product pricing resulted in deferral of the Aneth CO2 projects which decreased proved undeveloped reserves by 22,786 MBoe or 78% of the total 2015 revisions of previous estimates. 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, 2017. 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, 2017. 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, 2017 2016 2015 (in thousands) Future cash inflows $ 1,623,000 $ 1,800,000 $ 1,293,000 Future production costs (629,000 ) (934,000 ) (774,000 ) Future development costs (285,000 ) (288,000 ) (180,000 ) Future income taxes (3,000 ) (1,000 ) — Future net cash flows 706,000 577,000 339,000 10% annual discount for estimated timing of cash flows (273,000 ) (233,000 ) (140,000 ) Standardized measure of discounted future net cash flows $ 433,000 $ 344,000 $ 199,000 The principal sources of change in the standardized measure of discounted future net cash flows are: December 31, 2017 2016 2015 (in thousands) Standardized measure, beginning of year $ 344,000 $ 199,000 $ 833,000 Sales of oil and gas produced, net of production costs (136,000 ) (82,000 ) (181,000 ) Net changes in prices and production costs 41,000 (106,000 ) (917,000 ) Purchases of minerals in place 5,000 10,000 — Sales of minerals in place (99,000 ) — (134,000 ) Previously estimated development costs incurred during the year 16,000 22,000 33,000 Extensions, discoveries and improved recovery 108,000 268,000 13,000 Changes in estimated future development costs 213,000 12,000 119,000 Revisions of previous quantity estimates (71,000 ) (3,000 ) 196,000 Accretion of discount 25,000 20,000 70,000 Net change in income taxes (1,000 ) — 104,000 Changes in timing and other (12,000 ) 4,000 63,000 Standardized measure, end of year $ 433,000 $ 344,000 $ 199,000

Quarterly Financial Data

Quarterly Financial Data	12 Months Ended
	Dec. 31, 2017
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, 2017 and 2016 (in thousands except per share data). Certain prior period amounts have been reclassified to conform to the current period presentation. Three Months Ended March 31, June 30, September 30, December 31, 2017 2017 2017 2017 Year Ended December 31, 2017: Revenue $ 64,592 $ 70,260 $ 79,371 $ 89,255 Operating expenses (56,202 ) (55,847 ) (71,742 ) (75,668 ) Income from operations 8,390 14,413 7,629 13,587 Net income (loss) available to common shareholders 76 10,690 (14,602 ) (3,872 ) Income (loss) per common share: Basic $ 0.01 $ 0.49 $ (0.71 ) $ (0.18 ) Diluted $ 0.01 $ 0.47 $ (0.71 ) $ (0.18 ) Weighted average common shares outstanding: Basic 21,738 21,917 21,941 21,958 Diluted 22,791 22,894 21,941 21,958 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 available to common shareholders (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

Basis of Presentation and Sum21

Basis of Presentation and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2017
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; 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; and revenue and related receivables.
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 $535.1 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, 2017 2016 Trade receivables $ 18,079 $ 14,898 Revenue receivables 43,136 32,817 Derivative receivables 1,560 5,695 Other receivables 645 1,818 Total accounts receivable $ 63,420 $ 55,228 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 trade receivables are due between fifteen and thirty 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, 2017 and 2016, the Company had no allowance for doubtful accounts recorded.
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 50%, 24% and 15% of its total 2017 revenue from Plains Marketing L.P., Western Refining, Inc. (“Western”) and ETC Field Services, respectively; 47%, 27% and 13% of its total 2016 revenue from Western, Plains Marketing L.P. and Holly Frontier LLC, respectively and 58% and 14% of its total 2015 revenue from Western and Holly Frontier LLC, respectively. If Resolute was compelled to sell its oil and gas 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 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”). In Aneth Field (disposed of in November 2017), Resolute conducted 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 were capitalized at the time incurred. Development costs included 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 provided for improved recovery systems. Improved recovery systems included 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 were considered production costs and were expensed as incurred. These costs included, but were not limited to, compression, electricity, separation, re-injection of recovered CO 2 Capitalized general and administrative and operating costs include salaries, employee benefits, costs of consulting services and other specifically identifiable capital costs and do not include costs related to production operations, general corporate overhead or similar activities. Resolute capitalized general and administrative and operating costs related to its acquisition, exploration and development activities of $6.6 million during 2017, $5.7 million during 2016 and $6.3 million during 2015. 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 an exploration play in the Delaware Basin in Texas. 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, if any, 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. 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 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 2017, 2016 and 2015, the Company recorded $0, $58 million and $705 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 factor impacts 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 full cost ceiling impairment related to its oil and gas properties in such periods.
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. Capitalized interest totaled $15.8 million, $4.1 million and $6.0 million during 2017, 2016 and 2015, respectively.
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, 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.
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 balance of $23.2 million previously located on the Company’s consolidated balance sheet was contractually restricted for the purpose of settling asset retirement obligations of Aneth Field. Due to the disposition of Aneth Field, this asset and these obligations were transferred to the purchaser and the associated restricted cash balance is $0 as of December 31, 2017.
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 operations. Cash flows from commodity 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.
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 $5.3 million in deferred financing costs in 2017, $0 in 2016 and $0 in 2015, and amortized $2.7 million, $3.1 million and $5.0 million to interest expense during 2017, 2016 and 2015, respectively.
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). The unique inputs of each of the equity awards are outlined as follows: • Stock option award expense – measured using a Black-Scholes pricing model, no dividends, and expected price volatility and risk-free rates relative to the expected term. • Time-based restricted stock award expense – measured based on the Company’s closing stock price on the date of grant. • TSR award expense – measured based on a Monte Carlo simulation model, no dividends, and expected price volatility and risk-free rates relative to the expected term. Cash-settled incentive award expense is measured quarterly and is amortized over the requisite service period (usually the vesting period). The unique inputs of each of the liability awards are outlined as follows: • Cash-settled stock appreciation rights – measured using a Black-Scholes pricing model, no dividends, and expected price volatility and risk-free rates relative to the expected term. • Time-based restricted cash awards – measured based on the cash value per unit ($1 per unit) on the date of grant. • Performance-based restricted cash awards – measured using a Black-Scholes cash-or-nothing valuation model, no dividends, and expected price volatility and risk-free rates relative to the expected term. The Company estimates forfeitures in calculating the cost related to share-based compensation expense and cash-settled incentive awards expense as opposed to recognizing these forfeitures and the corresponding reduction in expense as they occur. The Company calculates the respective award’s price volatility using an average of the Company’s peer group (as determined by our Total Stockholder Return awards) based on the date of grant or quarterly valuation date for the expected term. Rick-free rates are obtained directly from the U.S. Department of the Treasury.
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
Recent Accounting Pronouncements	Recent Accounting Pronouncements In January 2017 the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2017-01, Business Combinations (Topic 805): Clarifying the Definition of a Business In May 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-09, Revenue from Contracts with Customers (Topic 606) Revenue Recognition During 2017, the Company completed its analysis of the impact of the standard on its contract types, and it does not believe that the adoption of ASU 2014-09 and ASU 2016-12 have material impact on its financial results. The Company has also modified current processes and controls to apply the requirements of the new standard. We do not believe such modifications are material to our internal controls over financial reporting. Additionally, we do not believe that adoption of the standard will impact our operational strategies and financial results. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842), which requires lessees to present nearly all leasing arrangements on the balance sheet as liabilities along with a corresponding right-of-use asset. The ASU will replace most existing lease guidance in GAAP when it becomes effective. The new standard becomes effective for the Company on January 1, 2019. Although early application is permitted, the Company does not plan to early adopt the ASU. The standard requires the use of the modified retrospective transition method. The Company is evaluating the effect that ASU 2016-02 will have on its consolidated financial statements and related disclosures. Currently, the Company is evaluating the standard’s applicability to our various contractual arrangements. We believe that adoption of the standard will result in increases to our assets and liabilities on our consolidated balance sheet. However, we have not yet determined the extent of the adjustments that will be required upon implementation of the standard. We continue to monitor relevant industry guidance regarding the implementation of ASU 2016-02 and will adjust our implementation strategies as necessary. We are in the process of evaluating the potential impact of adopting the new standard.

Basis of Presentation and Sum22

Basis of Presentation and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Accounts Receivable	The Company’s accounts receivable consist of the following for the periods indicated (in thousands): December 31, 2017 2016 Trade receivables $ 18,079 $ 14,898 Revenue receivables 43,136 32,817 Derivative receivables 1,560 5,695 Other receivables 645 1,818 Total accounts receivable $ 63,420 $ 55,228

Acquisitions and Divestitures (

Acquisitions and Divestitures (Tables)	12 Months Ended
	Dec. 31, 2017
Business Combinations [Abstract]
Purchase Price Allocation of Delaware Basin Firewheel Acquisitions	The Company 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 the indicated date below, 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, 2017 and 2016, respectively, gives effect to the divestiture of the Aneth Field, the Delaware Basin Firewheel Acquisition, and the sale of the Delaware Basin Midstream Assets as if each had occurred on January 1, 2016 (in thousands, except per share amounts): Year ended December 31, 2017 2016 Revenue $ 229,045 $ 92,711 Income/(loss) from operations 44,128 (86,341 ) Net loss available to common stockholders (8,261 ) (143,100 ) Basic and diluted net loss per share $ (0.38 ) $ (9.15 )

Earnings per Share (Tables)

Earnings per Share (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 2016 2015 Potential dilutive restricted stock 3,731 1,112 356 Anti-dilutive securities 3,731 3,365 980
Computation of Basic and Diluted Net Income (Loss) per Share of Common Stock	The following table sets forth the 2017, 2016 and 2015 computation of basic and diluted net income (loss) per share of common stock for the periods presented (in thousands, except per share amounts): 2017 2016 2015 Net loss available to common stockholders $ (7,708 ) $ (161,722 ) $ (742,279 ) Accumulated undeclared dividends — (1,185 ) — Adjusted net loss available to common shareholders (7,708 ) (162,907 ) (742,279 ) Basic weighted average common shares outstanding 21,889 15,767 14,986 Add: dilutive effect of non-vested restricted stock — — — Diluted weighted average common shares outstanding 21,889 15,767 14,986 Basic and diluted net loss per common share $ (0.35 ) $ (10.33 ) $ (49.55 )

Long Term Debt (Tables)

Long Term Debt (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 Revolving credit facility $ 30,000 $ — $ (2,513 ) $ 27,487 8.50% senior notes 525,000 2,222 (3,982 ) 523,240 Total long-term debt $ 555,000 $ 2,222 $ (6,495 ) $ 550,727 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

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Components of Provision for Income Taxes	The following table summarizes the components of the provision for income taxes (in thousands): 2017 2016 2015 Current income tax benefit (expense) $ 293 $ (91 ) $ — Deferred income tax benefit — — 22,354 Total income tax benefit (expense) $ 293 $ (91 ) $ 22,354
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, 2017, 2016 and 2015 differs from the amount that would be provided by applying the statutory maximum U.S. federal corporate 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): 2017 2016 2015 Expected statutory income tax benefit $ 534 $ 56,571 $ 267,621 State income tax benefit (expense) (116 ) 3,087 13,394 Change in state tax rate (2,466 ) — — Equity compensation 34 (2,761 ) (4,822 ) Non-deductible executive compensation (3,825 ) (690 ) — Prior year true up 1,745 — — Tax credits 1,034 — — Other 1,636 (293 ) (247 ) Change in corporate tax rate (1) (114,786 ) — — Valuation allowance 116,503 (56,005 ) (253,592 ) Total income tax benefit (expense) $ 293 $ (91 ) $ 22,354 (1) The change in the statutory maximum U.S. federal corporate income tax rate was enacted in December 2017 by Public Law No. 115-97, commonly referred to as the Tax Cuts and Jobs Act (the “Tax Act”), effective for taxable years beginning on or after January 1, 2018. The Tax Act resulted in the Company generating a deferred tax expense primarily due to the reduction in the U.S. statutory corporate income tax rate from a maximum This deferred tax expense was offset by the valuation allowance placed on the Company's deferred tax assets. Based on the Company’s current interpretation and subject to the release of regulations promulgated by the U.S. Department of Treasury and any other future interpretive guidance relating to the Tax Act, the Company believes the effects of the change in U.S. federal income tax laws incorporated herein are substantially complete
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, 2017 2016 Deferred income tax assets (liabilities): Derivative financial instruments 4,683 4,403 Net operating loss carryovers 164,564 206,663 Asset retirement obligation 613 7,530 Startup and organization costs 51 104 Deferred acquisition costs 26 45 Percentage depletion 582 1,335 Property and equipment costs 12,323 75,267 Equity compensation 1,330 2,267 Tax credits 3,837 283 Other 5,084 11,700 Valuation allowance (193,093 ) (309,597 ) 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, 2017
Expense Related to Incentive Plan	For the years ended December 31, 2017, 2016 and 2015, the Company recorded expense related to the Incentive Plan as follows (in thousands): Year Ended December 31, 2017 2016 2015 Time-based restricted stock awards $ 5,800 $ 4,359 $ 9,067 TSR awards 5,106 996 2,848 Stock option awards 1,264 936 365 Stock appreciation awards — — 45 Total share-based compensation expense 12,170 6,291 12,325 Time-based restricted cash awards 2,716 3,409 959 Performance-based restricted cash awards 2,012 13,780 226 Cash-settled stock appreciation awards 11,776 17,737 — Total cash-based compensation expense 16,504 34,926 1,185 Total Incentive Plan compensation expense $ 28,674 $ 41,217 $ 13,510
Unrecognized Compensation Expense and Weighted Average Period Related to Incentive Plan	As of December 31, 2017, 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 $ 10,443 2.1 TSR awards 5,112 2.2 Stock option awards 1,597 1.0 Total unrecognized compensation expense $ 17,152
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 2017 49.07% - 108.21% 0% 0.83% - 1.45%
Changes in Non-Vested Stock Option Awards	The following table summarizes the changes in non-vested option awards for the period presented: 2017 Weighted Average Aggregate Weighted Remaining Intrinsic Average Contractual Value Shares Exercise Price Term (in thousands) Outstanding, beginning of period 1,052,513 $ 4.03 Exercised (118,199 ) 4.76 Forfeited (16,060 ) 3.51 Outstanding, end of period 918,254 $ 3.95 7.9 $ 25,274 Exercisable, end of period 342,848 $ 4.58 7.8 $ 9,218
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: 2017 Weighted Average Grant Date Shares Fair Value Non-vested, beginning of period 151,781 $ 25.07 Granted 397,967 43.04 Vested (126,931 ) 27.22 Forfeited (15,330 ) 33.90 Non-vested, end of period 407,487 $ 41.62
TSR awards
Changes in Non-Vested Awards	The following table summarized changes in non-vested TSR Awards for the period presented: 2017 Weighted Average Grant Date Shares Fair Value Non-vested, beginning of period 97,561 $ 66.60 Granted 131,379 77.23 Vested (97,561 ) 66.60 Forfeited (935 ) 77.23 Non-vested, end of period 130,444 $ 77.23

Asset Retirement Obligation (Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 2016 Asset retirement obligations at beginning of period $ 20,352 $ 19,238 Additional liability incurred / acquired 443 587 Accretion expense 1,367 1,790 Liabilities settled / sold (20,292 ) (1,088 ) Revisions to previous estimates 917 (175 ) Asset retirement obligations at end of period 2,787 20,352 Less: current asset retirement obligations (540 ) (895 ) Long-term asset retirement obligations $ 2,247 $ 19,457

Derivative Instruments (Tables)

Derivative Instruments (Tables)	12 Months Ended
	Dec. 31, 2017
Derivative [Line Items]
Commodity Contracts and Swaps	The following table represents Resolute’s commodity option contracts as of December 31, 2017: Oil (NYMEX WTI) Remaining Term Bbl per Day Sold Call Price Jan – Dec 2018 1,100 $ 55.00 Jan – Dec 2019 1,100 $ 62.85 Subsequent to December 31, 2017, Resolute entered into additional commodity option contracts as summarized below: Oil (NYMEX WTI) Bought Call Bbl per Day Bought Call Price Feb – May 2018 1,100 $ 55.00 Oil (NYMEX WTI) Sold Call Bbl per Day Sold Call Price Jan – Dec 2019 1,330 $ 65.00
Amount of Commodity Derivative Instrument Gains (Losses)	The table below summarizes the location and amount of commodity derivative instrument gains and losses reported in the consolidated statements of income (in thousands): 2017 2016 2015 Other income (expense): Commodity derivative settlements $ 3,730 $ 88,010 $ 93,150 Mark-to-market loss (9,385 ) (107,794 ) (16,658 ) Commodity derivative instruments gain (loss) $ (5,655 ) $ (19,784 ) $ 76,492
Three-Way Commodity Collar Contract
Derivative [Line Items]
Commodity Contracts and Swaps	The following table represents Resolute’s three-way commodity collar contracts as of December 31, 2017: 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 2018 3,252 $ 40.15 $ 49.38 $ 54.19
Commodity Swap Contracts
Derivative [Line Items]
Commodity Contracts and Swaps	The following table represents Resolute’s commodity swap contracts as of December 31, 2017: Oil (NYMEX WTI) Remaining Term Bbl per Day Weighted Average Swap Price per Bbl Jan – Dec 2018 3,744 $ 51.10
Basis Swap Contract
Derivative [Line Items]
Commodity Contracts and Swaps	The following table represents Resolute’s basis swap contract as of December 31, 2017: Gas (Permian Basin El Paso) Remaining Term MMBtu per Day Weighted Average Price Differential per MMBtu Jan – Dec 2018 18,000 $ 0.688

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2017
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 and contingent payment 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, 2017 and December 31, 2016 (in thousands): Level 2 December 31, 2017 December 31, 2016 Assets Commodity derivative instruments, current $ 526 $ 218 Contingent payment derivative instruments, current 8,311 — Contingent payment derivative instruments, long term 9,635 — Total assets $ 18,472 $ 218 Liabilities Commodity derivative instruments, current $ 20,822 $ 8,014 Commodity derivative instruments, long term 990 4,104 Total liabilities $ 21,812 $ 12,118

Commitments and Contingencies (

Commitments and Contingencies (Tables)	12 Months Ended
	Dec. 31, 2017
Commitments And Contingencies Disclosure [Abstract]
Schedule of Future Payment Operating Leases Agreements	Future payments for the Company’s office facilities and vehicle leases under these operating lease agreements, as of December 31, 2017, are as follows (in thousands): Year Office Lease Rentals Vehicle Lease Rentals Total 2018 $ 1,855 $ 303 $ 2,158 2019 1,403 250 1,653 2020 1,287 221 1,508 2021 1,308 181 1,489 2022 and thereafter 550 83 633 Total $ 6,403 $ 1,038 $ 7,441

Supplemental Oil and Gas Info32

Supplemental Oil and Gas Information (Tables)	12 Months Ended
	Dec. 31, 2017
Extractive Industries [Abstract]
Costs Incurred in Oil and Gas Property Acquisition Exploration and Development Activities	Costs incurred during 2017, 2016 and 2015 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): 2017 2016 2015 Acquisition costs Proved $ 20,590 $ 41,830 $ — Unproved 147,442 120,851 6,583 Exploration costs 175,254 101,719 13,764 Development costs* 133,066 31,057 39,883 Total $ 476,352 $ 295,457 $ 60,230 * Includes $3.3 million, $5.9 million and $8.9 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, 2017 and December 31, 2016 were as follows (in thousands): 2017 2016 Proved oil and gas properties $ 2,030,316 $ 1,889,111 Unevaluated oil and gas properties, not subject to amortization 248,059 121,375 Accumulated depletion, depreciation and amortization (1,730,204 ) (1,640,279 ) Oil and gas properties, net $ 548,171 $ 370,207
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, 2015 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 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 21,427 41,151 6,257 34,543 Sales of minerals in place — — — — Revisions of previous estimates (4,042 ) (3,562 ) (900 ) (5,537 ) Proved reserves as of December 31, 2016 43,804 52,448 7,722 60,267 Purchase of minerals in place 171 704 73 362 Production (5,499 ) (12,101 ) (1,641 ) (9,156 ) Extensions, discoveries and other additions 14,170 60,330 7,394 31,619 Sales of minerals in place (22,821 ) (654 ) (96 ) (23,026 ) Revisions of previous estimates (4,506 ) (5,913 ) (1,143 ) (6,636 ) Proved reserves as of December 31, 2017 25,319 94,814 12,309 53,430 Proved developed reserves: As of December 31, 2017 12,274 46,827 6,136 26,215 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 Proved undeveloped reserves: As of December 31, 2017 13,045 47,987 6,173 27,215 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 (1) Boe is determined using one Bbl of oil or NGL to six Mcf of gas. In accordance with SEC and Financial Accounting Standards Board (“FASB”) requirements, our estimated net proved reserves and standardized measure at December 31, 2017, 2016 and 2015, were determined utilizing prices equal to the twelve-month unweighted arithmetic average using first day of the month prices, resulting in an average Plains Marketing, L.P. posted WTI oil price of $47.79, $39.25 and $46.79 per Bbl and an average Platts Gas Daily El Paso Permian Basin spot gas price of $2.62, $2.31, and $2.45 per MMBtu for the Permian Properties, respectively. Our estimated net proved reserves and standardized measure at December 31, 2016 and 2015 for the Aneth Properties, were determined utilizing prices equal to the respective twelve-month unweighted arithmetic average using the first day of the month prices, resulting in an average NYMEX WTI oil price of $42.75 and $50.28 per Bbl, and an average Platts Gas Daily El Paso San Juan Basin spot gas price of $2.33 and $2.46, respectively
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, 2017 2016 2015 (in thousands) Future cash inflows $ 1,623,000 $ 1,800,000 $ 1,293,000 Future production costs (629,000 ) (934,000 ) (774,000 ) Future development costs (285,000 ) (288,000 ) (180,000 ) Future income taxes (3,000 ) (1,000 ) — Future net cash flows 706,000 577,000 339,000 10% annual discount for estimated timing of cash flows (273,000 ) (233,000 ) (140,000 ) Standardized measure of discounted future net cash flows $ 433,000 $ 344,000 $ 199,000
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, 2017 2016 2015 (in thousands) Standardized measure, beginning of year $ 344,000 $ 199,000 $ 833,000 Sales of oil and gas produced, net of production costs (136,000 ) (82,000 ) (181,000 ) Net changes in prices and production costs 41,000 (106,000 ) (917,000 ) Purchases of minerals in place 5,000 10,000 — Sales of minerals in place (99,000 ) — (134,000 ) Previously estimated development costs incurred during the year 16,000 22,000 33,000 Extensions, discoveries and improved recovery 108,000 268,000 13,000 Changes in estimated future development costs 213,000 12,000 119,000 Revisions of previous quantity estimates (71,000 ) (3,000 ) 196,000 Accretion of discount 25,000 20,000 70,000 Net change in income taxes (1,000 ) — 104,000 Changes in timing and other (12,000 ) 4,000 63,000 Standardized measure, end of year $ 433,000 $ 344,000 $ 199,000

Quarterly Financial Data (Table

Quarterly Financial Data (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 and 2016 (in thousands except per share data). Certain prior period amounts have been reclassified to conform to the current period presentation. Three Months Ended March 31, June 30, September 30, December 31, 2017 2017 2017 2017 Year Ended December 31, 2017: Revenue $ 64,592 $ 70,260 $ 79,371 $ 89,255 Operating expenses (56,202 ) (55,847 ) (71,742 ) (75,668 ) Income from operations 8,390 14,413 7,629 13,587 Net income (loss) available to common shareholders 76 10,690 (14,602 ) (3,872 ) Income (loss) per common share: Basic $ 0.01 $ 0.49 $ (0.71 ) $ (0.18 ) Diluted $ 0.01 $ 0.47 $ (0.71 ) $ (0.18 ) Weighted average common shares outstanding: Basic 21,738 21,917 21,941 21,958 Diluted 22,791 22,894 21,941 21,958 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 available to common shareholders (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

Basis of Presentation and Sum34

Basis of Presentation and Summary of Significant Accounting Policies - Additional Information (Detail)	1 Months Ended	12 Months Ended
	May 31, 2015$ / shares	Dec. 31, 2017USD ($)Segment$ / shares	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Number of Operating Segments | Segment		1
Allowance for doubtful accounts		$ 0	$ 0
Capitalized general and administrative and operating costs		$ 6,600,000	$ 5,700,000	$ 6,300,000
Discount factor		10.00%	10.00%	10.00%
Impairment of proved oil and gas properties		$ 0	$ 58,000,000	$ 705,000,000
Capitalized Interest		15,800,000	4,100,000	6,000,000
Restricted cash		23,200,000
Deferred financing cost		5,300,000	0	0
Deferred financing cost amortization interest expense		$ 2,700,000	$ 3,100,000	$ 5,000,000
Stock Option Awards
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Expected dividend yield		0.00%
Average expected volatility		0.00%
Risk-free rates		0.00%
TSR awards
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Expected dividend yield		0.00%
Average expected volatility		0.00%
Risk-free rates		0.00%
Cash-Settled Stock Appreciation Rights
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Expected dividend yield		0.00%
Average expected volatility		0.00%
Risk-free rates		0.00%
Time-based Restricted Cash Awards
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Common stock, hurdle stock price | $ / shares		$ 1
Performance Based Restricted Cash Awards
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Expected dividend yield		0.00%
Average expected volatility		0.00%
Risk-free rates		0.00%
Common stock, hurdle stock price | $ / shares	$ 10	$ 40
Aneth Disposition
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Restricted cash		$ 0
Maximum | Performance Based Restricted Cash Awards
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Common stock, hurdle stock price | $ / shares	$ 40
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		24.00%	47.00%	58.00%
Revenue | Plains Marketing LP | Customer Concentration Risk
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Concentration of credit risk percentage		50.00%	27.00%
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%
Revenue | ETC Field Services
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Concentration of credit risk percentage		15.00%
Senior Notes
Organization And Summary Of Significant Accounting Policies Disclosure [Line Items]
Long-term debt, fair value		$ 535,100,000
Debt instrument, maturity date		May 1, 2020

Accounts Receivable (Detail)

Accounts Receivable (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Receivables [Abstract]
Trade receivables	$ 18,079	$ 14,898
Revenue receivables	43,136	32,817
Derivative receivables	1,560	5,695
Other receivables	645	1,818
Total accounts receivable	$ 63,420	$ 55,228

Acquisitions and Divestitures -

Acquisitions and Divestitures - Additional Information (Detail)

1 Months Ended

3 Months Ended

12 Months Ended

Nov. 30, 2017USD ($)

May 31, 2017USD ($)a

Mar. 31, 2017

Oct. 31, 2016USD ($)$ / sharesshares

Aug. 31, 2016USD ($)

Jul. 31, 2016USD ($)

Mar. 31, 2017USD ($)

Dec. 31, 2017USD ($)$ / shares

Dec. 31, 2016USD ($)$ / shares

Apr. 02, 2017$ / bbl

Feb. 28, 2017USD ($)

Jun. 30, 2016$ / shares

Business Acquisitions And Divestitures [Line Items]

Common stock, par value | $ / shares

$ 0.0001

$ 0.0001

$ 0.0001

Asset Retirement Obligation Liabilities Settled

$ 20,292,000

$ 1,088,000

Earn-out payment earned

25,600,000

Differential to indexed market price that will cover joint tariff payable | $ / bbl

1.75

Divestiture of Aneth Field

Business Acquisitions And Divestitures [Line Items]

Buyer funded performance deposit

$ 10,000,000

Cash consideration received

150,000,000

Receive additional cash consideration upon condition

16,000,000

Asset Retirement Obligation Liabilities Settled

15,800,000

Recognized gain (loss) on sale

0

Accrued cash severance payments

2,200,000

Denton and South Knowles

Business Acquisitions And Divestitures [Line Items]

Asset Retirement Obligation Liabilities Settled

$ 3,600,000

Sale of properties

$ 14,500,000

Maximum | Divestiture of Aneth Field

Business Acquisitions And Divestitures [Line Items]

Receive additional cash consideration upon condition

35,000,000

Maximum | Forty Thousand Per Week If Oil Price Exceeds Fifty Two Dollar And Fifty Cents Per Barrel | Divestiture of Aneth Field

Business Acquisitions And Divestitures [Line Items]

Receive additional cash consideration upon condition

10,000,000

Maximum | Fifty Thousand Per Week If Oil Price Exceeds Fifty Dollar Per Barrel | Divestiture of Aneth Field

Business Acquisitions And Divestitures [Line Items]

Receive additional cash consideration upon condition

10,000,000

Maximum | Sixty Thousand Per Week If Oil Price Exceeds Sixty Dollar Per Barrel | Divestiture of Aneth Field

Business Acquisitions And Divestitures [Line Items]

Receive additional cash consideration upon condition

$ 15,000,000

8.50% senior notes

Business Acquisitions And Divestitures [Line Items]

Principal amount

$ 125,000,000

$ 400,000,000

Debt instrument, interest rate

8.50%

8.50%

8.50%

Debt instrument, maturity date

May 1, 2020

Delaware Basin Bronco Acquisition

Business Acquisitions And Divestitures [Line Items]

Purchase agreement purchase price of properties

$ 161,300,000

Oil and gas properties

$ 144,800,000

Firewheel Energy, LLC

Business Acquisitions And Divestitures [Line Items]

Purchase agreement purchase price of properties

$ 153,200,000

Cash consideration

$ 90,000,000

Common stock shares, issued | shares

2,114,523

Common stock, par value | $ / shares

$ 0.0001

Mustang Agreement

Business Acquisitions And Divestitures [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 Acquisitions And Divestitures [Line Items]

Transaction date

Jul. 31, 2016

Purchase agreement purchase price of properties

$ 15,000,000

Appaloosa And Mustang Agreement

Business Acquisitions And Divestitures [Line Items]

Transaction date

Aug. 31, 2016

Recognized gain (loss) on sale

$ 0

Sale of properties

$ 36,000,000

Earn-out Agreement date

Jul. 31, 2016

Earn-out agreement amendment date

Mar. 31, 2017

Period of agreement

15 years

Purchase and Sale Agreement | Texas

Business Acquisitions And Divestitures [Line Items]

Area of properties acquired, net | a

4,600

Purchase and Sale Agreement | Reeves County, Texas

Business Acquisitions And Divestitures [Line Items]

Area of properties acquired, net | a

2,187

Purchase and Sale Agreement | Southern Reeves County

Business Acquisitions And Divestitures [Line Items]

Area of properties acquired, net | a

2,405

Purchase and Sale Agreement | Delaware Basin Bronco Acquisition

Business Acquisitions And Divestitures [Line Items]

Transaction date

May 31, 2017

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) - Aneth Field Firewheel Acquisition and Sale of Delaware Basin Midstream Assets - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Business Acquisition [Line Items]
Revenue	$ 229,045	$ 92,711
Income/(loss) from operations	44,128	(86,341)
Net loss available to common stockholders	$ (8,261)	$ (143,100)
Basic and diluted net loss per share	$ (0.38)	$ (9.15)

Weighted Average Dilutive and A

Weighted Average Dilutive and Anti-Dilutive Securities (Detail) - shares shares in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Earnings Per Share [Abstract]
Potential dilutive restricted stock	3,731	1,112	356
Anti-dilutive securities	3,731	3,365	980

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, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Earnings Per Share [Abstract]
Net loss available to common stockholders	$ (3,872)	$ (14,602)	$ 10,690	$ 76	$ (20,648)	$ (18,856)	$ (36,906)	$ (85,312)	$ (7,708)	$ (161,722)	$ (742,279)
Accumulated undeclared dividends										(1,185)
Adjusted net loss available to common shareholders									$ (7,708)	$ (162,907)	$ (742,279)
Basic weighted average common shares outstanding	21,958	21,941	21,917	21,738					21,889	15,767	14,986
Diluted weighted average common shares outstanding	21,958	21,941	22,894	22,791					21,889	15,767	14,986
Basic and diluted net loss per common share					$ (1.23)	$ (1.24)	$ (2.44)	$ (5.65)	$ (0.35)	$ (10.33)	$ (49.55)

Long-term Debt (Detail)

Long-term Debt (Detail) - USD ($)	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Principal	$ 555,000,000	$ 538,303,000
Unamortized premium/ (discount)	2,222,000	(3,897,000)
Unamortized deferred financing costs	(6,495,000)	(6,292,000)
Total long-term debt	550,727,000	528,114,000
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	30,000,000	10,000,000
Unamortized deferred financing costs	(2,513,000)	(1,179,000)
Total long-term debt	27,487,000	8,821,000
Secured term loan facility
Debt Instrument [Line Items]
Principal		128,303,000
Unamortized premium/ (discount)		(4,882,000)
Unamortized deferred financing costs		(1,282,000)
Total long-term debt		122,139,000
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	525,000,000	400,000,000
Unamortized premium/ (discount)	2,222,000	985,000
Unamortized deferred financing costs	(3,982,000)	(3,831,000)
Total long-term debt	$ 523,240,000	$ 397,154,000

Long-term Debt (Parenthetical)

Long-term Debt (Parenthetical) (Detail)	Dec. 31, 2017	May 31, 2017	Dec. 31, 2016
8.50% senior notes
Debt Instrument [Line Items]
Debt instrument, interest rate	8.50%	8.50%	8.50%

Long Term Debt - Additional Inf

Long Term Debt - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt Instrument [Line Items]
Interest Expense on Long-term debt	$ 43.4	$ 50.7	$ 64.4
Interest expense capitalized	15.8	$ 4.1	$ 6
Secured term loan facility
Debt Instrument [Line Items]
Interest Expense on Long-term debt	$ 9.7

Long Term Debt - Revolving Cred

Long Term Debt - Revolving Credit Facility - Additional Information (Detail) - USD ($)	Feb. 17, 2017	Oct. 31, 2017	Dec. 31, 2017	Dec. 31, 2016
Debt Instrument [Line Items]
Principal			$ 555,000,000	$ 538,303,000
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
Debt Instrument [Line Items]
Revolving credit facility, maturity date	Feb. 28, 2021
Revolving credit facility
Debt Instrument [Line Items]
Current assets to current liabilities ratio			100.00%
Secured debt to EBITDA ratio maximum			400.00%
Revolving Credit Facility covenant description			covenants that require, among other things, Resolute to maintain 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 (as defined in the Revolving Credit Facility) of no more than 4.0 to 1.0. The Revolving Credit Facility also includes customary additional terms and covenants that place limitations on certain types of activities, hedging, the payment of dividends, and that require satisfaction of certain financial tests.
Derivative agreement, percentage of anticipated projected production from properties		75.00%
Derivative agreement, percentage of anticipated projected production from proved properties		85.00%
Line of credit, borrowing base		$ 218,800,000	$ 210,000,000
Line of credit facility reduction in borrowing capacity			2,800,000
Percentage of borrowing base reduction in unsecured indebtedness		25.00%
Debt instrument unsecured indebtedness in excess amount		$ 550,000,000
Principal			$ 30,000,000	$ 10,000,000
Weighted average interest rate			4.44%
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%.
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	1 Months Ended	12 Months Ended
	Jan. 31, 2017	Dec. 31, 2017	Dec. 31, 2015	May 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Outstanding borrowings under term loan facility					$ 150,000
Repayment of secured term loan with proceeds			$ 70,000
Repayments of debt		$ 128,303	$ 71,697
Secured Term Loan Agreement
Debt Instrument [Line Items]
Repayments of debt	$ 132,000
Secured Term Loan Agreement | Incremental Term Loan
Debt Instrument [Line Items]
Incremental borrowings under term loan facility				$ 50,000

Long Term Debt - Senior Notes -

Long Term Debt - Senior Notes - Additional Information (Detail) $ in Millions	May 01, 2018	May 31, 2017USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2012PrivatePlacement	Dec. 31, 2016
Maximum
Debt Instrument [Line Items]
Senior Notes, redemption notice period			60 days
Guarantor Subsidiaries
Debt Instrument [Line Items]
Ownership interest in subsidiaries by the company			100.00%
Senior Notes
Debt Instrument [Line Items]
Principal amount		$ 125	$ 400
Debt instrument, maturity date			May 1, 2020
Debt instrument, interest rate		8.50%	8.50%		8.50%
Net proceeds from offering of Incremental Senior Notes		$ 125.1
Senior Notes, redemption price percentage of principal	100.00%		102.125%
Long-term debt, fair value			$ 535.1
Senior Notes | Level 2
Debt Instrument [Line Items]
Long-term debt, fair value			$ 535.1
Senior Notes | Minimum
Debt Instrument [Line Items]
Senior Notes, redemption notice period			30 days
Senior Notes | Change of Control
Debt Instrument [Line Items]
Senior Notes, redemption price percentage of principal			101.00%
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, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Current income tax benefit (expense)	$ 293	$ (91)
Deferred income tax benefit			$ 22,354
Total income tax benefit (expense)	$ 293	$ (91)	$ 22,354

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Taxes [Line Items]
U.S. federal corporate income tax rate	35.00%	35.00%	35.00%
U.S. net operating loss carryforwards	$ 723,200,000
U.S. net operating loss carryforwards, beginning of expiration date	2,026
Deferred tax assets, valuation allowance	$ 193,093,000	$ 309,597,000
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	2,014
Earliest Tax Year | State Taxing Authorities
Income Taxes [Line Items]
Tax years open to examination	2,013
Latest Tax Year | Internal Revenue Service
Income Taxes [Line Items]
Tax years open to examination	2,017
Latest Tax Year | State Taxing Authorities
Income Taxes [Line Items]
Tax years open to examination	2,017

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Expected statutory income tax benefit		$ 534	$ 56,571	$ 267,621
State income tax benefit (expense)		(116)	3,087	13,394
Change in state tax rate		(2,466)
Equity compensation		34	(2,761)	(4,822)
Non-deductible executive compensation		(3,825)	(690)
Prior year true up		1,745
Tax credits		1,034
Other		1,636	(293)	(247)
Change in corporate tax rate	[1]	(114,786)
Valuation allowance		116,503	(56,005)	(253,592)
Total income tax benefit (expense)		$ 293	$ (91)	$ 22,354
[1]	The change in the statutory maximum U.S. federal corporate income tax rate was enacted in December 2017 by Public Law No. 115-97, commonly referred to as the Tax Cuts and Jobs Act (the “Tax Act”), effective for taxable years beginning on or after January 1, 2018. The Tax Act resulted in the Company generating a deferred tax expense primarily due to the reduction in the U.S. statutory corporate income tax rate from a maximum 35% to a flat 21% rate. This deferred tax expense was offset by the valuation allowance placed on the Company's deferred tax assets. Based on the Company’s current interpretation and subject to the release of regulations promulgated by the U.S. Department of Treasury and any other future interpretive guidance relating to the Tax Act, the Company believes the effects of the change in U.S. federal income tax laws incorporated herein are substantially complete.

Reconciliation of Provision f50

Reconciliation of Provision for Income Taxes to Amount Provided by Applying Statutory United States Federal Income Tax Rate to Income Before Income Taxes (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Taxes [Line Items]
U.S. federal corporate income tax rate, percentage		35.00%	35.00%	35.00%
Scenario, Forecast
Income Taxes [Line Items]
U.S. federal corporate income tax rate, percentage	21.00%

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, 2017	Dec. 31, 2016
Deferred income tax assets (liabilities):
Derivative financial instruments, assets	$ 4,683	$ 4,403
Net operating loss carryovers	164,564	206,663
Asset retirement obligation	613	7,530
Startup and organization costs	51	104
Deferred acquisition costs	26	45
Percentage depletion	582	1,335
Property and equipment costs	12,323	75,267
Equity compensation	1,330	2,267
Tax credits	3,837	283
Other	5,084	11,700
Valuation allowance	$ (193,093)	$ (309,597)

Stockholders' Equity and Equi52

Stockholders' Equity and Equity Based Awards - Preferred Stock - Additional Information (Detail) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended
	Oct. 31, 2016	Dec. 31, 2017	Dec. 31, 2016
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	62,500
Preferred stock, outstanding		62,500	62,500
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	62,500
Preferred stock, dividend rate	8.125%
Preferred stock issued pursuant to Initial Purchaser, aggregate net consideration, before offering expenses	$ 60
Preferred Stock Purchase Agreement | BMO Capital Markets Corp. | 8.125% Series B Cumulative Perpetual Convertible Preferred Stock
Class Of Stock [Line Items]
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.
Preferred dividends payable		$ 1.3
Date of dividends declared		Dec. 19, 2017
Date dividends paid		Jan. 16, 2018
Record date of dividends paid to holders		Jan. 1, 2018
Over-Allotment Option | Purchase Agreement | BMO Capital Markets Corp. | 8.125% Series B Cumulative Perpetual Convertible Preferred Stock
Class Of Stock [Line Items]
Initial Purchaser option to purchase additional shares	7,500

Stockholders' Equity and Equi53

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, 2017$ / sharesshares	Dec. 31, 2016USD ($)$ / sharesshares
Class Of Stock [Line Items]
Common stock, shares authorized	45,000,000		45,000,000	45,000,000	45,000,000
Common stock, shares issued			21,932,842	22,527,652	21,932,842
Common stock, shares outstanding			21,932,842	22,527,652	21,932,842
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
Issuance of stock, net of deductible fees and estimated expenses (in 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	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 Equi54

Stockholders' Equity and Equity Based Awards - Long-Term Employee Incentive Plan - Additional Information (Detail) - Long-term Employee Incentive Plan - USD ($)	1 Months Ended
	Dec. 31, 2017	May 31, 2017	May 31, 2016	Jun. 30, 2015
Class Of Stock [Line Items]
Maximum number of shares of common stock to be issued under the Incentive Plan	4,901,548
Additional number of shares of common stock to be issued under the Incentive Plan		1,450,000	1,000,000	620,000
Time-based restricted shares | Aneth Disposition, Aneth Rank and File Employee Awards
Class Of Stock [Line Items]
Modification of awards resulted in accelerated vesting, number	47,057
Stock appreciation rights | Aneth Disposition, Aneth Rank and File Employee Awards
Class Of Stock [Line Items]
Modification of awards resulted in accelerated vesting, number	26,177
Stock Options | Aneth Disposition, Aneth Rank and File Employee Awards
Class Of Stock [Line Items]
Modification of awards resulted in accelerated vesting, number	47,998
Time-based restricted cash | Aneth Disposition, Aneth Rank and File Employee Awards
Class Of Stock [Line Items]
Modification of awards resulted in accelerated vesting, cost	$ 552,813
Performance-based restricted cash | Aneth Disposition, Aneth Rank and File Employee Awards
Class Of Stock [Line Items]
Modification of awards resulted in accelerated vesting, cost	$ 31,296

Expense Related to Incentive Pl

Expense Related to Incentive Plan (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Class Of Stock [Line Items]
Total share-based compensation expense	$ 12,161	$ 6,315	$ 12,148
Long-term Employee Incentive Plan
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	28,674	41,217	13,510
Total share-based compensation expense	12,170	6,291	12,325
Total cash-based compensation expense	16,504	34,926	1,185
Long-term Employee Incentive Plan | Time-based restricted stock awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	5,800	4,359	9,067
Long-term Employee Incentive Plan | TSR awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	5,106	996	2,848
Long-term Employee Incentive Plan | Stock appreciation awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense			45
Long-term Employee Incentive Plan | Stock Option Awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	1,264	936	365
Long-term Employee Incentive Plan | Time-based restricted cash awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	2,716	3,409	959
Long-term Employee Incentive Plan | Performance Based Restricted Cash Awards
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	2,012	13,780	$ 226
Long-term Employee Incentive Plan | Cash-Settled Stock Appreciation Rights
Class Of Stock [Line Items]
Incentive Plan compensation (income) expense	$ 11,776	$ 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, 2017USD ($)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 17,152
Stock Option Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 1,597
Weighted Average Years Remaining	1 year
Time-based restricted stock awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 10,443
Weighted Average Years Remaining	2 years 1 month 6 days
TSR awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Unrecognized Compensation Expense	$ 5,112
Weighted Average Years Remaining	2 years 2 months 12 days

Stockholders' Equity and Equi57

Stockholders' Equity and Equity Based Awards - Equity Awards - Additional Information (Detail) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended
	Feb. 28, 2017EntityInstallment	Dec. 31, 2017USD ($)$ / sharesshares	Dec. 31, 2016USD ($)$ / shares	Dec. 31, 2015$ / sharesshares
Time-based restricted stock awards
Class Of Stock [Line Items]
Vesting period		3 years
Shares granted		397,967
Weighted average grant date fair value of share granted | $ / shares		$ 43.04	$ 4.48	$ 6.75
Vested, shares		126,931
Time-based restricted stock awards | Non-Employee Directors
Class Of Stock [Line Items]
Vesting period		1 year
TSR awards
Class Of Stock [Line Items]
Shares granted		131,379
Weighted average grant date fair value of share granted | $ / shares		$ 77.23
Number of Peer Companies | Entity	12
Number of installment for performance-Vested Shares vest | Installment	3
Vested, shares		97,561
Dividend yield		0.00%
TSR awards | First Installment
Class Of Stock [Line Items]
Vesting period	1 year
TSR awards | Second Installment
Class Of Stock [Line Items]
Vesting period	2 years
TSR awards | Third Installment
Class Of Stock [Line Items]
Vesting period	3 years
TSR Awards 2014
Class Of Stock [Line Items]
Vested, shares		63,024
Stock Option Awards
Class Of Stock [Line Items]
Vesting period		3 years
Options granted, term		10 years
Dividend yield		0.00%
Average Expected Volatility, minimum		63.00%
Average Expected 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 | $		$ 3.6	$ 0.5
Options exercisable		342,848		0
Minimum | Time-based restricted stock awards
Class Of Stock [Line Items]
Estimated forfeiture rates		0.00%
Minimum | TSR awards
Class Of Stock [Line Items]
Estimated forfeiture rates		0.00%
Minimum | Stock Option Awards
Class Of Stock [Line Items]
Estimated forfeiture rates		0.00%
Maximum | Time-based restricted stock awards
Class Of Stock [Line Items]
Estimated forfeiture rates		15.00%
Maximum | TSR awards
Class Of Stock [Line Items]
Estimated forfeiture rates		2.00%
Maximum | Stock Option Awards
Class Of Stock [Line Items]
Estimated forfeiture rates		15.00%

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested, beginning of period, Shares	151,781
Granted, Shares	397,967
Vested, Shares	(126,931)
Forfeited, Shares	(15,330)
Non-vested, end of period, Shares	407,487	151,781
Non-vested, beginning of period, Weighted Average Grant Date Fair Value	$ 25.07
Granted, Weighted Average Grant Date Fair Value	43.04	$ 4.48	$ 6.75
Vested, Weighted Average Grant Date Fair Value	27.22
Forfeited, Weighted Average Grant Date Fair Value	33.90
Non-vested, end of period, Weighted Average Grant Date Fair Value	$ 41.62	$ 25.07

Valuation Model for Performance

Valuation Model for Performance-Based Awards (Detail) - Stock Performance Based Awards	12 Months Ended
	Dec. 31, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Average Expected Volatility, minimum	49.07%
Average Expected Volatility, maximum	108.21%
Expected Dividend Yield	0.00%
Risk-Free Interest Rate, Minimum	0.83%
Risk-Free Interest Rate, Maximum	1.45%

Changes in Non-Vested TSR Award

Changes in Non-Vested TSR Awards (Detail) - TSR awards	12 Months Ended
	Dec. 31, 2017$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested, beginning of period, Shares | shares	97,561
Granted, Shares | shares	131,379
Vested, Shares | shares	(97,561)
Forfeited, Shares | shares	(935)
Non-vested, end of period, Shares | shares	130,444
Non-vested, beginning of period, Weighted Average Grant Date Fair Value | $ / shares	$ 66.60
Granted, Weighted Average Grant Date Fair Value | $ / shares	77.23
Vested, Weighted Average Grant Date Fair Value | $ / shares	66.60
Forfeited, Weighted Average Grant Date Fair Value | $ / shares	77.23
Non-vested, end of period, Weighted Average Grant Date Fair Value | $ / shares	$ 77.23

Changes in Non-Vested Stock Opt

Changes in Non-Vested Stock Option Awards (Detail) - Stock Option Awards $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Outstanding, beginning of period, Shares | shares	1,052,513
Exercised, Shares | shares	(118,199)
Forfeited, Shares | shares	(16,060)
Outstanding, end of period, Shares | shares	918,254
Exercisable, end of period, Shares | shares	342,848
Outstanding, beginning of period, Weighted Average Exercise Price | $ / shares	$ 4.03
Exercised, Weighted Average Exercise Price | $ / shares	4.76
Forfeited, Weighted Average Exercise Price | $ / shares	3.51
Outstanding, end of period, Weighted Average Exercise Price | $ / shares	3.95
Exercisable, end of period, Weighted Average Exercise Price | $ / shares	$ 4.58
Outstanding, Weighted Average Remaining Contractual Term	7 years 10 months 24 days
Exercisable, Weighted Average Remaining Contractual Term	7 years 9 months 18 days
Outstanding, Aggregate Intrinsic Value | $	$ 25,274
Exercisable, Aggregate Intrinsic Value | $	$ 9,218

Stockholders' Equity and Equi62

Stockholders' Equity and Equity Based Awards - Liability Awards - Additional Information (Detail) $ / shares in Units, $ in Millions	1 Months Ended		12 Months Ended
	Feb. 29, 2016Installment$ / sharesshares	May 31, 2015$ / shares	Dec. 31, 2017USD ($)$ / shares
Cash-Settled Stock Appreciation Rights
Class Of Stock [Line Items]
Cash-settled stock appreciation rights, fair value | $			$ 49.6
Cash-settled stock appreciation rights, fair value expensed | $			$ 29.8
Dividend yield			0.00%
Expected price volatility			0.00%
Risk-free rates			0.00%
Cash-Settled Stock Appreciation Rights | Employees
Class Of Stock [Line Items]
Cash-settled stock appreciation rights, base price | $ / shares	$ 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 | $ / shares	$ 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 | $			$ 9.6
Restricted cash award, fair value expensed | $			$ 7.1
Restricted cash award, measured on cash value per unit | $ / shares			$ 1
Common stock, hurdle stock price | $ / shares			$ 1
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%
Dividend yield			0.00%
Expected price volatility			0.00%
Risk-free rates			0.00%
Restricted cash award, fair value | $			$ 16.6
Restricted cash award, fair value expensed | $			$ 16
Number of trading days			60 days
Common stock, hurdle stock price | $ / shares		$ 10	$ 40
Restricted cash award, average effective term			1 year
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			8.00%
Maximum | Time-based restricted cash awards
Class Of Stock [Line Items]
Estimated forfeiture rates			25.00%
Maximum | Performance-based restricted cash awards
Class Of Stock [Line Items]
Common stock, hurdle stock price | $ / shares		$ 40

Asset Retirement Obligation - A

Asset Retirement Obligation - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2017
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, 2017	Dec. 31, 2016
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations at beginning of period	$ 20,352	$ 19,238
Additional liability incurred / acquired	443	587
Accretion expense	1,367	1,790
Liabilities settled / sold	(20,292)	(1,088)
Revisions to previous estimates	917	(175)
Asset retirement obligations at end of period	2,787	20,352
Less: current asset retirement obligations	(540)	(895)
Long-term asset retirement obligations	$ 2,247	$ 19,457

Derivative Instruments - Additi

Derivative Instruments - Additional Information (Detail) - USD ($) $ in Thousands	Nov. 06, 2017	Dec. 31, 2017	Dec. 31, 2016
Derivative [Line Items]
Additional consideration, fair value		$ 18,472	$ 218
Maximum amount of loss in the event of all counterparties defaulting		0
Aneth Disposition | Maximum
Derivative [Line Items]
Receive additional cash consideration upon condition	$ 35,000
Contingent Payment Derivative Instrument | Aneth Disposition
Derivative [Line Items]
Additional consideration, fair value		17,900
Level 2 | Commodity Contract
Derivative [Line Items]
Fair value of commodity derivatives net liability		$ 21,300

Oil Commodity Contracts (Detail

Oil Commodity Contracts (Detail) - Jan – Dec 2018 Commodity Swap Contracts - Oil (NYMEX WTI)	12 Months Ended
	Dec. 31, 2017$ / bblbbl
Derivative [Line Items]
Bbl per Day | bbl	3,744
Weighted Average Swap Price per Bbl | $ / bbl	51.10

Commodity Collar Contracts (Det

Commodity Collar Contracts (Detail) - Oil (NYMEX WTI) - Jan - Dec 2018 Three Way Commodity Collar Contracts	Dec. 31, 2017bbl$ / bbl
Derivative [Line Items]
Bbl per Day | bbl	3,252
Weighted Average Short Put Price	40.15
Weighted Average Floor Price	49.38
Weighted Average Ceiling Price	54.19

Commodity Option Contracts (Det

Commodity Option Contracts (Detail) - Oil (NYMEX WTI)	Dec. 31, 2017bbl$ / bbl
Jan - Dec 2018 Commodity Option Contract
Derivative [Line Items]
Bbl per Day | bbl	1,100
Sold Call Price | $ / bbl	55
Jan - Dec 2019 Commodity Option Contract
Derivative [Line Items]
Bbl per Day | bbl	1,100
Sold Call Price | $ / bbl	62.85

Basis Swap Contracts (Detail)

Basis Swap Contracts (Detail) - Gas (NYMEX HH) - Jan – Dec 2018 Basis Swap Contracts	12 Months Ended
	Dec. 31, 2017MMBTU$ / MMBTU
Derivative [Line Items]
MMBtu per Day | MMBTU	18,000
Weighted Average Price Differential | $ / MMBTU	0.688

Additional Commodity Option Con

Additional Commodity Option Contracts (Detail) - Oil (NYMEX WTI)	Mar. 12, 2018bbl$ / bbl	Dec. 31, 2017bbl$ / bbl
Feb - May 2018 Commodity Option Contract | Subsequent Event
Derivative [Line Items]
Bbl per Day | bbl	1,100
Bought Call Price | $ / bbl	55
Jan - Dec 2019 Commodity Option Contract
Derivative [Line Items]
Bbl per Day | bbl		1,100
Sold Call Price | $ / bbl		62.85
Jan - Dec 2019 Commodity Option Contract | Subsequent Event
Derivative [Line Items]
Bbl per Day | bbl	1,330
Sold Call Price | $ / bbl	65

Amount of Commodity Derivative

Amount of Commodity Derivative Instrument Gains Losses (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Derivative Instruments And Hedging Activities Disclosure [Abstract]
Commodity derivative settlements	$ 3,730	$ 88,010	$ 93,150
Mark-to-market loss	(9,385)	(107,794)	(16,658)
Commodity derivative instruments gain (loss)	$ (5,655)	$ (19,784)	$ 76,492

Assets and Liabilities Required

Assets and Liabilities Required to be Measured at Fair Value on Recurring Basis (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Assets
Total assets	$ 18,472	$ 218
Liabilities
Commodity derivative instruments	20,822	8,014
Commodity derivative instruments	990	4,104
Total liabilities	21,812	12,118
Contingent Payment
Assets
Derivative instruments, current	8,311
Derivative instruments, long term	9,635
Commodity
Assets
Derivative instruments, current	$ 526	$ 218

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Office facilities
Commitment And Contingencies [Line Items]
Rental expense, net	$ 3,000	$ 3,000	$ 1,100
Compressors and Other Oilfield Equipment
Commitment And Contingencies [Line Items]
Rental expense, net	$ 700	$ 1,700	$ 1,900

Schedule of Future Payment Oper

Schedule of Future Payment Operating Leases Agreements (Detail) $ in Thousands	Dec. 31, 2017USD ($)
Operating Leases Future Minimum Payments Due [Abstract]
2,018	$ 2,158
2,019	1,653
2,020	1,508
2,021	1,489
2022 and thereafter	633
Total	7,441
Office Lease Rentals
Operating Leases Future Minimum Payments Due [Abstract]
2,018	1,855
2,019	1,403
2,020	1,287
2,021	1,308
2022 and thereafter	550
Total	6,403
Vehicle Lease Rentals
Operating Leases Future Minimum Payments Due [Abstract]
2,018	303
2,019	250
2,020	221
2,021	181
2022 and thereafter	83
Total	$ 1,038

Subsequent Events - Additional

Subsequent Events - Additional Information (Detail)	1 Months Ended			12 Months Ended
	Feb. 28, 2018Installmentshares	Jan. 31, 2018USD ($)shares	Dec. 31, 2017USD ($)shares	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Subsequent Event [Line Items]
Total share-based compensation expense | $					$ 12,161,000	$ 6,315,000	$ 12,148,000
Long-term Employee Incentive Plan
Subsequent Event [Line Items]
Total share-based compensation expense | $					$ 12,170,000	$ 6,291,000	$ 12,325,000
Long-term Employee Incentive Plan | Aneth Disposition, Aneth Rank and File Employee Awards | Time-based restricted shares
Subsequent Event [Line Items]
Modification of awards resulted in accelerated vesting, number			47,057
Long-term Employee Incentive Plan | Aneth Disposition, Aneth Rank and File Employee Awards | Stock appreciation rights
Subsequent Event [Line Items]
Modification of awards resulted in accelerated vesting, number			26,177
Long-term Employee Incentive Plan | Aneth Disposition, Aneth Rank and File Employee Awards | Stock Options
Subsequent Event [Line Items]
Modification of awards resulted in accelerated vesting, number			47,998
Long-term Employee Incentive Plan | Aneth Disposition, Aneth Rank and File Employee Awards | Time-based restricted cash
Subsequent Event [Line Items]
Modification of awards resulted in accelerated vesting, cost | $			$ 552,813
Long-term Employee Incentive Plan | Aneth Disposition, Aneth Rank and File Employee Awards | Performance-based restricted cash
Subsequent Event [Line Items]
Modification of awards resulted in accelerated vesting, cost | $			$ 31,296
Long-term Employee Incentive Plan | Scenario, Forecast | Aneth Disposition, Aneth Rank and File Employee Awards
Subsequent Event [Line Items]
Total share-based compensation expense | $				$ 1,000,000
Cash-based compensation expense | $				$ 100,000
Long-term Employee Incentive Plan | Subsequent Event | Time-based restricted stock awards | Employees
Subsequent Event [Line Items]
Number of shares expected to vest	332,561
Number of installment for equity awards | Installment	3
Long-term Employee Incentive Plan | Subsequent Event | Performance Vesting Shares | Employees
Subsequent Event [Line Items]
Number of shares expected to vest	184,657
Number of installment for equity awards | Installment	3
Long-term Employee Incentive Plan | Subsequent Event | Performance Vesting Shares | Non-Employee Directors
Subsequent Event [Line Items]
Number of shares expected to vest	29,058
Number of installment for equity awards | Installment	1
Long-term Employee Incentive Plan | Subsequent Event | Outperformance Vesting Shares
Subsequent Event [Line Items]
Number of installment for equity awards | Installment	3
Long-term Employee Incentive Plan | Subsequent Event | Outperformance Vesting Shares | Maximum
Subsequent Event [Line Items]
Number of shares expected to vest	184,657
Long-term Employee Incentive Plan | Subsequent Event | Aneth Disposition, Aneth Rank and File Employee Awards | Time-based restricted shares
Subsequent Event [Line Items]
Modification of awards resulted in accelerated vesting, number		27,669
Long-term Employee Incentive Plan | Subsequent Event | Aneth Disposition, Aneth Rank and File Employee Awards | Stock appreciation rights
Subsequent Event [Line Items]
Modification of awards resulted in accelerated vesting, number		182,366
Long-term Employee Incentive Plan | Subsequent Event | Aneth Disposition, Aneth Rank and File Employee Awards | Stock Options
Subsequent Event [Line Items]
Modification of awards resulted in accelerated vesting, number		80,375
Long-term Employee Incentive Plan | Subsequent Event | Aneth Disposition, Aneth Rank and File Employee Awards | Time-based restricted cash
Subsequent Event [Line Items]
Modification of awards resulted in accelerated vesting, cost | $		$ 563,475
Long-term Employee Incentive Plan | Subsequent Event | Aneth Disposition, Aneth Rank and File Employee Awards | Performance-based restricted cash
Subsequent Event [Line Items]
Modification of awards resulted in accelerated vesting, cost | $		$ 161,669

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Acquisition costs
Proved		$ 20,590	$ 41,830
Unproved		147,442	120,851	$ 6,583
Exploration costs		175,254	101,719	13,764
Development costs	[1]	133,066	31,057	39,883
Total		$ 476,352	$ 295,457	$ 60,230
[1]	*Includes $3.3 million, $5.9 million and $8.9 million of acquired CO2 during 2017, 2016 and 2015, respectively

Costs Incurred in Oil and Gas77

Costs Incurred in Oil and Gas Property Acquisition Exploration and Development Activities (Parenthetical) (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Extractive Industries [Abstract]
Acquired CO2	$ 3.3	$ 5.9	$ 8.9

Net Capitalized Costs Related t

Net Capitalized Costs Related to Resolute's Oil and Gas Producing Activities (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Property Plant And Equipment [Abstract]
Proved oil and gas properties	$ 2,030,316	$ 1,889,111
Unevaluated oil and gas properties, not subject to amortization	248,059	121,375
Accumulated depletion, depreciation and amortization	(1,730,204)	(1,640,279)
Oil and gas properties, net	$ 548,171	$ 370,207

Changes in Estimated Reserves (

Changes in Estimated Reserves (Detail) bbl in Thousands, MMcf in Thousands, Boe in Thousands		12 Months Ended
		Dec. 31, 2017BoebblMMcf	Dec. 31, 2016BoebblMMcf	Dec. 31, 2015BoebblMMcf
Reserve Quantities [Line Items]
Extensions, discoveries and other additions | Boe				970
Oil Equivalent
Reserve Quantities [Line Items]
Proved reserves, beginning balance | Boe	[1]	60,267	33,120	74,218
Purchase of minerals in place | Boe	[1]	362	3,323
Production | Boe	[1]	(9,156)	(5,182)	(4,535)
Extensions, discoveries and other additions | Boe	[1]	31,619	34,543	4,602
Sales of minerals in place | Boe	[1]	(23,026)		(12,072)
Revisions of previous estimates | Boe	[1]	(6,636)	(5,537)	(29,093)
Proved reserves, ending balance | Boe	[1]	53,430	60,267	33,120
Proved developed reserves | Boe	[1]	26,215	37,656	27,874
Proved undeveloped reserves | Boe	[1]	27,215	22,611	5,246
Oil
Reserve Quantities [Line Items]
Proved reserves, beginning balance		43,804	28,748	63,715
Purchase of minerals in place		171	1,492
Production		(5,499)	(3,821)	(3,270)
Extensions, discoveries and other additions		14,170	21,427	1,965
Sales of minerals in place		(22,821)		(5,289)
Revisions of previous estimates		(4,506)	(4,042)	(28,373)
Proved reserves, ending balance		25,319	43,804	28,748
Proved developed reserves		12,274	30,026	25,672
Proved undeveloped reserves		13,045	13,778	3,076
Gas
Reserve Quantities [Line Items]
Proved reserves, beginning balance | MMcf		52,448	13,860	36,798
Purchase of minerals in place | MMcf		704	5,810
Production | MMcf		(12,101)	(4,811)	(5,193)
Extensions, discoveries and other additions | MMcf		60,330	41,151	8,208
Sales of minerals in place | MMcf		(654)		(23,674)
Revisions of previous estimates | MMcf		(5,913)	(3,562)	(2,279)
Proved reserves, ending balance | MMcf		94,814	52,448	13,860
Proved developed reserves | MMcf		46,827	24,209	7,098
Proved undeveloped reserves | MMcf		47,987	28,238	6,761
NGL
Reserve Quantities [Line Items]
Proved reserves, beginning balance		7,722	2,061	4,370
Purchase of minerals in place		73	863
Production		(1,641)	(559)	(400)
Extensions, discoveries and other additions		7,394	6,257	1,269
Sales of minerals in place		(96)		(2,837)
Revisions of previous estimates		(1,143)	(900)	(341)
Proved reserves, ending balance		12,309	7,722	2,061
Proved developed reserves		6,136	3,595	1,019
Proved undeveloped reserves		6,173	4,127	1,043
[1]	Boe is determined using one Bbl of oil or NGL to six Mcf of gas. In accordance with SEC and Financial Accounting Standards Board (“FASB”) requirements, our estimated net proved reserves and standardized measure at December 31, 2017, 2016 and 2015, were determined utilizing prices equal to the twelve-month unweighted arithmetic average using first day of the month prices, resulting in an average Plains Marketing, L.P. posted WTI oil price of $47.79, $39.25 and $46.79 per Bbl and an average Platts Gas Daily El Paso Permian Basin spot gas price of $2.62, $2.31, and $2.45 per MMBtu for the Permian Properties, respectively. Our estimated net proved reserves and standardized measure at December 31, 2016 and 2015 for the Aneth Properties, were determined utilizing prices equal to the respective twelve-month unweighted arithmetic average using the first day of the month prices, resulting in an average NYMEX WTI oil price of $42.75 and $50.28 per Bbl, and an average Platts Gas Daily El Paso San Juan Basin spot gas price of $2.33 and $2.46, respectively

Changes in Estimated Reserves80

Changes in Estimated Reserves (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2017$ / bbl$ / MMBTU	Dec. 31, 2016$ / bbl$ / MMBTU	Dec. 31, 2015$ / bbl$ / MMBTU	Dec. 31, 2014$ / bbl
Reserve Quantities [Line Items]
Period of determined utilizing prices equal to unweighted arithmetic average using first day of month prices	12 months
Oil | Plains Marketing, L.P. WTI
Reserve Quantities [Line Items]
Average oil and gas market price	47.79	39.25	46.79
Oil | NYMEX WTI
Reserve Quantities [Line Items]
Average oil and gas market price		42.75	50.28	94.99
Gas | Platts Gas Daily El Paso Permian Basin spot
Reserve Quantities [Line Items]
Average oil and gas market price | $ / MMBTU	2.62	2.31	2.45
Aneth Properties
Reserve Quantities [Line Items]
Period of determined utilizing prices equal to unweighted arithmetic average using first day of month prices	12 months
Aneth Properties | Oil | NYMEX WTI
Reserve Quantities [Line Items]
Average oil and gas market price		42.75	50.28
Aneth Properties | 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

Supplemental Oil and Gas Info81

Supplemental Oil and Gas Information - Additional Information (Detail)		12 Months Ended
		Dec. 31, 2017BoeWell	Dec. 31, 2016Boe$ / bbl	Dec. 31, 2015BoeWell$ / bbl	Dec. 31, 2014$ / bbl
Supplemental Oil And Gas Information [Line Items]
Extensions, discoveries and other additions				970,000
Net of production related to extensions, discoveries and other additions		2,469,000
Net of production related to sales of minerals in place		1,847,000
Discount factor		10.00%	10.00%	10.00%
Additional Proved Undeveloped Offset Locations
Supplemental Oil And Gas Information [Line Items]
Extensions, discoveries and other additions				3,600,000
Denton and Knowles South Fields
Supplemental Oil And Gas Information [Line Items]
Net of production related to sales of minerals in place		32,000
Denton and Knowles South Fields | New Mexico
Supplemental Oil And Gas Information [Line Items]
Number of gross wells | Well		36
Sales of minerals in place		431,000
Denton and Knowles South Fields | New Mexico | Purchase and Sale Agreement
Supplemental Oil And Gas Information [Line Items]
Transaction date		Feb. 22, 2017
Aneth Field
Supplemental Oil And Gas Information [Line Items]
Number of gross wells | Well		371
Extensions, discoveries and other additions			4,500
Sales of minerals in place		22,595,000
Net of production related to sales of minerals in place		1,816,000
Powder River Basin Howard And Martin County And Gardendale Midland Basin
Supplemental Oil And Gas Information [Line Items]
Sales of minerals in place				12,072,000
Net of production related to sales of minerals in place				1,091,000
Powder River Basin
Supplemental Oil And Gas Information [Line Items]
Number of gross wells | Well				161
Sales of minerals in place				5,475,000
Net of production related to sales of minerals in place				462,000
Howard And Martin County
Supplemental Oil And Gas Information [Line Items]
Number of gross wells | Well				54
Sales of minerals in place				1,698,000
Net of production related to sales of minerals in place				86,000
Gardendale Midland Basin
Supplemental Oil And Gas Information [Line Items]
Number of gross wells | Well				102
Sales of minerals in place				4,899,000
Net of production related to sales of minerals in place				543,000
Oil Equivalent
Supplemental Oil And Gas Information [Line Items]
Purchase of minerals in place	[1]	362,000	3,323,000
Production	[1]	9,156,000	5,182,000	4,535,000
Extensions, discoveries and other additions	[1]	31,619,000	34,543,000	4,602,000
Sales of minerals in place	[1]	23,026,000		12,072,000
Revisions of previous estimates	[1]	6,636,000	5,537,000	29,093,000
Oil Equivalent | Permian Basin Properties
Supplemental Oil And Gas Information [Line Items]
Production		7,341,000	2,927,000	1,782,000
Percentage of oil equivalent production		80.00%	56.00%	39.00%
Oil Equivalent | Powder River Basin Properties
Supplemental Oil And Gas Information [Line Items]
Production				462,000
Percentage of oil equivalent production				10.00%
Oil Equivalent | Aneth Field
Supplemental Oil And Gas Information [Line Items]
Production		1,816,000	2,255,000	2,292,000
Percentage of oil equivalent production		20.00%	44.00%	51.00%
Oil | Permian Basin Properties
Supplemental Oil And Gas Information [Line Items]
Production		3,765,000	1,689,000	973,000
Oil | Powder River Basin Properties
Supplemental Oil And Gas Information [Line Items]
Production				125,000
Oil | NYMEX WTI
Supplemental Oil And Gas Information [Line Items]
Average oil and gas market price | $ / bbl			42.75	50.28	94.99
Percentage of price increase (decrease)			(15.00%)	(47.00%)
Oil | Aneth Field
Supplemental Oil And Gas Information [Line Items]
Production		1,734,000	2,132,000	2,172,000
Gas | Permian Basin Properties
Supplemental Oil And Gas Information [Line Items]
Production		11,612,000	4,071,000	2,523,000
Gas | Powder River Basin Properties
Supplemental Oil And Gas Information [Line Items]
Production				1,954,000
Gas | Aneth Field
Supplemental Oil And Gas Information [Line Items]
Production		489,000	739,000	717,000
NGL | Permian Basin Properties
Supplemental Oil And Gas Information [Line Items]
Production		1,641,000	559,000	389,000
NGL | Powder River Basin Properties
Supplemental Oil And Gas Information [Line Items]
Production				11,000
Newly Drilled Permian Wells
Supplemental Oil And Gas Information [Line Items]
Number of gross wells | Well		16
Extensions, discoveries and other additions		10,741,000
DUC
Supplemental Oil And Gas Information [Line Items]
Number of gross wells | Well		7
Extensions, discoveries and other additions		2,722,000
Immediate Offset Proved Undeveloped Permian Locations
Supplemental Oil And Gas Information [Line Items]
Number of gross wells | Well		15
Extensions, discoveries and other additions		11,939,000
Offset Locations to Permian Wells Drilled | Proved undeveloped reserves
Supplemental Oil And Gas Information [Line Items]
Number of gross wells | Well		9
Extensions, discoveries and other additions		6,217,000
Delaware Basin Bronco Acquisition
Supplemental Oil And Gas Information [Line Items]
Purchase of minerals in place		362,000	3,323,000
Number of gross wells | Well		2
Production			169,000
Delaware Basin Bronco Acquisition | Purchase and Sale Agreement
Supplemental Oil And Gas Information [Line Items]
Transaction date		May 31, 2017
Appaloosa And Mustang Agreement
Supplemental Oil And Gas Information [Line Items]
Transaction date		Aug. 31, 2016
Appaloosa And Mustang Agreement | Reeves County Drilling Program
Supplemental Oil And Gas Information [Line Items]
Extensions, discoveries and other additions			13,900
Appaloosa And Mustang Agreement | Reeves County Drilling Program | Additional Proved Undeveloped Offset Locations
Supplemental Oil And Gas Information [Line Items]
Extensions, discoveries and other additions			16,200
Aneth Properties
Supplemental Oil And Gas Information [Line Items]
Revisions of previous estimates			(3,660,000)	(22,786,000)
Percentage of price increase (decrease)			66.00%	78.00%
Aneth Properties | Oil | NYMEX WTI
Supplemental Oil And Gas Information [Line Items]
Average oil and gas market price | $ / bbl			42.75	50.28
[1]	Boe is determined using one Bbl of oil or NGL to six Mcf of gas. In accordance with SEC and Financial Accounting Standards Board (“FASB”) requirements, our estimated net proved reserves and standardized measure at December 31, 2017, 2016 and 2015, were determined utilizing prices equal to the twelve-month unweighted arithmetic average using first day of the month prices, resulting in an average Plains Marketing, L.P. posted WTI oil price of $47.79, $39.25 and $46.79 per Bbl and an average Platts Gas Daily El Paso Permian Basin spot gas price of $2.62, $2.31, and $2.45 per MMBtu for the Permian Properties, respectively. Our estimated net proved reserves and standardized measure at December 31, 2016 and 2015 for the Aneth Properties, were determined utilizing prices equal to the respective twelve-month unweighted arithmetic average using the first day of the month prices, resulting in an average NYMEX WTI oil price of $42.75 and $50.28 per Bbl, and an average Platts Gas Daily El Paso San Juan Basin spot gas price of $2.33 and $2.46, respectively

Future Net Cash Flows Relating

Future Net Cash Flows Relating to Proved Oil and Gas Reserves (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Extractive Industries [Abstract]
Future cash inflows	$ 1,623,000	$ 1,800,000	$ 1,293,000
Future production costs	(629,000)	(934,000)	(774,000)
Future development costs	(285,000)	(288,000)	(180,000)
Future income taxes	(3,000)	(1,000)
Future net cash flows	706,000	577,000	339,000
10% annual discount for estimated timing of cash flows	(273,000)	(233,000)	(140,000)
Standardized measure of discounted future net cash flows	$ 433,000	$ 344,000	$ 199,000	$ 833,000

Future Net Cash Flows Relatin83

Future Net Cash Flows Relating to Proved Oil and Gas Reserves (Parenthetical) (Detail)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
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, 2017	Dec. 31, 2016	Dec. 31, 2015
Extractive Industries [Abstract]
Standardized measure, beginning of year	$ 344,000	$ 199,000	$ 833,000
Sales of oil and gas produced, net of production costs	(136,000)	(82,000)	(181,000)
Net changes in prices and production costs	41,000	(106,000)	(917,000)
Purchases of minerals in place	5,000	10,000
Sales of minerals in place	(99,000)		(134,000)
Previously estimated development costs incurred during the year	16,000	22,000	33,000
Extensions, discoveries and improved recovery	108,000	268,000	13,000
Changes in estimated future development costs	213,000	12,000	119,000
Revisions of previous quantity estimates	(71,000)	(3,000)	196,000
Accretion of discount	25,000	20,000	70,000
Net change in income taxes	(1,000)		104,000
Changes in timing and other	(12,000)	4,000	63,000
Standardized measure, end of year	$ 433,000	$ 344,000	$ 199,000

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, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Quarterly Financial Data [Abstract]
Revenue	$ 89,255	$ 79,371	$ 70,260	$ 64,592	$ 62,667	$ 47,419	$ 35,390	$ 19,002	$ 303,478	$ 164,478	$ 154,644
Operating expenses	(75,668)	(71,742)	(55,847)	(56,202)	(64,042)	(57,089)	(39,767)	(95,086)	(259,459)	(255,984)	(931,348)
Income (loss) from operations	13,587	7,629	14,413	8,390	(1,375)	(9,670)	(4,377)	(76,084)	44,019	(91,506)	(776,704)
Net income (loss) available to common shareholders	$ (3,872)	$ (14,602)	$ 10,690	$ 76	$ (20,648)	$ (18,856)	$ (36,906)	$ (85,312)	$ (7,708)	$ (161,722)	$ (742,279)
Income (loss) per common share:
Basic	$ (0.18)	$ (0.71)	$ 0.49	$ 0.01
Diluted	$ (0.18)	$ (0.71)	$ 0.47	$ 0.01
Basic and Diluted					$ (1.23)	$ (1.24)	$ (2.44)	$ (5.65)	$ (0.35)	$ (10.33)	$ (49.55)
Weighted average common shares outstanding:
Basic	21,958	21,941	21,917	21,738					21,889	15,767	14,986
Diluted	21,958	21,941	22,894	22,791					21,889	15,767	14,986
Basic and Diluted					17,690	15,173	15,155	15,036	21,889	15,767	14,986