HighPoint Resources (HPR) 10-Q 9 Aug 18 2018 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2018	Jul. 25, 2018
Document Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q2
Trading Symbol	HPR
Entity Registrant Name	HighPoint Resources Corp
Entity Central Index Key	1,725,526
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		212,410,301

CONSOLIDATED BALANCE SHEETS (UN

CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Current assets:
Cash and cash equivalents	$ 107,379	$ 314,466
Accounts receivable, net of allowance for doubtful accounts	63,443	51,415
Prepayments and other current assets	2,697	1,782
Total current assets	173,519	367,663
Property and equipment - at cost, successful efforts method for oil and gas properties:
Proved oil and gas properties	1,676,068	1,361,168
Unproved oil and gas properties, excluded from amortization	732,475	84,676
Furniture, equipment and other	19,329	17,899
Property, plant and equipment, gross	2,427,872	1,463,743
Accumulated depreciation, depletion, amortization and impairment	(522,252)	(444,863)
Total property and equipment, net	1,905,620	1,018,880
Deferred financing costs and other noncurrent assets	3,814	4,163
Total	2,082,953	1,390,706
Current liabilities:
Accounts payable and other accrued liabilities	113,638	84,055
Amounts payable to oil and gas property owners	46,825	16,594
Production taxes payable	35,282	26,876
Derivative liabilities	66,406	20,940
Current portion of long-term debt	2,096	469
Total current liabilities	264,247	148,934
Long-term debt, net of debt issuance costs	616,625	617,744
Asset retirement obligations	24,766	16,097
Deferred income taxes	137,111	0
Derivatives and other noncurrent liabilities	25,001	9,377
Commitments and contingencies (Note 13)
Stockholders' equity:
Common stock, $0.001 par value; authorized 400,000,000 and 300,000,000 shares at June 30, 2018 and December 31, 2017, respectively; 212,349,072 and 110,363,539 shares issued and outstanding at June 30, 2018 and December 31, 2017, respectively, with 2,858,278 and 1,394,868 shares subject to restrictions, respectively	209	109
Additional paid-in capital	1,767,899	1,279,507
Retained earnings (accumulated deficit)	(752,905)	(681,062)
Treasury stock, at cost: zero shares at June 30, 2018 and December 31, 2017	0	0
Total stockholders' equity	1,015,203	598,554
Total liabilities and stockholders' equity	$ 2,082,953	$ 1,390,706

CONSOLIDATED BALANCE SHEETS (U3

CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) - $ / shares	Jun. 30, 2018	Dec. 31, 2017
Statement of Financial Position [Abstract]
Common Stock, Par or Stated Value Per Share (in dollars per share)	$ 0.001	$ 0.001
Common Stock, Shares Authorized	400,000,000	300,000,000
Common Stock, Shares, Issued	212,349,072	110,363,539
Common stock, shares outstanding (in shares)	212,349,072	110,363,539
Common stock, shares subject to restrictions (in shares)	2,858,278	1,394,868
Treasury stock, shares (in shares)	0	0

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS (UNAUDITED) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Operating Revenues:
Total operating revenues	$ 110,398	$ 51,066	$ 191,208	$ 101,602
Operating Expenses:
Production tax expense	9,684	3,434	14,859	3,756
Exploration expense	7	3	20	30
Impairment, dry hole costs and abandonment expense	108	1	425	8,075
(Gain) loss on sale of properties	564	0	972	(92)
Depreciation, depletion and amortization	52,175	39,337	93,160	77,677
Unused commitments	4,572	4,558	9,110	9,130
General and administrative expense	11,624	8,943	21,731	18,292
Merger transaction expense	1,277	0	6,040	0
Other operating expenses, net	9	(755)	48	(1,328)
Total operating expenses	88,626	61,562	161,641	127,932
Operating Income (Loss)	21,772	(10,496)	29,567	(26,330)
Other Income and Expense:
Interest and other income	701	492	1,392	698
Interest expense	(13,093)	(16,137)	(26,183)	(30,088)
Commodity derivative gain (loss)	(56,286)	15,598	(76,619)	32,062
Gain (loss) on extinguishment of debt	0	(7,904)	0	(7,904)
Total other income and expense	(68,678)	(7,951)	(101,410)	(5,232)
Income (Loss) before Income Taxes	(46,906)	(18,447)	(71,843)	(31,562)
(Provision for) Benefit from Income Taxes	0	0	0	0
Net Income (Loss)	$ (46,906)	$ (18,447)	$ (71,843)	$ (31,562)
Net Income (Loss) Per Common Share, Basic (in dollars per share)	$ (0.22)	$ (0.25)	$ (0.43)	$ (0.42)
Net Income (Loss) Per Common Share, Diluted (in dollars per share)	$ (0.22)	$ (0.25)	$ (0.43)	$ (0.42)
Weighted Average Common Shares Outstanding, Basic	209,393,002	74,794,448	166,731,287	74,669,806
Weighted Average Common Shares Outstanding, Diluted	209,393,002	74,794,448	166,731,287	74,669,806
Oil, gas and NGL production
Operating Revenues:
Production and other revenues	$ 110,118	$ 50,941	$ 190,949	$ 101,366
Other operating revenues, net
Operating Revenues:
Production and other revenues	280	125	259	236
Lease operating expense
Operating Expenses:
Cost of goods and services	7,594	5,506	13,845	11,368
Gathering, transportation and processing expense
Operating Expenses:
Cost of goods and services	$ 1,012	$ 535	$ 1,431	$ 1,024

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (UNAUDITED) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Statement of Comprehensive Income [Abstract]
Net Income (Loss)	$ (46,906)	$ (18,447)	$ (71,843)	$ (31,562)	$ (138,225)
Other Comprehensive Income (Loss), net of tax:
Other comprehensive income (loss)	0	0	0	0
Comprehensive Income (Loss)	$ (46,906)	$ (18,447)	$ (71,843)	$ (31,562)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Operating Activities:
Net Income (Loss)	$ (71,843)	$ (31,562)
Adjustments to reconcile to net cash provided by operations:
Depreciation, depletion and amortization	93,160	77,677
Impairment, dry hole costs and abandonment expense	425	8,075
Commodity derivative (gain) loss	76,619	(32,062)
Settlements of commodity derivatives	(23,848)	9,798
Stock compensation and other non-cash charges	3,490	3,654
Amortization of deferred financing costs	1,131	1,155
(Gain) loss on extinguishment of debt	0	7,904
(Gain) loss on sale of properties	972	(92)
Change in operating assets and liabilities:
Accounts receivable	(4,197)	2,427
Prepayments and other assets	(1,089)	(1,377)
Accounts payable, accrued and other liabilities	(36,033)	(5,585)
Amounts payable to oil and gas property owners	25,532	2,673
Production taxes payable	4,568	(4,486)
Net cash provided by (used in) operating activities	68,887	38,199
Investing Activities:
Additions to oil and gas properties, including acquisitions	(220,816)	(104,236)
Additions of furniture, equipment and other	(470)	(201)
Repayment of debt associated with merger, net of cash acquired	(53,357)	0
Proceeds from sale of properties and other investing activities	530	(615)
Net cash provided by (used in) investing activities	(274,113)	(105,052)
Financing Activities:
Proceeds from debt	0	275,000
Principal payments on debt	(232)	(322,113)
Proceeds from sale of common stock, net of offering costs	0	(298)
Deferred financing costs and other	(1,629)	(6,012)
Net cash provided by (used in) financing activities	(1,861)	(53,423)
Increase (Decrease) in Cash and Cash Equivalents	(207,087)	(120,276)
Beginning Cash and Cash Equivalents	314,466	275,841
Ending Cash and Cash Equivalents	$ 107,379	$ 155,565

CONSOLIDATED STATEMENTS OF STOC

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (UNAUDITED) - USD ($) $ in Thousands	Total	Common Stock	Additional Paid-In Capital	Retained Earnings (Accumulated Deficit)	Treasury Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Cumulative effect of accounting change	$ (329)		$ 180	$ (509)
Balance at Dec. 31, 2016	571,543	$ 74	1,113,797	(542,328)	$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Exercise of options, restricted stock activity and shares exchanged for exercise and tax withholding	(1,252)	1			(1,253)
Stock-based compensation	7,099		7,099
Retirement of treasury stock	0		(1,253)		1,253
Exchange of senior notes for shares of common stock	48,992	11	48,981
Issuance of common stock, net of offering costs	110,726	23	110,703
Net income (loss)	(138,225)			(138,225)
Balance at Dec. 31, 2017	598,554	109	1,279,507	(681,062)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Exercise of options, restricted stock activity and shares exchanged for exercise and tax withholding	(1,490)				(1,490)
Stock-based compensation	5,982		5,982
Retirement of treasury stock	0		(1,490)		1,490
Issuance of common stock, merger	484,000	100	483,900
Net income (loss)	(71,843)			(71,843)
Balance at Jun. 30, 2018	$ 1,015,203	$ 209	$ 1,767,899	$ (752,905)	$ 0

Organization

Organization	6 Months Ended
	Jun. 30, 2018
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization	Organization HighPoint Resources Corporation, a Delaware corporation, together with its wholly-owned subsidiaries (collectively, the "Company"), is an independent oil and gas company engaged in the exploration, development and production of oil, natural gas and natural gas liquids ("NGLs"). The Company became the successor to Bill Barrett Corporation ("Bill Barrett"), on March 19, 2018, upon closing of the transactions contemplated by the Agreement and Plan of Merger, dated December 4, 2017 (the "Merger Agreement"), pursuant to which Bill Barrett combined with Fifth Creek Operating Company, LLC ("Fifth Creek") (the "Merger"). As a result of the Merger, Bill Barrett became a wholly-owned subsidiary of HighPoint Resources Corporation and subsequently Bill Barrett changed its name to HighPoint Operating Corporation. The Company currently conducts its activities principally in the Denver Julesburg Basin ("DJ Basin") in Colorado. Except where the context indicates otherwise, references herein to the "Company" with respect to periods prior to the completion of the Merger refer to Bill Barrett and its subsidiaries.

Summary of Significant Accounti

Summary of Significant Accounting Policies	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Summary of Significant Accounting Policies Basis of Presentation. The accompanying Unaudited Consolidated Financial Statements include the accounts of the Company. These statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). All intercompany accounts and transactions have been eliminated in consolidation. In the opinion of management, the accompanying consolidated financial statements include all adjustments (consisting of normal recurring accruals and adjustments) necessary to present fairly, in all material respects, the Company's interim results. However, operating results for the periods presented are not necessarily indicative of the results that may be expected for the full year. The Annual Report on Form 10-K filed by the Company's predecessor Bill Barrett for the year ended December 31, 2017 includes certain definitions and a summary of significant accounting policies and should be read in conjunction with this Quarterly Report on Form 10-Q. Except as disclosed herein, there have been no material changes to the information disclosed in the notes to the consolidated financial statements included in the Bill Barrett 2017 Annual Report on Form10-K. The results of operations attributable to the merged companies are included in the Unaudited Consolidated Statements of Operations beginning on March 19, 2018. Use of Estimates. In the course of preparing the Company's financial statements in accordance with GAAP, management makes various assumptions, judgments and estimates to determine the reported amount of assets, liabilities, revenues and expenses and in the disclosure 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 and, accordingly, actual results could differ from amounts initially established. Areas requiring the use of assumptions, judgments and estimates relate to volumes of oil, natural gas and NGL reserves used in calculating depreciation, depletion and amortization ("DD&A"), the amount of expected future cash flows used in determining possible impairments of oil and gas properties and the amount of future capital costs used in these calculations. Assumptions, judgments and estimates also are required in determining the fair values of assets acquired and liabilities assumed in business combinations, asset retirement obligations, the timing of dry hole costs, impairments of proved and unproved oil and gas properties, valuing deferred tax assets and estimating fair values of derivative instruments and stock-based payment awards. Accounts Receivable. Accounts receivable is comprised of the following: As of June 30, 2018 As of December 31, 2017 (in thousands) Oil, gas and NGL sales $ 41,998 $ 36,569 Due from joint interest owners 21,381 14,779 Other 65 270 Allowance for doubtful accounts (1 ) (203 ) Total accounts receivable $ 63,443 $ 51,415 Oil and Gas Properties. The Company's oil, gas and NGL exploration and production activities are accounted for using the successful efforts method. Under this method, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether the well has found proved reserves. If an exploratory well does not find proved reserves, the costs of drilling the well are charged to expense and remain within cash flows from investing activities in the Unaudited Consolidated Statements of Cash Flows. If an exploratory well does find proved reserves, the costs remain capitalized and are included within additions to oil and gas properties and remain within cash flows from investing activities in the Unaudited Consolidated Statements of Cash Flows. The costs of development wells are capitalized whether proved reserves are added or not. Oil and gas lease acquisition costs are also capitalized. Upon sale or retirement of depreciable or depletable property, the cost and related accumulated DD&A are eliminated from the accounts and the resulting gain or loss is recognized. Other exploration costs, including certain geological and geophysical expenses and delay rentals for oil and gas leases, are charged to expense as incurred. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the unit-of-production amortization rate. Maintenance and repairs are charged to expense, and renewals and betterments are capitalized to the appropriate property and equipment accounts. Unproved oil and gas property costs are transferred to proved oil and gas properties if the properties are subsequently determined to be productive or are assigned proved reserves. Proceeds from sales of partial interests in unproved leases are accounted for as a recovery of cost without recognizing any gain until all costs are recovered. Unproved oil and gas properties are assessed periodically for impairment based on remaining lease terms, drilling results, reservoir performance, commodity price outlooks, future plans to develop acreage, recent sales prices of comparable properties and other relevant matters. Materials and supplies consist primarily of tubular goods and well equipment to be used in future drilling operations or repair operations and are carried at the lower of cost or market value. The following table sets forth the net capitalized costs and associated accumulated DD&A and non-cash impairments relating to the Company's oil, natural gas and NGL producing activities: As of June 30, 2018 As of December 31, 2017 (in thousands) Proved properties $ 348,607 $ 230,800 Wells and related equipment and facilities 1,264,134 1,088,692 Support equipment and facilities 52,976 38,776 Materials and supplies 10,351 2,900 Total proved oil and gas properties (1) $ 1,676,068 $ 1,361,168 Unproved properties (1) 620,403 18,832 Wells and facilities in progress 112,072 65,844 Total unproved oil and gas properties, excluded from amortization $ 732,475 $ 84,676 Accumulated depreciation, depletion, amortization and impairment (510,029 ) (433,234 ) Total oil and gas properties, net $ 1,898,514 $ 1,012,610 (1) Includes properties acquired in the Merger of $105.7 million of proved oil and gas properties and $608.6 million of unproved properties. See Note 4 for additional information regarding the Merger. The Company reviews oil and natural gas properties for impairment on a quarterly basis or whenever events and circumstances indicate that a decline in the recoverability of their carrying value may have occurred. The Company estimates the expected undiscounted future net cash flows of its oil and gas properties using proved and risked probable and possible reserves based on the Company's development plans and best estimate of future production, commodity pricing, reserve risking, gathering and transportation deductions, production tax rates, lease operating expenses and future development costs. The Company compares such undiscounted future net cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the undiscounted future net cash flows exceed the carrying amount of the oil and gas properties, no impairment is taken. If the carrying amount of a property exceeds the undiscounted future net cash flows, the Company will impair the carrying value to fair value based on an analysis of quantitative and qualitative factors existing as of the balance sheet date. The Company does not believe that the undiscounted future net cash flows of its oil and gas properties represent the applicable market value. The factors used to determine fair value may include, but are not limited to, recent sales prices of comparable properties, indications from marketing activities, the present value of future revenues, net of estimated operating and development costs using estimates of reserves, future commodity pricing, future production estimates, anticipated capital expenditures and various discount rates commensurate with the risk and current market conditions associated with realizing the projected cash flows. In addition, oil and gas properties are assessed for impairment once they meet the criteria to be classified as held for sale. Assets held for sale are carried at the lower of carrying cost or fair value less costs to sell. The fair value of the assets is determined using a market approach, based on an estimated selling price, as evidenced by current marketing activities, if possible. If an estimated selling price is not available, the Company utilizes the income valuation technique, which involves calculating the present value of future net cash flows as discussed above. If the carrying amount of the assets exceeds the fair value less costs to sell, an impairment will result to reduce the value of the properties down to fair value less costs to sell. The Company recognized non-cash impairment charges, which were included within impairment, dry hole costs and abandonment expense in the Unaudited Consolidated Statements of Operations, as follows: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (in thousands) Impairment of unproved oil and gas properties (1) $ — $ — $ — $ 8,010 Dry hole costs — — — 2 Abandonment expense and lease expirations 108 1 425 63 Total impairment, dry hole costs and abandonment expense $ 108 $ 1 $ 425 $ 8,075 (1) The Company recognized impairment related to unproved oil and gas properties in the Cottonwood Gulch area of the Piceance Basin during the six months ended June 30, 2017 . The Company had no current plan to develop this acreage. The provision for DD&A of oil and gas properties is calculated on a field-by-field basis based on geologic and reservoir delineation using the unit-of-production method. Natural gas and NGLs are converted to an oil equivalent, Boe, at the standard rate of six Mcf to one Boe and forty-two gallons to one Boe, respectively. Estimated future dismantlement, restoration and abandonment costs are taken into consideration by this calculation. Accounts Payable and Other Accrued Liabilities. Accounts payable and other accrued liabilities are comprised of the following: As of June 30, 2018 As of December 31, 2017 (in thousands) Accrued drilling, completion and facility costs $ 77,133 $ 35,856 Accrued lease operating, gathering, transportation and processing expenses 6,275 4,360 Accrued general and administrative expenses 8,744 11,134 Accrued interest payable 6,482 6,484 Accrued merger transaction expenses 503 8,278 Accrued hedge settlements 4,996 65 Prepayments from partners 1,069 2,524 Trade payables 4,098 10,067 Other 4,338 5,287 Total accounts payable and other accrued liabilities $ 113,638 $ 84,055 Environmental Liabilities. Environmental expenditures that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation are expensed. Environmental liabilities are accrued when environmental assessments and/or clean-ups are probable, and the costs can be reasonably estimated. Recent case law in Wyoming has exposed us to obligations for plugging and abandoning wells, and associated reclamation, for assets that were sold to other industry parties in prior years that are now in default. Regulatory agencies and landowners have demanded that the Company perform such activities. Revenue Recognition. All of the Company's sales of oil, gas and NGLs are made under contracts with customers, whereby revenues are recognized when the Company satisfies its performance obligations and the customer obtains control of the product. Performance obligations under the Company's contracts with customers are typically satisfied at a point-in-time through monthly delivery of oil, gas and/or NGLs. Accordingly, at the end of the reporting period, the Company does not have any unsatisfied performance obligations. The Company's contracts with customers typically include variable consideration based on monthly pricing tied to local indices and volumes delivered in the current month. The nature of the Company's contracts with customers does not require the Company to constrain variable consideration for accounting purposes. As of June 30, 2018 , the Company had open contracts with customers with terms of 1 month to 20 years , as well as evergreen contracts that renew on a periodic basis if not canceled by the Company or the customer. The Company's contracts with customers typically require payment within one month of delivery. Under the Company's contracts with customers, natural gas and its components, including NGLs, are either sold to a midstream entity (which processes the natural gas and subsequently sells the resulting residue gas and NGLs) or are sold to a gas or NGL purchaser after being processed by a third party for a fee. Regardless of the contract structure type, the terms of these contracts compensate the Company for the value of the residue gas and NGLs at current market prices for each product. The Company's oil is sold to multiple oil purchasers at specific delivery points at or near the wellhead. All costs incurred to gather, transport and/or process the Company's oil, gas and NGLs after control has transferred to the customer are considered components of the consideration received from the customer and thus recorded in oil, gas and NGL production revenues in the Unaudited Consolidated Statements of Operations. All costs incurred prior to the transfer of control to the customer are included in gathering, transportation and processing expense in the Unaudited Consolidated Statements of Operations. Gas imbalances from the sale of natural gas are recorded on the basis of gas actually sold by the Company. If the Company's aggregate sales volumes for a well are greater (or less) than its proportionate share of production from the well, a liability (or receivable) is established to the extent there are insufficient proved reserves available to make-up the overproduced (or underproduced) imbalance. Imbalances have not been significant in the periods presented. Derivative Instruments and Hedging Activities. The Company periodically uses derivative financial instruments to achieve a more predictable cash flow from its oil, natural gas and NGL sales by reducing its exposure to price fluctuations. Derivative instruments are recorded at fair market value and are included in the Unaudited Consolidated Balance Sheets as assets or liabilities. Income Taxes. Income taxes are provided for the tax effects of transactions reported in the financial statements and consist of taxes currently payable plus deferred income taxes related to certain income and expenses recognized in different periods for financial and income tax reporting purposes. Deferred income tax assets and liabilities represent the future tax return consequences of those differences, which will either be taxable or deductible when assets are recovered or liabilities are settled. Deferred income taxes also include tax credits and net operating losses that are available to offset future income taxes. Deferred income taxes are measured by applying currently enacted tax rates. Deferred tax assets are regularly reviewed, considering all positive and negative evidence, including scheduled reversals of deferred tax liabilities, projected future taxable income, taxable strategies and results of recent operations. The assumptions about future taxable income require significant judgment to determine whether it is more likely than not that the deferred tax asset will be realized. Changes to the Company's development plans, increases in market prices for hydrocarbons, improvements in our operating results, or other factors, could result in a release of some or all of the valuation allowance in a future period which would result in the recognition of a tax benefit. The Company accounts for uncertainty in income taxes for tax positions taken or expected to be taken in a tax return. Only tax positions that meet the more-likely-than-not recognition threshold are recognized. The Company does not have any uncertain tax positions recorded as of June 30, 2018 . Earnings/Loss Per Share. Basic net income (loss) per common share is calculated by dividing net income (loss) attributable to common stock by the weighted average number of common shares outstanding during each period. Diluted net income (loss) per common share is calculated by dividing net income (loss) attributable to common stock by the weighted average number of common shares outstanding and other dilutive securities. Potentially dilutive securities for the diluted net income per common share calculations consist of nonvested shares of common stock and outstanding in-the-money stock options to purchase the Company's common stock. As the Company was in a net loss position, all potentially dilutive securities were anti-dilutive for the three and six months ended June 30, 2018 and 2017 . The following table sets forth the calculation of basic and diluted income (loss) per share: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (in thousands, except per share amounts) Net income (loss) $ (46,906 ) $ (18,447 ) $ (71,843 ) $ (31,562 ) Basic weighted-average common shares outstanding in period 209,393 74,794 166,731 74,670 Diluted weighted-average common shares outstanding in period 209,393 74,794 166,731 74,670 Basic net income (loss) per common share $ (0.22 ) $ (0.25 ) $ (0.43 ) $ (0.42 ) Diluted net income (loss) per common share $ (0.22 ) $ (0.25 ) $ (0.43 ) $ (0.42 ) New Accounting Pronouncements. In June 2018, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2018-07, Stock Compensation-Improvements to Non-employee Share-Based Payment Accounting . The objective of this update is to simplify several aspects of the accounting for non-employee share-based payment transactions resulting from expanding the scope of Topic 718, Compensation- Stock Compensation , to include share-based payment transactions for acquiring goods and services from non-employees. ASU 2018-07 is effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods. The standard will not have a material impact on the Company's disclosures and financial statements. In May 2017, the FASB issued ASU 2017-09, Stock Compensation-Scope of Modification Accounting . The objective of this update is to provide clarity and reduce both diversity in practice and cost and complexity when applying a change to the terms or conditions of a share-based payment award. ASU 2017-09 was effective for annual periods beginning after December 15, 2017, and interim periods within those annual periods. The standard was adopted on January 1, 2018 and did not have a material impact on the Company's disclosures and financial statements. In January 2017, the FASB issued ASU 2017-01, Business Combinations: Clarifying the definition of a business . The objective of this update is to clarify the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. ASU 2017-01 was effective for annual and interim periods beginning after December 15, 2017. The standard was adopted prospectively on January 1, 2018 and did not have a material impact on the Company's disclosures and financial statements. The accounting treatment of the Merger was not affected by this guidance. See Note 4 for additional information regarding the Merger. In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows-Classification of Certain Cash Receipts and Cash Payments . The objective of this update is to address eight specific cash flow issues in order to reduce the existing diversity in practice. ASU 2016-15 was effective for the annual periods beginning after December 15, 2017, and interim periods within those annual periods. The standard was adopted on January 1, 2018 and did not have a material impact on the Company's disclosures and financial statements. In February 2016, the FASB issued ASU 2016-02, Leases . The objective of this update is to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. ASU 2016-02 is effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods. The Company has performed an initial assessment by compiling and analyzing contracts and leasing arrangements that may be affected. The Company is still evaluating the impact of adopting this standard. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers. The objective of this update is to clarify the principles for recognizing revenue and to develop a common revenue standard. The FASB subsequently issued ASU 2015-14, ASU 2016-08, ASU 2016-10, ASU 2016-12 and ASU 2016-20, which provided additional implementation guidance and deferred the effective date of ASU 2014-09. The standard was effective for annual reporting periods beginning after December 15, 2017, and interim periods within those annual periods. The standard was adopted on January 1, 2018 using the modified retrospective transition method, which was applied to contracts in place at the date of adoption. The adoption required the Company to net some additional gathering, transportation and processing expenses against its oil, gas and NGL production revenues. However, the cash flow and timing of the Company's revenue was not impacted and there was therefore no impact on the Company's net income (loss) or net income (loss) per common share. The standard also required additional footnote disclosures. See the " Revenue Recognition" section above for additional disclosures.

Supplemental Disclosures of Cas

Supplemental Disclosures of Cash Flow Information	6 Months Ended
	Jun. 30, 2018
Supplemental Cash Flow Elements [Abstract]
Supplemental Disclosures of Cash Flow Information	Supplemental Disclosures of Cash Flow Information Supplemental cash flow information is as follows: Six Months Ended June 30, 2018 2017 (in thousands) Cash paid for interest $ 25,058 $ 30,976 Cash paid for income taxes — — Supplemental disclosures of non-cash investing and financing activities: Accrued liabilities - oil and gas properties 79,792 37,175 Change in asset retirement obligations, net of disposals 7,887 10,545 Retirement of treasury stock (1,490 ) (1,230 ) Properties exchanged in non-cash transactions — 11,790 Issuance of common stock for Merger 484,000 —

Mergers

Mergers	6 Months Ended
	Jun. 30, 2018
Business Combinations [Abstract]
Mergers	Mergers Merger with Fifth Creek Operating Company, LLC On March 19, 2018, the Company completed the Merger with Fifth Creek. Assets acquired include approximately 81,000 net acres in Weld County in the DJ Basin, substantially all of which are operated, and 62 producing standard-length lateral wells and 10 producing extended-reach lateral wells. In addition, the Company recorded net proved reserves of 9.3 MMBoe, of which 4.7 MMBoe are proved developed reserves and 4.6 MMBoe are proved undeveloped reserves. The Merger was effected through the issuance of 100,000,000 shares of the Company's common stock, with a fair value of $484.0 million on the date of closing, and the repayment of $53.9 million of Fifth Creek debt. In connection with the Merger, the Company incurred costs of approximately $14.7 million to date of severance, consulting, advisory, legal and other merger-related fees, of which $6.0 million and $8.7 million were included in the Company's Unaudited Consolidated Statement of Operations for the six months ended June 30, 2018 and in the Company's Consolidated Statement of Operations for the year ended December 31, 2017, respectively. Purchase Price Allocation The transaction was accounted for as a business combination, using the acquisition method, with the Company being the acquirer for accounting purposes. The following table represents the preliminary allocation of the total purchase price to the identifiable assets acquired and the liabilities assumed based on the estimated fair values at the acquisition date. We expect to complete the purchase price allocation during the 12-month period following the acquisition date, during which time the value of the assets and liabilities may be revised as appropriate. The following table sets forth our preliminary purchase price allocation: March 19, 2018 (in thousands) Purchase Price: Fair value of common stock issued $ 484,000 Plus: Repayment of Fifth Creek debt 53,900 Total purchase price 537,900 Plus Liabilities Assumed: Accounts payable and accrued liabilities 25,382 Current unfavorable contract 2,651 Other current liabilities 13,797 Asset retirement obligations 7,361 Long-term deferred tax liability 137,111 Long-term unfavorable contract 4,449 Other noncurrent liabilities 2,354 Total purchase price plus liabilities assumed $ 731,005 Fair Value of Assets Acquired: Cash 543 Accounts receivable 7,831 Oil and Gas Properties: Proved oil and gas properties 105,702 Unproved oil and gas properties 608,572 Asset Retirement Obligations 7,361 Furniture, equipment and other 931 Other noncurrent assets 65 Total asset value $ 731,005 The fair value measurements of oil and natural gas properties and asset retirement obligations are based on inputs that are not observable in the market and therefore represent Level 3 inputs. The fair values of proved oil and natural gas properties and asset retirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of oil and natural gas properties included estimates of: (i) recoverable reserves; (ii) production rates; (iii) future operating and development costs; (iv) future commodity prices; and (v) a market-based weighted average cost of capital rate. The fair value of unproved properties was determined using a market approach utilizing recent transactions of a similar nature in the same basin. These inputs required significant judgments and estimates by management at the time of the valuation and are the most sensitive to possible future changes. The results of operations attributable to the merged companies are included in the Unaudited Consolidated Statements of Operations beginning on March 19, 2018. The Company generated revenues of approximately $12.3 million and $14.3 million from the Fifth Creek assets during the three and six months ended June 30, 2018 , respectively, and expenses of approximately $9.5 million and $11.3 million during the three and six months ended June 30, 2018 , respectively. Pro Forma Financial Information The following pro forma condensed combined financial information was derived from the historical financial statements of the Company and Fifth Creek and gives effect to the acquisition as if it had occurred on January 1, 2017. The below information reflects pro forma adjustments based on available information and certain assumptions that the Company believes are reasonable, including (i) the repayment of Fifth Creek's debt (ii) depletion of Fifth Creek's fair-valued proved crude oil and natural gas properties, and (iii) the estimated tax impacts of the pro forma adjustments. Additionally, pro forma earnings for the three and six months ended June 30, 2018 were adjusted to exclude merger-related costs of $1.3 million and $6.0 million , respectively, incurred by the Company and zero and $4.0 million , respectively, incurred by Fifth Creek. The pro forma results of operations do not include any cost savings or other synergies that may result from the acquisition or any estimated costs that have been or will be incurred by us to integrate the Fifth Creek assets. The pro forma condensed combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the acquisition taken place on January 1, 2017; furthermore, the financial information is not intended to be a projection of future results. Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (in thousands, except per share data) Revenues $ 110,398 $ 60,065 $ 207,140 $ 114,754 Net Income (Loss) and Comprehensive Income (Loss) (45,629 ) (19,180 ) (69,733 ) (31,879 ) Net Income (Loss) per Common Share, Basic and Diluted (0.22 ) (0.11 ) (0.33 ) (0.18 )

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt The Company's outstanding debt is summarized below: As of June 30, 2018 As of December 31, 2017 Maturity Date Principal Debt Issuance Costs Carrying Amount Principal Debt Issuance Costs Carrying Amount (in thousands) Amended Credit Facility April 8, 2020 $ — $ — $ — $ — $ — $ — 7.0% Senior Notes (1) October 15, 2022 350,000 (3,628 ) 346,372 350,000 (4,033 ) 345,967 8.75% Senior Notes (2) June 15, 2025 275,000 (4,747 ) 270,253 275,000 (5,080 ) 269,920 Lease Financing Obligation (3) August 10, 2020 2,096 — 2,096 2,328 (2 ) 2,326 Total Debt $ 627,096 $ (8,375 ) $ 618,721 $ 627,328 $ (9,115 ) $ 618,213 Less: Current Portion of Long-Term Debt (4) 2,096 — 2,096 469 — 469 Total Long-Term Debt $ 625,000 $ (8,375 ) $ 616,625 $ 626,859 $ (9,115 ) $ 617,744 (1) The aggregate estimated fair value of the 7.0% Senior Notes was approximately $353.5 million and $356.1 million as of June 30, 2018 and December 31, 2017 , respectively, based on reported market trades of these instruments. (2) The aggregate estimated fair value of the 8.75% Senior Notes was approximately $294.3 million and $305.3 million as of June 30, 2018 and December 31, 2017 , respectively, based on reported market trades of these instruments. (3) The aggregate estimated fair value of the Lease Financing Obligation was approximately $1.9 million and $2.1 million as of June 30, 2018 and December 31, 2017 , respectively. As there is no active, public market for the Lease Financing Obligation, the aggregate estimated fair value was based on market-based parameters of comparable term secured financing instruments. (4) The current portion of long-term debt includes the current portion of the Lease Financing Obligation. The Company has elected to exercise the early buyout option pursuant to which the Company will purchase the equipment for $1.8 million on February 10, 2019. Amended Credit Facility The Amended Credit Facility had commitments from 13 lenders and a borrowing base of $300.0 million as of June 30, 2018 . As credit support for future payments under a contractual obligation, a $26.0 million letter of credit has been issued under the Amended Credit Facility, which reduced the available borrowing capacity of the Amended Credit Facility as of June 30, 2018 to $274.0 million . There were no borrowings under the Amended Credit Facility in 2018 to date or in 2017. Interest rates are LIBOR plus applicable margins of 1.5% to 2.5% or ABR plus 0.5% to 1.5% , and the unused commitment fee is between 0.375% and 0.5% based on borrowing base utilization. The borrowing base under the Amended Credit Facility is determined at the discretion of the lenders, based on the collateral value of the Company's proved reserves that have been mortgaged to the lenders, and is subject to regular re-determinations on or about April 1 and October 1 of each year, as well as following any property sales. On May 1, 2018, the Company's borrowing base was re-affirmed at $300.0 million based on Bill Barrett's proved reserves in place at December 31, 2017 and the Company's commodity hedge position. Borrowing bases are computed based on proved oil, natural gas and NGL reserves, hedge positions and estimated future cash flows from those reserves calculated using future commodity pricing provided by the Company's lenders, as well as any other outstanding debt. Lower commodity prices could result in a decreased borrowing base. The Amended Credit Facility contains certain financial covenants. The Company is currently in compliance with all financial covenants and has complied with all financial covenants since issuance. If the Company fails to comply with the covenants or other terms of any agreements governing the Company's debt, the Company's lenders and holders of the Company's senior notes may have the right to accelerate the maturity of that debt and foreclose upon the collateral, if any, securing that debt. The occurrence of any such event would adversely affect the Company's financial condition. 7.0% Senior Notes Due 2022 The Company's $350.0 million aggregate principal amount of 7.0% Senior Notes mature on October 15, 2022 at par, unless earlier redeemed or purchased by the Company. Interest is payable in arrears semi-annually on April 15 and October 15 of each year. The 7.0% Senior Notes are senior unsecured obligations and rank equal in right of payment with all of the Company's other existing and future senior unsecured indebtedness, including the 8.75% Senior Notes. The 7.0% Senior Notes became redeemable at the Company's option on October 15, 2017 at a redemption price of 103.500% of the principal amount. The redemption price will decrease to 102.333% , 101.167% and 100.000% of the principal amount on or after October 15, 2018, 2019 and 2020, respectively. 8.75% Senior Notes Due 2025 The Company's $275.0 million aggregate principal amount of 8.75% Senior Notes mature on June 15, 2025 at par, unless earlier redeemed or purchased by the Company. Interest is payable in arrears semi-annually on June 15 and December 15 of each year. The 8.75% Senior Notes are senior unsecured obligations and rank equal in right of payment with all of the Company's other existing and future senior unsecured indebtedness, including the 7.0% Senior Notes. The 8.75% Senior Notes will become redeemable at the Company's option on or after June 15, 2020, 2021, 2022 and 2023 at redemption prices of 106.563% , 104.375% , 102.188% and 100.000% of the principal amount, respectively. Prior to June 15, 2020, the Company may use proceeds of an equity offering to redeem up to 35% of the principal amount at a redemption price of 108.750% of the principal amount. In addition, prior to June 15, 2020, the Company may redeem the notes at a redemption price equal to 100.000% of the principal amount plus a specified "make-whole" premium. The issuer of the 7.0% Senior Notes and the 8.75% Senior Notes is HighPoint Operating Corporation (f/k/a Bill Barrett). Pursuant to supplemental indentures entered into in connection with the Merger, HighPoint Resources Corporation became a guarantor of the 7.0% Senior Notes and the 8.75% Senior Notes in March 2018. A subsidiary of HighPoint Operating Corporation is also a guarantor of the Senior Notes. All covenants in the indentures governing the notes limit the activities of HighPoint Operating Corporation and the subsidiary guarantor, including limitations on the ability of HighPoint Operating Corporation to pay dividends, incur additional indebtedness, make restricted payments, create liens, sell assets or make loans to HighPoint Resources Corporation, but in most cases the covenants in the indentures are not applicable to HighPoint Resources Corporation. HighPoint Operating Corporation is currently in compliance with all covenants and has complied with all covenants since issuance. Nothing in the indentures governing the 7.0% Senior Notes or the 8.75% Senior Notes prohibits the Company from repurchasing any of the notes from time to time at any price in open market purchases, negotiated transactions or by tender offer or otherwise without any notice to or consent of the holders. Lease Financing Obligation Due 2020 The Company has a lease financing obligation with a balance of $2.1 million as of June 30, 2018 resulting from the Company's sale and subsequent lease back of certain compressors and related facilities owned by the Company (the "Lease Financing Obligation"). The Lease Financing Obligation expires on August 10, 2020 , and the Company has the option to purchase the equipment at the end of the lease term for the then current fair market value. The Lease Financing Obligation also contains an early buyout option pursuant to which the Company will purchase the equipment for $1.8 million on February 10, 2019. The lease payments related to the equipment are recognized as principal and interest expense based on a weighted average implicit interest rate of 3.3% . See Note 12 for a discussion of aggregate minimum future lease payments.

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2018
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations A reconciliation of the Company's asset retirement obligations for the six months ended June 30, 2018 is as follows (in thousands): As of December 31, 2017 $ 17,586 Liabilities incurred (1) 8,454 Liabilities settled (727 ) Disposition of properties (66 ) Accretion expense 574 Revisions to estimate 226 As of June 30, 2018 $ 26,047 Less: Current asset retirement obligations 1,281 Long-term asset retirement obligations $ 24,766 (1) Includes $7.4 million associated with properties acquired in the Merger during the six months ended June 30, 2018 . See Note 4 for additional information regarding this Merger.

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2018
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). The Company uses market data or assumptions that market participants would use in pricing the asset or liability, including assumptions about risk. These inputs can be readily observable, market corroborated or generally unobservable. A fair value hierarchy was established that prioritizes the inputs used to measure fair value. The hierarchy gives the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities (Level 1 measurements) and the lowest priority to unobservable inputs (Level 3 measurements). Level 1 – Quoted prices are available in active markets for identical assets or liabilities as of the reporting date. Active markets are those in which transactions for the asset or liability occur in sufficient frequency and volume to provide pricing information on an ongoing basis. Level 2 – Quoted prices are available in active markets for similar assets or liabilities and in non-active markets for identical or similar instruments. Model-derived valuations have inputs that are observable or whose significant value drivers are observable. These models are primarily industry-standard models that consider various assumptions, including quoted forward prices for commodities, time value, volatility factors and current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these assumptions are observable in the marketplace throughout the full term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Level 3 – Pricing inputs include significant inputs that are generally less observable than objective sources. These inputs may be used with internally developed methodologies that result in management's best estimate of fair value. At each balance sheet date, the Company performs an analysis of all applicable instruments and includes in Level 3 all of those whose fair value is based on significant unobservable inputs. Assets and Liabilities Measured at Fair Value on a Recurring Basis Certain assets and liabilities are measured at fair value on a recurring basis in our consolidated balance sheet. The following methods and assumptions were used to estimate the fair values: Cash equivalents – The highly liquid cash equivalents are recorded at fair value. Carrying value approximates fair value, which represents a Level 1 input. Deferred compensation plan – The Company maintains a non-qualified deferred compensation plan which allows certain management employees to defer receipt of a portion of their compensation. The Company maintains assets for the deferred compensation plan in a rabbi trust. The assets of the rabbi trust are invested in publicly traded mutual funds and are recorded in other current and other long-term assets in the Unaudited Consolidated Balance Sheets. The deferred compensation plan financial assets are reported at fair value based on active market quotes, which represent Level 1 inputs. Commodity derivatives – The fair value of crude oil, natural gas and NGL swaps are valued based on an income approach using various assumptions, such as quoted forward prices for commodities and time value factors. These assumptions 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 inputs. The Company utilizes its counterparties' valuations to assess the reasonableness of its own valuations. The commodity derivatives have been adjusted for non-performance risk. For applicable financial assets carried at fair value, the credit standing of the counterparties is analyzed and factored into the fair value measurement of those assets. In addition, the fair value measurement of a liability has been adjusted to reflect the nonperformance risk of the Company. The following tables set forth by level within the fair value hierarchy the Company's non-financial assets and liabilities that were measured at fair value on a recurring basis in the Unaudited Consolidated Balance Sheets. Level 1 Level 2 Level 3 Total (in thousands) As of June 30, 2018 Financial Assets Cash equivalents $ 74,842 $ — $ — $ 74,842 Deferred compensation plan 1,412 — — 1,412 Commodity derivatives — 766 — 766 Financial Liabilities Commodity derivatives — 86,019 — 86,019 As of December 31, 2017 Financial Assets Cash equivalents 271,027 — — 271,027 Deferred compensation plan 1,749 — — 1,749 Commodity derivatives — 656 — 656 Financial Liabilities Commodity derivatives — 25,714 — 25,714 Assets and Liabilities Measured at Fair Value on a Nonrecurring Basis Certain assets and liabilities are measured at fair value on a nonrecurring basis in our consolidated balance sheets. The following methods and assumptions were used to estimate the fair values: Oil and gas properties – Oil and gas property costs are evaluated for impairment and reduced to fair value when there is an indication that the carrying costs may not be recoverable. If an impairment is necessary, the fair value is estimated by using either a market approach based on recent sales prices of comparable properties and/or indications from marketing activities or by using the income valuation technique, which involves calculating the present value of future net revenues. The present value, net of estimated operating and development costs, is calculated using estimates of reserves, future commodity pricing, future production estimates, anticipated capital expenditures and various discount rates commensurate with the risk and current market conditions associated with realizing the projected cash flows, predominantly all of which are designated as Level 3 inputs within the fair value hierarchy. Information about impaired assets is as follows: Level 1 Level 2 Level 3 Net Book (1) Impairment (in thousands) As of June 30, 2018 Proved and unproved properties $ — $ — $ — $ — $ — As of December 31, 2017 Uinta Basin oil and gas properties (2) — — 106,587 144,532 37,945 DJ Basin unproved properties (3) — — 18,832 20,887 2,055 Piceance Basin unproved properties (4) — — — 9,098 9,098 (1) Amount represents net book value at the date of assessment. (2) The Company recognized a non-cash impairment charge associated with the Company's Uinta Oil Program proved properties during the year ended December 31, 2017. The properties were sold on December 29, 2017. (3) As a result of having no future plans to develop certain acreage and/or estimated market values below carrying value, the Company recognized non-cash impairment charges of $2.1 million associated with certain non-core unproved properties in the DJ Basin during the year ended December 31, 2017 . (4) As a result of having no future plans to develop certain acreage and/or estimated market values below carrying value, the Company recognized non-cash impairment charges of $9.1 million associated with certain unproved properties in the Cottonwood Gulch area of the Piceance Basin during the year ended December 31, 2017 . Purchase price allocation – The Merger was accounted for as a business combination, using the acquisition method. The allocation of the total purchase price to the identifiable assets acquired and the liabilities assumed was based on the fair values at the acquisition date. See Note 4 for additional information regarding the fair value of the Merger. Additional Fair Value Disclosures Long-term Debt – Long-term debt is not presented at fair value on the Unaudited Consolidated Balance Sheets, as it is recorded at carrying value, net of unamortized debt issuance costs. The fair values of the Company's fixed rate 7.0% Senior Notes and 8.75% Senior Notes totaled $647.8 million and $661.4 million as of June 30, 2018 and December 31, 2017 , respectively. The fair values of the Company's fixed rate Senior Notes are based on active market quotes, which represent Level 1 inputs. There is no active, public market for the Amended Credit Facility or Lease Financing Obligation. The recorded value of the Amended Credit Facility approximates its fair value due to its floating rate structure based on the LIBOR spread, secured interest, and the Company's borrowing base utilization. The Amended Credit Facility had a balance of zero as of June 30, 2018 and December 31, 2017 . The Lease Financing Obligation fair values of $1.9 million and $2.1 million as of June 30, 2018 and December 31, 2017 , respectively, are measured based on market-based parameters of comparable term secured financing instruments. The fair value measurements for the Amended Credit Facility and Lease Financing Obligation represent Level 2 inputs.

Derivative Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments The Company uses financial derivative instruments as part of its price risk management program to achieve a more predictable cash flow from its production revenues by reducing its exposure to commodity price fluctuations. The Company has entered into financial commodity swap contracts related to the sale of a portion of the Company's production. The Company does not enter into derivative instruments for speculative or trading purposes. In addition to financial contracts, the Company may at times be party to various physical commodity contracts for the sale of oil, natural gas and NGLs that have varying terms and pricing provisions. These physical commodity contracts qualify for the normal purchase and normal sale exception and, therefore, are not subject to hedge or mark-to-market accounting. The financial impact of physical commodity contracts is included in oil, natural gas and NGL production revenues at the time of settlement. All derivative instruments, other than those that meet the normal purchase and normal sale exception, as mentioned above, are recorded at fair value and included on the Unaudited Consolidated Balance Sheets as assets or liabilities. The following table summarizes the location, as well as the gross and net fair value amounts, of all derivative instruments presented on the Unaudited Consolidated Balance Sheets as of the dates indicated. As of June 30, 2018 Balance Sheet Gross Amounts of Gross Amounts Net Amounts of (in thousands) Derivative assets $ 433 $ (433 ) (1) $ — Deferred financing costs and other noncurrent assets 333 (333 ) (1) — Total derivative assets $ 766 $ (766 ) $ — Gross Amounts of Gross Amounts Net Amounts of (in thousands) Derivative liabilities $ (66,839 ) $ 433 (1) $ (66,406 ) Derivatives and other noncurrent liabilities (19,180 ) 333 (1) (18,847 ) Total derivative liabilities $ (86,019 ) $ 766 $ (85,253 ) As of December 31, 2017 Balance Sheet Gross Amounts of Gross Amounts Net Amounts of (in thousands) Derivative assets $ 594 $ (594 ) (1) $ — Deferred financing costs and other noncurrent assets 62 (62 ) (1) — Total derivative assets $ 656 $ (656 ) $ — Gross Amounts of Gross Amounts Net Amounts of (in thousands) Derivative liabilities $ (21,534 ) $ 594 (1) $ (20,940 ) Derivatives and other noncurrent liabilities (4,180 ) 62 (1) (4,118 ) Total derivative liabilities $ (25,714 ) $ 656 $ (25,058 ) (1) Asset and liability balances with the same counterparty are presented as a net asset or liability on the Unaudited Consolidated Balance Sheets. As of June 30, 2018 , the Company had financial instruments in place to hedge the following volumes for the periods indicated: July – December 2018 For the year 2019 For the year 2020 Derivative Weighted Average Price Derivative Volumes Weighted Average Price Derivative Volumes Weighted Average Price Oil (Bbls) 2,543,651 $ 54.63 6,017,934 $ 58.09 549,000 $ 57.25 Natural Gas (MMbtu) 920,000 $ 2.68 912,500 $ 2.05 — $ — The Company's derivative financial instruments are generally executed with major financial or commodities trading institutions. The instruments expose the Company to market and credit risks and may, at times, be concentrated with certain counterparties or groups of counterparties. The Company had derivatives in place with seven different counterparties as of June 30, 2018 . Although notional amounts are used to express the volume of these contracts, the amounts potentially subject to credit risk in the event of non-performance by the counterparties are substantially smaller. The creditworthiness of counterparties is subject to continual review by management, and the Company believes all of these institutions currently are acceptable credit risks. Full performance is anticipated, and the Company has no past due receivables from any of these counterparties. It is the Company's policy to enter into derivative contracts with counterparties that are lenders in the Amended Credit Facility, affiliates of lenders in the Amended Credit Facility or potential lenders in the Amended Credit Facility. The Company's derivative contracts are documented using an industry standard contract known as a Schedule to the Master Agreement and International Swaps and Derivative Association, Inc. ("ISDA") Master Agreement or other contracts. Typical terms for these contracts include credit support requirements, cross default provisions, termination events and set-off provisions. The Company is not required to provide any credit support to its counterparties other than cross collateralization with the properties securing the Amended Credit Facility. The Company has set-off provisions in its derivative contracts with lenders under its Amended Credit Facility which, in the event of a counterparty default, allow the Company to set-off amounts owed to the defaulting counterparty under the Amended Credit Facility or other obligations against monies owed to the Company under derivative contracts. Where the counterparty is not a lender under the Company's Amended Credit Facility, the Company may not be able to set-off amounts owed by the Company under the Amended Credit Facility, even if such counterparty is an affiliate of a lender under such facility. The Company does not have any derivative balances that are offset by cash collateral.

Income Taxes

Income Taxes	6 Months Ended
	Jun. 30, 2018
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes On the date of the Merger, the Fifth Creek assets were acquired in a nontaxable transaction pursuant to Section 351 of the Internal Revenue Code. Accordingly, a deferred tax liability of $137.1 million was recorded to reflect the difference between the fair value recorded and the tax basis of the assets acquired and liabilities assumed. The tax effects of temporary differences that give rise to significant components of the deferred tax assets and deferred tax liabilities as of June 30, 2018 and December 31, 2017 are presented below: As of June 30, 2018 As of December 31, 2017 (in thousands) Deferred tax assets: Net operating loss carryforward $ 117,540 $ 170,536 Stock-based compensation 3,105 3,826 Deferred rent — 163 Deferred compensation 872 1,824 State tax credit carryforwards — 6,499 Financing obligation 649 705 Accrued expenses 593 248 Investment in partnership 1,255 — Derivative instruments 21,003 6,158 Other assets 2,203 228 Less: Valuation allowance (62,988 ) (114,530 ) Total deferred tax assets 84,232 75,657 Deferred tax liabilities: Oil and gas properties (221,129 ) (75,409 ) Prepaid expenses (214 ) (248 ) Total deferred tax assets (liabilities) (221,343 ) (75,657 ) Net deferred tax assets (liabilities) $ (137,111 ) $ — In connection with the Merger, the Company had a greater than 50% ownership change pursuant to Section 382 of the Internal Revenue Code. As a result of the ownership change, the Company's ability to use pre-change net operating losses ("NOLs") and credits against post-change taxable income is limited to an annual amount plus any built-in gains recognized within five years of the ownership change. The Company's annual limitation amount is approximately $11.7 million . The Company has reduced its Federal and state NOLs by $274.6 million and $10.0 million , respectively, and eliminated its state tax credits by $8.2 million to reflect the expected impact of the Section 382 limitation. Deferred tax assets and the corresponding valuation allowance have been reduced by $64.5 million for the expected tax effect of the Section 382 limitation. As of June 30, 2018 , the Company projected approximately $476.6 million and $476.9 million of Federal and state NOLs, respectively. The Federal NOLs begin to expire in 2025 and the state NOLs begin to expire in 2029. On December 22, 2017, the Tax Cut and Jobs Act of 2017 ("TCJA") became law. The TCJA includes significant changes to the U.S. corporate tax system including a rate reduction from 35% to 21% beginning in January of 2018. Accordingly, the 21% Federal tax rate is utilized in computing the Company's annualized effective tax rate. Other provisions of TCJA include the elimination of the corporate alternative minimum tax, acceleration of depreciation for U.S. tax purposes, limitations on deductibility of interest expense, expanded Section 162(m) limitations on the deductibility of officers' compensation, the elimination of NOL carrybacks, and indefinite carryforwards on losses generated after 2017, subject to restrictions on their utilization. In assessing the Company's ability to realize the benefit of the deferred tax assets, management must consider whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. Management considers all available evidence (both positive and negative) in determining whether a valuation allowance is required. Such evidence includes the scheduled reversal of deferred tax liabilities and projected future taxable income and tax planning strategies, and judgment is required in considering the relative weight of negative and positive evidence. In regard to the Company's deferred tax assets, the Company considered all available evidence in assessing the need for a valuation allowance.

Stockholders' Equity

Stockholders' Equity	6 Months Ended
	Jun. 30, 2018
Equity [Abstract]
Stockholders' Equity	Stockholders' Equity Common and Preferred Stock. The Company's authorized capital structure consists of 75,000,000 shares of preferred stock, par value, $0.001 per share, and 400,000,000 shares of common stock, par value $0.001 per share. In March 2018, the Company adopted an amended and restated Certificate of Incorporation, which increased the number of authorized shares of common stock from 300,000,000 to 400,000,000 . There are no issued and outstanding shares of preferred stock. In March 2018, the Company completed the Merger with Fifth Creek. Pursuant to the Merger Agreement, each share of Bill Barrett common stock, par value $0.001 per share (the "BBG Common Stock"), issued and outstanding immediately prior to the closing of the Merger was converted into one share of the Company's common stock and all outstanding equity interests in Fifth Creek, in the aggregate, were converted into 100,000,000 shares of the Company's common stock. In addition, all options to purchase shares of BBG Common Stock and all common stock awards and performance-based cash unit awards relating to BBG Common Stock that were outstanding immediately prior to the closing of the Merger were generally converted into corresponding awards relating to shares of the Company's common stock on the same terms and conditions (excluding performance conditions) as applied prior to the closing of the Merger (with 2016 and 2017 Program performance-based cash units converting into time-based common stock awards based on actual performance for the 2016 program and target performance for the 2017 program through the closing date). See Note 11 for additional information on equity compensation. In March 2018, the Company terminated the Equity Distribution Agreement, dated as of June 2015, by and between the Company and Goldman, Sachs and Co., which established an "at-the-market" program for sales of common stock from time to time. The agreement was terminable at will upon written notification by the Company with no penalty.

Equity Incentive Compensation P

Equity Incentive Compensation Plans and Other Long-term Incentive Programs	6 Months Ended
	Jun. 30, 2018
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Equity Incentive Compensation Plans and Other Long-term Incentive Programs	Equity Incentive Compensation Plans and Other Long-term Incentive Programs The Company maintains various stock-based compensation plans and other employee benefits as discussed below. Stock-based compensation is measured at the grant date based on the value of the awards, and the fair value is recognized on a straight-line basis over the requisite service period (usually the vesting period). Nonvested shares of common stock generally vest ratably over a three year service period and nonvested shares of common stock units vest over a one year service period. Cash-based compensation is measured at fair value at each reporting date and is recognized on a straight-line basis over the requisite service period (usually the vesting period). Cash-based awards generally have a cliff vest of three years . The following table presents the long-term equity and cash incentive compensation related to awards for the periods indicated: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (in thousands) Nonvested common stock (1) $ 1,520 $ 1,553 $ 2,850 $ 3,003 Nonvested common stock units (1) 277 172 447 342 Nonvested performance-based shares (1) — 89 — 558 Nonvested performance cash units (2)(3) 451 (139 ) 378 (1,100 ) Total $ 2,248 $ 1,675 $ 3,675 $ 2,803 (1) Unrecognized compensation expense as of June 30, 2018 was $11.2 million , which related to grants of nonvested shares of common stock that are expected to be recognized over a weighted-average period of 2.0 years . (2) The nonvested performance-based cash units are accounted for as liability awards with $1.4 million in accounts payable and accrued liabilities as of December 31, 2017 and $0.6 million and $3.0 million in derivatives and other noncurrent liabilities as of June 30, 2018 and December 31, 2017 , respectively, in the Unaudited Consolidated Balance Sheets. (3) Liability awards are fair valued at each reporting date. For the three months ended June 30, 2018 , the weighted average fair value share price increased from $5.08 as of March 31, 2018 to $6.08 as of June 30, 2018 . For the three months ended June 30, 2017 , the weighted average fair value share price decreased from $4.55 as of March 31, 2017 to $3.41 as of June 30, 2017 . For the six months ended June 30, 2018 , the weighted average fair value share price increased from $5.10 as of December 31, 2017 to $6.08 as of June 30, 2018 and included the 2016 and 2017 Program conversion as an offset. See "2016 Program" and "2017 Program" below for additional information regarding the conversion. For the six months ended June 30, 2017 , the weighted average fair value share price decreased from $8.89 as of December 31, 2016 to $3.41 as of June 30, 2017 . Nonvested Equity and Cash Awards. The following tables present the equity and cash awards granted pursuant to the Company's various stock compensation plans. A summary of the Company's nonvested common stock awards for the three and six months ended June 30, 2018 and 2017 is presented below: Three Months Ended June 30, 2018 Three Months Ended June 30, 2017 Nonvested Common Stock Awards Shares Weighted Average Shares Weighted Average Outstanding at April 1, 2,657,535 $ 5.14 1,441,939 $ 7.25 Granted 221,025 7.08 28,017 3.62 Vested (15,724 ) 5.45 (26,289 ) 11.12 Forfeited or expired (4,558 ) 7.38 (43,407 ) 7.48 Outstanding at June 30, 2,858,278 5.28 1,400,260 7.10 Six Months Ended June 30, 2018 Six Months Ended June 30, 2017 Nonvested Common Stock Awards Shares Weighted Average Shares Weighted Average Outstanding at January 1, 1,394,868 $ 7.00 1,169,099 $ 9.33 Granted 1,017,448 5.45 777,244 6.01 Modified (1) 1,146,305 4.84 — — Vested (667,932 ) 8.28 (494,892 ) 10.58 Forfeited or expired (32,411 ) 6.73 (51,191 ) 7.79 Outstanding at June 30, 2,858,278 5.28 1,400,260 7.10 (1) Due to the closing of the Merger, the 2016 and 2017 Performance Cash Programs were converted from nonvested performance-based cash units to nonvested common stock awards, resulting in an increase of nonvested common stock awards for the six months ended June 30, 2018 . A summary of the Company's nonvested common stock unit awards for the three and six months ended June 30, 2018 and 2017 is presented below: Three Months Ended June 30, 2018 Three Months Ended June 30, 2017 Nonvested Common Stock Unit Awards Units Weighted Average Units Weighted Average Outstanding at April 1, 272,559 $ 6.37 147,167 $ 10.09 Granted 158,885 6.87 183,353 3.50 Vested (129,027 ) 4.62 (57,961 ) 6.75 Outstanding at June 30, 302,417 7.37 272,559 6.37 Six Months Ended June 30, 2018 Six Months Ended June 30, 2017 Nonvested Common Stock Unit Awards Units Weighted Average Units Weighted Average Outstanding at January 1, 272,559 $ 6.37 147,167 $ 10.09 Granted 162,083 6.83 186,924 3.52 Vested (132,225 ) 4.63 (61,532 ) 6.62 Outstanding at June 30, 302,417 7.37 272,559 6.37 A summary of the Company's nonvested performance-based cash unit awards for the three and six months ended June 30, 2018 and 2017 is presented below: Three Months Ended June 30, 2018 Three Months Ended June 30, 2017 Nonvested Performance-Based Cash Unit Awards Units Weighted Average Units Weighted Average Outstanding at April 1, 796,423 1,567,400 Granted 49,833 25,017 Forfeited or expired — (55,219 ) Outstanding at June 30, 846,256 $ 6.08 1,537,198 $ 3.07 Six Months Ended June 30, 2018 Six Months Ended June 30, 2017 Nonvested Performance-Based Cash Unit Awards Units Weighted Average Units Weighted Average Outstanding at January 1, 1,548,083 942,326 Granted 846,256 658,158 Performance goal adjustment (1) 11,289 — Modified (2) (1,211,478 ) — Vested (286,652 ) — Forfeited or expired (61,242 ) (63,286 ) Outstanding at June 30, 846,256 $ 6.08 1,537,198 $ 3.07 (1) The 2015 Program vested at 104.1% in excess of target level and resulted in additional units vested in March 2018. These units are included in the vested line item for the six months ended June 30, 2018 . (2) Due to the closing of the Merger, the 2016 and 2017 Performance Cash Programs were converted from nonvested performance-based cash units to nonvested common stock awards, resulting in a decrease in nonvested performance-based cash units for the six months ended June 30, 2018 . The 2016 Program converted based on its performance through March 19, 2018, which resulted in 89% of the units converting to nonvested common stock awards or a reduction of 65,173 units converting to nonvested common stock awards. Performance Cash Program 2018 Program. In February 2018, the Compensation Committee of the Board of Directors of the Company approved a performance cash program (the "2018 Program") granting performance cash units that will settle in cash and are accounted for as liability awards. The performance-based awards contingently vest in February 2021, depending on the level at which the performance goal is achieved. The performance goal, which will be measured over the three -year period ending December 31, 2020, will be the Company's total shareholder return ("TSR") based on a matrix measurement of (1) the Company's absolute performance and (2) the Company's ranking relative to a defined peer group's individual TSRs ("Relative TSR"). The Company's absolute performance is measured against the December 29, 2017 closing share price of $5.13 . If the Company's absolute performance is lower than the $5.13 share price, the payout is zero for this portion. If the Company's absolute performance is greater than the $5.13 share price, the performance cash units will vest 1% for each 1% in growth, up to 150% of the original grant. If the Company's Relative TSR is less than the median, the payout is zero for this portion. If the Company's Relative TSR is above the median, the payout is equal to the Company's percentile rank above the median, up to 50% of the original grant. The Company's combined absolute performance and Relative TSR have a maximum vest of up to 200% of the original grant. A total of 846,256 units were granted under this program during the six months ended June 30, 2018 . 2017 Program. In February 2017, the Compensation Committee approved a performance cash program (the "2017 Program") granting performance cash units that would settle in cash and were accounted for as liability awards. In March 2018 upon the Merger closing, each award under the 2017 Program was converted to a nonvested common stock award at 100% of the original award. At the time of the modification, 619,006 units were converted to 619,006 nonvested shares of the Company's nonvested common stock. These awards no longer have a performance criteria, but continue to have a service-based criteria through the cliff vest in February 2020. The conversion of the performance-based liability award to a service-based equity award was accounted for as a modification in accordance with ASC 718, Compensation - Stock Compensation . The Company recorded an increase to additional paid-in capital ("APIC") and a decrease to derivative and other noncurrent liabilities of $0.9 million as of June 30, 2018 in the Unaudited Consolidated Statement of Stockholders' Equity and the Unaudited Consolidated Balance Sheets, respectively. 2016 Program. In March 2016, the Compensation Committee approved a performance cash program (the "2016 Program") granting performance cash units that would settle in cash and were accounted for as liability awards. In March 2018 upon the Merger closing, each award under the 2016 Program was converted to a nonvested common stock award at 89% of the original award based on the Company's performance through March 19, 2018. At the time of the modification, 592,472 units were converted to 527,299 nonvested shares of the Company's nonvested common stock. These awards no longer have a performance criteria, but continue to have a service-based criteria through the cliff vest in February 2019. The conversion of the performance-based liability award to a service-based equity award was accounted for as a modification in accordance with ASC 718, Compensation - Stock Compensation . The Company recorded an increase to APIC and a decrease to derivative and other noncurrent liabilities of $1.8 million as of June 30, 2018 in the Unaudited Consolidated Statement of Stockholders' Equity and the Unaudited Consolidated Balance Sheets, respectively. 2015 Program. In February 2015, the Compensation Committee approved a performance cash program (the "2015 Program") granting performance cash units that would settle in cash and were accounted for as liability awards. The performance-based awards were to contingently vest in May 2018, depending on the level at which the performance goals were achieved. The performance goals, which were measured over the three year period ending December 31, 2017, consisted of the TSR compared to Relative TSR (weighted at 60% ) and the percentage change in discretionary cash flow per debt adjusted share relative to a defined peer group's percentage calculation ("DCF per Debt Adjusted Share") (weighted at 40% ). The Relative TSR and DCF per Debt Adjusted Share goals would vest at 25% or 50% , respectively, of the total award for performance met at the threshold level, 100% at the target level and 200% at the stretch level. If the actual results for a metric were between the threshold and target levels or between the target and stretch levels, the vested number of units would be prorated based on the actual results compared to the threshold, target and stretch goals. If the threshold metrics were not met, no units would vest. In any event, the total number of units that could vest would not exceed 200% of the original number of performance cash units granted. At the end of the three year vesting period, any units that had not vested would be forfeited. A total of 422,345 units were granted under this program during the year ended December 31, 2015. All compensation expense related to the TSR metric would be recognized if the requisite service period was fulfilled, even if the market condition was not achieved. All compensation expense related to the DCF per Debt Adjusted Share metric would be based on the number of shares expected to vest at the end of the three year period. The Company modified the vesting date of these awards from May 2018 to March 2018. Based upon the Company's performance through 2017, 104.1% or 286,652 units of the 2015 Program vested in March 2018.

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Lease Financing Obligation. The Company has a Lease Financing Obligation with Bank of America Leasing & Capital, LLC as the lead bank as discussed in Note 5 . The aggregate undiscounted minimum future lease payments, including both principal and interest components, are presented below. The Company has elected to exercise the early buyout option pursuant to which the Company will purchase the equipment for $1.8 million on February 10, 2019. As of June 30, 2018 (in thousands) 2018 $ 269 2019 1,869 Thereafter — Total $ 2,138 Firm Transportation Agreements. The Company is party to two firm transportation contracts, through July 2021, to provide capacity on natural gas pipeline systems. The contracts require the Company to pay transportation charges regardless of the amount of pipeline capacity utilized by the Company. These monthly transportation payments are included in unused commitments expense in the Unaudited Consolidated Statements of Operations. As a result of previous divestitures in 2013 and 2014, the Company will likely not utilize the firm capacity on the natural gas pipelines. The amounts in the table below represent the Company's future minimum transportation charges: As of June 30, 2018 (in thousands) 2018 $ 9,211 2019 18,691 2020 18,691 2021 10,904 Thereafter — Total $ 57,497 Gas Gathering and Processing Agreement. The Company is party to one minimum volume commitment through December 2021 which requires the Company to deliver a minimum volume of natural gas to a midstream entity for gathering and processing. The contract requires the Company to pay a fee associated with those volumes regardless of the amount delivered. The amounts in the table below represent the Company's future minimum volume charges: As of June 30, 2018 (in thousands) 2018 $ 1,308 2019 2,365 2020 2,167 2021 1,996 Thereafter — Total $ 7,836 Lease and Other Commitments. The Company leases office space, vehicles and certain equipment under non-cancellable operating leases. The Company incurred rent expense related to these operating leases of $0.6 million and $1.1 million for the three and six months ended June 30, 2018 , respectively, and $0.5 million and $1.0 million for the three and six months ended June 30, 2017 , respectively. The Company also has non-cancellable agreements for telecommunication and geological and geophysical services. Future minimum annual payments under lease and other agreements are as follows: As of June 30, 2018 (in thousands) 2018 $ 5,132 2019 2,793 2020 2,405 2021 2,734 2022 2,764 Thereafter 13,087 Total $ 28,915 Litigation. The Company is subject to litigation, claims and governmental and regulatory proceedings arising in the ordinary course of business. It is the opinion of the Company's management that current claims and litigation involving the Company are not likely to have a material adverse effect on its Unaudited Consolidated Balance Sheet, Cash Flows or Statements of Operations.

Guarantor Subsidiaries

Guarantor Subsidiaries	6 Months Ended
	Jun. 30, 2018
Condensed Financial Information Disclosure [Abstract]
Guarantor Subsidiaries	Guarantor Subsidiaries The condensed consolidating financial information as of and for the periods ended June 30, 2018 presents the results of operations, financial position and cash flows of HighPoint Resources Corporation, or parent guarantor, HighPoint Operating Corporation (f/k/a Bill Barrett), or subsidiary issuer, and Circle B Land Company, LLC, a subsidiary guarantor, as well as the consolidating adjustments necessary to present HighPoint Resources Corporation's results on a consolidated basis. The parent guarantor and the subsidiary guarantor, on a joint and several basis, have fully and unconditionally guaranteed the debt securities of the subsidiary issuer. The indentures governing those securities limit the ability of the subsidiary issuer and the subsidiary guarantor to pay dividends or otherwise provide funding to the parent guarantor. Prior periods are presented under the structure of the Company prior to the Merger, under which Circle B Land Company, LLC and Aurora Gathering, LLC (both 100% owned subsidiaries of the Company), on a joint and several basis, fully and unconditionally guaranteed the debt of Bill Barrett, the parent issuer. On December 29, 2017, the Company completed the sale of its remaining assets in the Uinta Basin, which included the sale of Aurora Gathering, LLC. For the purpose of the following financial information, investments in subsidiaries are reflected in accordance with the equity method of accounting. The financial information may not necessarily be indicative of results of operations, cash flows, or financial position had the subsidiaries operated as independent entities. Condensed Consolidating Balance Sheets As of June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Assets: Cash and cash equivalents $ — $ 107,379 $ — $ — $ 107,379 Accounts receivable, net of allowance for doubtful accounts — 63,443 — — 63,443 Other current assets — 2,697 — — 2,697 Property and equipment, net — 1,903,726 1,894 — 1,905,620 Intercompany receivable — 854 — (854 ) — Investment in subsidiaries 1,015,203 1,040 — (1,016,243 ) — Noncurrent assets — 3,814 — — 3,814 Total assets $ 1,015,203 $ 2,082,953 $ 1,894 $ (1,017,097 ) $ 2,082,953 Liabilities and Stockholders' Equity: Accounts payable and other accrued liabilities $ — $ 113,638 $ — $ — $ 113,638 Other current liabilities — 150,609 — — 150,609 Intercompany payable — — 854 (854 ) — Long-term debt — 616,625 — — 616,625 Deferred income taxes — 137,111 — — 137,111 Other noncurrent liabilities — 49,767 — — 49,767 Stockholders' equity 1,015,203 1,015,203 1,040 (1,016,243 ) 1,015,203 Total liabilities and stockholders' equity $ 1,015,203 $ 2,082,953 $ 1,894 $ (1,017,097 ) $ 2,082,953 As of December 31, 2017 Parent Subsidiary Intercompany Consolidated (in thousands) Assets: Cash and cash equivalents $ 314,466 $ — $ — $ 314,466 Accounts receivable, net of allowance for doubtful accounts 51,415 — — 51,415 Other current assets 1,782 — — 1,782 Property and equipment, net 1,016,986 1,894 — 1,018,880 Intercompany receivable 854 — (854 ) — Investment in subsidiaries 1,040 — (1,040 ) — Noncurrent assets 4,163 — — 4,163 Total assets $ 1,390,706 $ 1,894 $ (1,894 ) $ 1,390,706 Liabilities and Stockholders' Equity: Accounts payable and other accrued liabilities $ 84,055 $ — $ — $ 84,055 Other current liabilities 64,879 — — 64,879 Intercompany payable — 854 (854 ) — Long-term debt 617,744 — — 617,744 Other noncurrent liabilities 25,474 — — 25,474 Stockholders' equity 598,554 1,040 (1,040 ) 598,554 Total liabilities and stockholders' equity $ 1,390,706 $ 1,894 $ (1,894 ) $ 1,390,706 Condensed Consolidating Statements of Operations Three Months Ended June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Operating and other revenues $ — $ 110,398 $ — $ — $ 110,398 Operating expenses — (75,725 ) — — (75,725 ) General and administrative — (11,624 ) — — (11,624 ) Merger transaction expense — (1,277 ) — — (1,277 ) Interest expense — (13,093 ) — — (13,093 ) Interest income and other income (expense) — (55,585 ) — — (55,585 ) Income (loss) before income taxes and equity in earnings (loss) of subsidiaries — (46,906 ) — — (46,906 ) (Provision for) benefit from income taxes — — — — — Equity in earnings (loss) of subsidiaries (46,906 ) — — 46,906 — Net income (loss) $ (46,906 ) $ (46,906 ) $ — $ 46,906 $ (46,906 ) Six Months Ended June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Operating and other revenues $ — $ 191,208 $ — $ — $ 191,208 Operating expenses — (133,870 ) — — (133,870 ) General and administrative — (21,731 ) — — (21,731 ) Merger transaction expense — (6,040 ) — — (6,040 ) Interest expense — (26,183 ) — — (26,183 ) Interest income and other income (expense) — (75,227 ) — — (75,227 ) Income (loss) before income taxes and equity in earnings (loss) of subsidiaries — (71,843 ) — — (71,843 ) (Provision for) benefit from income taxes — — — — — Equity in earnings (loss) of subsidiaries (71,843 ) — — 71,843 — Net income (loss) $ (71,843 ) $ (71,843 ) $ — $ 71,843 $ (71,843 ) Three Months Ended June 30, 2017 Parent Subsidiary Intercompany Consolidated (in thousands) Operating and other revenues $ 50,919 $ 147 $ — $ 51,066 Operating expenses (52,452 ) (167 ) — (52,619 ) General and administrative (8,943 ) — — (8,943 ) Interest expense (16,137 ) — — (16,137 ) Interest income and other income (expense) 8,186 — — 8,186 Income (loss) before income taxes and equity in earnings (loss) of subsidiaries (18,427 ) (20 ) — (18,447 ) (Provision for) benefit from income taxes — — — — Equity in earnings (loss) of subsidiaries (20 ) — 20 — Net income (loss) $ (18,447 ) $ (20 ) $ 20 $ (18,447 ) Six Months Ended June 30, 2017 Parent Subsidiary Intercompany Eliminations Consolidated (in thousands) Operating and other revenues $ 101,344 $ 258 $ — $ 101,602 Operating expenses (109,310 ) (330 ) — (109,640 ) General and administrative (18,292 ) — — (18,292 ) Interest expense (30,088 ) — — (30,088 ) Interest income and other income (expense) 24,856 — — 24,856 Income (loss) before income taxes and equity in earnings (loss) of subsidiaries (31,490 ) (72 ) — (31,562 ) (Provision for) benefit from income taxes — — — — Equity in earnings (loss) of subsidiaries (72 ) — 72 — Net income (loss) $ (31,562 ) $ (72 ) $ 72 $ (31,562 ) Condensed Consolidating Statements of Comprehensive Income (Loss) Three Months Ended June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Net income (loss) $ (46,906 ) $ (46,906 ) $ — $ 46,906 $ (46,906 ) Other comprehensive loss — — — — — Comprehensive income (loss) $ (46,906 ) $ (46,906 ) $ — $ 46,906 $ (46,906 ) Six Months Ended June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Net income (loss) $ (71,843 ) $ (71,843 ) $ — $ 71,843 $ (71,843 ) Other comprehensive loss — — — — — Comprehensive income (loss) $ (71,843 ) $ (71,843 ) $ — $ 71,843 $ (71,843 ) Three Months Ended June 30, 2017 Parent Subsidiary Intercompany Eliminations Consolidated (in thousands) Net income (loss) $ (18,447 ) $ (20 ) $ 20 $ (18,447 ) Other comprehensive loss — — — — Comprehensive income (loss) $ (18,447 ) $ (20 ) $ 20 $ (18,447 ) Six Months Ended June 30, 2017 Parent Subsidiary Intercompany Consolidated (in thousands) Net income (loss) $ (31,562 ) $ (72 ) $ 72 $ (31,562 ) Other comprehensive loss — — — — Comprehensive income (loss) $ (31,562 ) $ (72 ) $ 72 $ (31,562 ) Condensed Consolidating Statements of Cash Flows Six Months Ended June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Cash flows from operating activities $ — $ 68,887 $ — $ — $ 68,887 Cash flows from investing activities: Additions to oil and gas properties, including acquisitions — (220,816 ) — — (220,816 ) Additions to furniture, fixtures and other — (470 ) — — (470 ) Repayment of debt associated with merger, net of cash acquired — (53,357 ) — — (53,357 ) Proceeds from sale of properties and other investing activities — 530 — — 530 Intercompany transfers — — — — — Cash flows from financing activities: Principal payments on debt — (232 ) — — (232 ) Intercompany transfers — — — — — Other financing activities — (1,629 ) — — (1,629 ) Change in cash and cash equivalents — (207,087 ) — — (207,087 ) Beginning cash and cash equivalents — 314,466 — — 314,466 Ending cash and cash equivalents $ — $ 107,379 $ — $ — $ 107,379 Six Months Ended June 30, 2017 Parent Subsidiary Intercompany Consolidated (in thousands) Cash flows from operating activities $ 37,975 $ 224 $ — $ 38,199 Cash flows from investing activities: Additions to oil and gas properties, including acquisitions (104,236 ) — — (104,236 ) Additions to furniture, fixtures and other (201 ) — — (201 ) Proceeds from sale of properties and other investing activities (615 ) — — (615 ) Intercompany transfers 224 — (224 ) — Cash flows from financing activities: Proceeds from debt 275,000 — — 275,000 Principal payments on debt (322,113 ) — — (322,113 ) Proceeds from sale of common stock, net of offering costs (298 ) — — (298 ) Intercompany transfers — (224 ) 224 — Other financing activities (6,012 ) — — (6,012 ) Change in cash and cash equivalents (120,276 ) — — (120,276 ) Beginning cash and cash equivalents 275,841 — — 275,841 Ending cash and cash equivalents $ 155,565 $ — $ — $ 155,565

Summary of Significant Accoun21

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation. The accompanying Unaudited Consolidated Financial Statements include the accounts of the Company. These statements have been prepared in accordance with accounting principles generally accepted in the United States of America ("GAAP"). All intercompany accounts and transactions have been eliminated in consolidation. In the opinion of management, the accompanying consolidated financial statements include all adjustments (consisting of normal recurring accruals and adjustments) necessary to present fairly, in all material respects, the Company's interim results. However, operating results for the periods presented are not necessarily indicative of the results that may be expected for the full year. The Annual Report on Form 10-K filed by the Company's predecessor Bill Barrett for the year ended December 31, 2017 includes certain definitions and a summary of significant accounting policies and should be read in conjunction with this Quarterly Report on Form 10-Q. Except as disclosed herein, there have been no material changes to the information disclosed in the notes to the consolidated financial statements included in the Bill Barrett 2017 Annual Report on Form10-K. The results of operations attributable to the merged companies are included in the Unaudited Consolidated Statements of Operations beginning on March 19, 2018.
Use of Estimates	Use of Estimates. In the course of preparing the Company's financial statements in accordance with GAAP, management makes various assumptions, judgments and estimates to determine the reported amount of assets, liabilities, revenues and expenses and in the disclosure 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 and, accordingly, actual results could differ from amounts initially established. Areas requiring the use of assumptions, judgments and estimates relate to volumes of oil, natural gas and NGL reserves used in calculating depreciation, depletion and amortization ("DD&A"), the amount of expected future cash flows used in determining possible impairments of oil and gas properties and the amount of future capital costs used in these calculations. Assumptions, judgments and estimates also are required in determining the fair values of assets acquired and liabilities assumed in business combinations, asset retirement obligations, the timing of dry hole costs, impairments of proved and unproved oil and gas properties, valuing deferred tax assets and estimating fair values of derivative instruments and stock-based payment awards.
Oil and Gas Properties	Oil and Gas Properties. The Company's oil, gas and NGL exploration and production activities are accounted for using the successful efforts method. Under this method, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether the well has found proved reserves. If an exploratory well does not find proved reserves, the costs of drilling the well are charged to expense and remain within cash flows from investing activities in the Unaudited Consolidated Statements of Cash Flows. If an exploratory well does find proved reserves, the costs remain capitalized and are included within additions to oil and gas properties and remain within cash flows from investing activities in the Unaudited Consolidated Statements of Cash Flows. The costs of development wells are capitalized whether proved reserves are added or not. Oil and gas lease acquisition costs are also capitalized. Upon sale or retirement of depreciable or depletable property, the cost and related accumulated DD&A are eliminated from the accounts and the resulting gain or loss is recognized. Other exploration costs, including certain geological and geophysical expenses and delay rentals for oil and gas leases, are charged to expense as incurred. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the unit-of-production amortization rate. Maintenance and repairs are charged to expense, and renewals and betterments are capitalized to the appropriate property and equipment accounts. Unproved oil and gas property costs are transferred to proved oil and gas properties if the properties are subsequently determined to be productive or are assigned proved reserves. Proceeds from sales of partial interests in unproved leases are accounted for as a recovery of cost without recognizing any gain until all costs are recovered. Unproved oil and gas properties are assessed periodically for impairment based on remaining lease terms, drilling results, reservoir performance, commodity price outlooks, future plans to develop acreage, recent sales prices of comparable properties and other relevant matters. Materials and supplies consist primarily of tubular goods and well equipment to be used in future drilling operations or repair operations and are carried at the lower of cost or market value. The following table sets forth the net capitalized costs and associated accumulated DD&A and non-cash impairments relating to the Company's oil, natural gas and NGL producing activities: As of June 30, 2018 As of December 31, 2017 (in thousands) Proved properties $ 348,607 $ 230,800 Wells and related equipment and facilities 1,264,134 1,088,692 Support equipment and facilities 52,976 38,776 Materials and supplies 10,351 2,900 Total proved oil and gas properties (1) $ 1,676,068 $ 1,361,168 Unproved properties (1) 620,403 18,832 Wells and facilities in progress 112,072 65,844 Total unproved oil and gas properties, excluded from amortization $ 732,475 $ 84,676 Accumulated depreciation, depletion, amortization and impairment (510,029 ) (433,234 ) Total oil and gas properties, net $ 1,898,514 $ 1,012,610 (1) Includes properties acquired in the Merger of $105.7 million of proved oil and gas properties and $608.6 million of unproved properties. See Note 4 for additional information regarding the Merger. The Company reviews oil and natural gas properties for impairment on a quarterly basis or whenever events and circumstances indicate that a decline in the recoverability of their carrying value may have occurred. The Company estimates the expected undiscounted future net cash flows of its oil and gas properties using proved and risked probable and possible reserves based on the Company's development plans and best estimate of future production, commodity pricing, reserve risking, gathering and transportation deductions, production tax rates, lease operating expenses and future development costs. The Company compares such undiscounted future net cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the undiscounted future net cash flows exceed the carrying amount of the oil and gas properties, no impairment is taken. If the carrying amount of a property exceeds the undiscounted future net cash flows, the Company will impair the carrying value to fair value based on an analysis of quantitative and qualitative factors existing as of the balance sheet date. The Company does not believe that the undiscounted future net cash flows of its oil and gas properties represent the applicable market value. The factors used to determine fair value may include, but are not limited to, recent sales prices of comparable properties, indications from marketing activities, the present value of future revenues, net of estimated operating and development costs using estimates of reserves, future commodity pricing, future production estimates, anticipated capital expenditures and various discount rates commensurate with the risk and current market conditions associated with realizing the projected cash flows. In addition, oil and gas properties are assessed for impairment once they meet the criteria to be classified as held for sale. Assets held for sale are carried at the lower of carrying cost or fair value less costs to sell. The fair value of the assets is determined using a market approach, based on an estimated selling price, as evidenced by current marketing activities, if possible. If an estimated selling price is not available, the Company utilizes the income valuation technique, which involves calculating the present value of future net cash flows as discussed above. If the carrying amount of the assets exceeds the fair value less costs to sell, an impairment will result to reduce the value of the properties down to fair value less costs to sell. The Company recognized non-cash impairment charges, which were included within impairment, dry hole costs and abandonment expense in the Unaudited Consolidated Statements of Operations, as follows: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (in thousands) Impairment of unproved oil and gas properties (1) $ — $ — $ — $ 8,010 Dry hole costs — — — 2 Abandonment expense and lease expirations 108 1 425 63 Total impairment, dry hole costs and abandonment expense $ 108 $ 1 $ 425 $ 8,075 (1) The Company recognized impairment related to unproved oil and gas properties in the Cottonwood Gulch area of the Piceance Basin during the six months ended June 30, 2017 . The Company had no current plan to develop this acreage. The provision for DD&A of oil and gas properties is calculated on a field-by-field basis based on geologic and reservoir delineation using the unit-of-production method. Natural gas and NGLs are converted to an oil equivalent, Boe, at the standard rate of six Mcf to one Boe and forty-two gallons to one Boe, respectively. Estimated future dismantlement, restoration and abandonment costs are taken into consideration by this calculation.
Accounts Payable and Accrued Liabilities	Accounts Payable and Other Accrued Liabilities. Accounts payable and other accrued liabilities are comprised of the following: As of June 30, 2018 As of December 31, 2017 (in thousands) Accrued drilling, completion and facility costs $ 77,133 $ 35,856 Accrued lease operating, gathering, transportation and processing expenses 6,275 4,360 Accrued general and administrative expenses 8,744 11,134 Accrued interest payable 6,482 6,484 Accrued merger transaction expenses 503 8,278 Accrued hedge settlements 4,996 65 Prepayments from partners 1,069 2,524 Trade payables 4,098 10,067 Other 4,338 5,287 Total accounts payable and other accrued liabilities $ 113,638 $ 84,055
Environmental Liabilities	Environmental Liabilities. Environmental expenditures that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation are expensed. Environmental liabilities are accrued when environmental assessments and/or clean-ups are probable, and the costs can be reasonably estimated. Recent case law in Wyoming has exposed us to obligations for plugging and abandoning wells, and associated reclamation, for assets that were sold to other industry parties in prior years that are now in default. Regulatory agencies and landowners have demanded that the Company perform such activities.
Revenue Recognition	Revenue Recognition. All of the Company's sales of oil, gas and NGLs are made under contracts with customers, whereby revenues are recognized when the Company satisfies its performance obligations and the customer obtains control of the product. Performance obligations under the Company's contracts with customers are typically satisfied at a point-in-time through monthly delivery of oil, gas and/or NGLs. Accordingly, at the end of the reporting period, the Company does not have any unsatisfied performance obligations. The Company's contracts with customers typically include variable consideration based on monthly pricing tied to local indices and volumes delivered in the current month. The nature of the Company's contracts with customers does not require the Company to constrain variable consideration for accounting purposes. As of June 30, 2018 , the Company had open contracts with customers with terms of 1 month to 20 years , as well as evergreen contracts that renew on a periodic basis if not canceled by the Company or the customer. The Company's contracts with customers typically require payment within one month of delivery. Under the Company's contracts with customers, natural gas and its components, including NGLs, are either sold to a midstream entity (which processes the natural gas and subsequently sells the resulting residue gas and NGLs) or are sold to a gas or NGL purchaser after being processed by a third party for a fee. Regardless of the contract structure type, the terms of these contracts compensate the Company for the value of the residue gas and NGLs at current market prices for each product. The Company's oil is sold to multiple oil purchasers at specific delivery points at or near the wellhead. All costs incurred to gather, transport and/or process the Company's oil, gas and NGLs after control has transferred to the customer are considered components of the consideration received from the customer and thus recorded in oil, gas and NGL production revenues in the Unaudited Consolidated Statements of Operations. All costs incurred prior to the transfer of control to the customer are included in gathering, transportation and processing expense in the Unaudited Consolidated Statements of Operations. Gas imbalances from the sale of natural gas are recorded on the basis of gas actually sold by the Company. If the Company's aggregate sales volumes for a well are greater (or less) than its proportionate share of production from the well, a liability (or receivable) is established to the extent there are insufficient proved reserves available to make-up the overproduced (or underproduced) imbalance. Imbalances have not been significant in the periods presented.
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities. The Company periodically uses derivative financial instruments to achieve a more predictable cash flow from its oil, natural gas and NGL sales by reducing its exposure to price fluctuations. Derivative instruments are recorded at fair market value and are included in the Unaudited Consolidated Balance Sheets as assets or liabilities.
Income Taxes	Income Taxes. Income taxes are provided for the tax effects of transactions reported in the financial statements and consist of taxes currently payable plus deferred income taxes related to certain income and expenses recognized in different periods for financial and income tax reporting purposes. Deferred income tax assets and liabilities represent the future tax return consequences of those differences, which will either be taxable or deductible when assets are recovered or liabilities are settled. Deferred income taxes also include tax credits and net operating losses that are available to offset future income taxes. Deferred income taxes are measured by applying currently enacted tax rates. Deferred tax assets are regularly reviewed, considering all positive and negative evidence, including scheduled reversals of deferred tax liabilities, projected future taxable income, taxable strategies and results of recent operations. The assumptions about future taxable income require significant judgment to determine whether it is more likely than not that the deferred tax asset will be realized. Changes to the Company's development plans, increases in market prices for hydrocarbons, improvements in our operating results, or other factors, could result in a release of some or all of the valuation allowance in a future period which would result in the recognition of a tax benefit. The Company accounts for uncertainty in income taxes for tax positions taken or expected to be taken in a tax return. Only tax positions that meet the more-likely-than-not recognition threshold are recognized. The Company does not have any uncertain tax positions recorded as of June 30, 2018 .
Earnings/Loss Per Share	Earnings/Loss Per Share. Basic net income (loss) per common share is calculated by dividing net income (loss) attributable to common stock by the weighted average number of common shares outstanding during each period. Diluted net income (loss) per common share is calculated by dividing net income (loss) attributable to common stock by the weighted average number of common shares outstanding and other dilutive securities. Potentially dilutive securities for the diluted net income per common share calculations consist of nonvested shares of common stock and outstanding in-the-money stock options to purchase the Company's common stock. As the Company was in a net loss position, all potentially dilutive securities were anti-dilutive for the three and six months ended June 30, 2018 and 2017 . The following table sets forth the calculation of basic and diluted income (loss) per share: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (in thousands, except per share amounts) Net income (loss) $ (46,906 ) $ (18,447 ) $ (71,843 ) $ (31,562 ) Basic weighted-average common shares outstanding in period 209,393 74,794 166,731 74,670 Diluted weighted-average common shares outstanding in period 209,393 74,794 166,731 74,670 Basic net income (loss) per common share $ (0.22 ) $ (0.25 ) $ (0.43 ) $ (0.42 ) Diluted net income (loss) per common share $ (0.22 ) $ (0.25 ) $ (0.43 ) $ (0.42 )
New Accounting Pronouncements	New Accounting Pronouncements. In June 2018, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("ASU") 2018-07, Stock Compensation-Improvements to Non-employee Share-Based Payment Accounting . The objective of this update is to simplify several aspects of the accounting for non-employee share-based payment transactions resulting from expanding the scope of Topic 718, Compensation- Stock Compensation , to include share-based payment transactions for acquiring goods and services from non-employees. ASU 2018-07 is effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods. The standard will not have a material impact on the Company's disclosures and financial statements. In May 2017, the FASB issued ASU 2017-09, Stock Compensation-Scope of Modification Accounting . The objective of this update is to provide clarity and reduce both diversity in practice and cost and complexity when applying a change to the terms or conditions of a share-based payment award. ASU 2017-09 was effective for annual periods beginning after December 15, 2017, and interim periods within those annual periods. The standard was adopted on January 1, 2018 and did not have a material impact on the Company's disclosures and financial statements. In January 2017, the FASB issued ASU 2017-01, Business Combinations: Clarifying the definition of a business . The objective of this update is to clarify the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. ASU 2017-01 was effective for annual and interim periods beginning after December 15, 2017. The standard was adopted prospectively on January 1, 2018 and did not have a material impact on the Company's disclosures and financial statements. The accounting treatment of the Merger was not affected by this guidance. See Note 4 for additional information regarding the Merger. In August 2016, the FASB issued ASU 2016-15, Statement of Cash Flows-Classification of Certain Cash Receipts and Cash Payments . The objective of this update is to address eight specific cash flow issues in order to reduce the existing diversity in practice. ASU 2016-15 was effective for the annual periods beginning after December 15, 2017, and interim periods within those annual periods. The standard was adopted on January 1, 2018 and did not have a material impact on the Company's disclosures and financial statements. In February 2016, the FASB issued ASU 2016-02, Leases . The objective of this update is to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. ASU 2016-02 is effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods. The Company has performed an initial assessment by compiling and analyzing contracts and leasing arrangements that may be affected. The Company is still evaluating the impact of adopting this standard. In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers. The objective of this update is to clarify the principles for recognizing revenue and to develop a common revenue standard. The FASB subsequently issued ASU 2015-14, ASU 2016-08, ASU 2016-10, ASU 2016-12 and ASU 2016-20, which provided additional implementation guidance and deferred the effective date of ASU 2014-09. The standard was effective for annual reporting periods beginning after December 15, 2017, and interim periods within those annual periods. The standard was adopted on January 1, 2018 using the modified retrospective transition method, which was applied to contracts in place at the date of adoption. The adoption required the Company to net some additional gathering, transportation and processing expenses against its oil, gas and NGL production revenues. However, the cash flow and timing of the Company's revenue was not impacted and there was therefore no impact on the Company's net income (loss) or net income (loss) per common share. The standard also required additional footnote disclosures. See the " Revenue Recognition" section above for additional disclosures.

Summary of Significant Accoun22

Summary of Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2018
Accounting Policies [Abstract]
Summary of Accounts Receivable	Accounts receivable is comprised of the following: As of June 30, 2018 As of December 31, 2017 (in thousands) Oil, gas and NGL sales $ 41,998 $ 36,569 Due from joint interest owners 21,381 14,779 Other 65 270 Allowance for doubtful accounts (1 ) (203 ) Total accounts receivable $ 63,443 $ 51,415
Net Capitalized Costs and Associated Accumulated DD&A and Non Cash Impairments	The following table sets forth the net capitalized costs and associated accumulated DD&A and non-cash impairments relating to the Company's oil, natural gas and NGL producing activities: As of June 30, 2018 As of December 31, 2017 (in thousands) Proved properties $ 348,607 $ 230,800 Wells and related equipment and facilities 1,264,134 1,088,692 Support equipment and facilities 52,976 38,776 Materials and supplies 10,351 2,900 Total proved oil and gas properties (1) $ 1,676,068 $ 1,361,168 Unproved properties (1) 620,403 18,832 Wells and facilities in progress 112,072 65,844 Total unproved oil and gas properties, excluded from amortization $ 732,475 $ 84,676 Accumulated depreciation, depletion, amortization and impairment (510,029 ) (433,234 ) Total oil and gas properties, net $ 1,898,514 $ 1,012,610 (1) Includes properties acquired in the Merger of $105.7 million of proved oil and gas properties and $608.6 million of unproved properties. See Note 4 for additional information regarding the Merger.
Non-Cash Impairment Charges, Included within Impairment, Dry Hole Costs and Abandonment Expense in Consolidated Statements of Operations	The Company recognized non-cash impairment charges, which were included within impairment, dry hole costs and abandonment expense in the Unaudited Consolidated Statements of Operations, as follows: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (in thousands) Impairment of unproved oil and gas properties (1) $ — $ — $ — $ 8,010 Dry hole costs — — — 2 Abandonment expense and lease expirations 108 1 425 63 Total impairment, dry hole costs and abandonment expense $ 108 $ 1 $ 425 $ 8,075 (1) The Company recognized impairment related to unproved oil and gas properties in the Cottonwood Gulch area of the Piceance Basin during the six months ended June 30, 2017 . The Company had no current plan to develop this acreage.
Accounts Payable and Accrued Liabilities	Accounts payable and other accrued liabilities are comprised of the following: As of June 30, 2018 As of December 31, 2017 (in thousands) Accrued drilling, completion and facility costs $ 77,133 $ 35,856 Accrued lease operating, gathering, transportation and processing expenses 6,275 4,360 Accrued general and administrative expenses 8,744 11,134 Accrued interest payable 6,482 6,484 Accrued merger transaction expenses 503 8,278 Accrued hedge settlements 4,996 65 Prepayments from partners 1,069 2,524 Trade payables 4,098 10,067 Other 4,338 5,287 Total accounts payable and other accrued liabilities $ 113,638 $ 84,055
Calculation of Basic and Diluted Earnings (Loss) Per Share	The following table sets forth the calculation of basic and diluted income (loss) per share: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (in thousands, except per share amounts) Net income (loss) $ (46,906 ) $ (18,447 ) $ (71,843 ) $ (31,562 ) Basic weighted-average common shares outstanding in period 209,393 74,794 166,731 74,670 Diluted weighted-average common shares outstanding in period 209,393 74,794 166,731 74,670 Basic net income (loss) per common share $ (0.22 ) $ (0.25 ) $ (0.43 ) $ (0.42 ) Diluted net income (loss) per common share $ (0.22 ) $ (0.25 ) $ (0.43 ) $ (0.42 )

Supplemental Disclosures of C23

Supplemental Disclosures of Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2018
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental cash flow information is as follows: Six Months Ended June 30, 2018 2017 (in thousands) Cash paid for interest $ 25,058 $ 30,976 Cash paid for income taxes — — Supplemental disclosures of non-cash investing and financing activities: Accrued liabilities - oil and gas properties 79,792 37,175 Change in asset retirement obligations, net of disposals 7,887 10,545 Retirement of treasury stock (1,490 ) (1,230 ) Properties exchanged in non-cash transactions — 11,790 Issuance of common stock for Merger 484,000 —

Mergers (Tables)

Mergers (Tables)	6 Months Ended
	Jun. 30, 2018
Business Combinations [Abstract]
Summary of Purchase Price Allocation	The following table sets forth our preliminary purchase price allocation: March 19, 2018 (in thousands) Purchase Price: Fair value of common stock issued $ 484,000 Plus: Repayment of Fifth Creek debt 53,900 Total purchase price 537,900 Plus Liabilities Assumed: Accounts payable and accrued liabilities 25,382 Current unfavorable contract 2,651 Other current liabilities 13,797 Asset retirement obligations 7,361 Long-term deferred tax liability 137,111 Long-term unfavorable contract 4,449 Other noncurrent liabilities 2,354 Total purchase price plus liabilities assumed $ 731,005 Fair Value of Assets Acquired: Cash 543 Accounts receivable 7,831 Oil and Gas Properties: Proved oil and gas properties 105,702 Unproved oil and gas properties 608,572 Asset Retirement Obligations 7,361 Furniture, equipment and other 931 Other noncurrent assets 65 Total asset value $ 731,005
Summary of Pro Forma Financial Information	The pro forma condensed combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the acquisition taken place on January 1, 2017; furthermore, the financial information is not intended to be a projection of future results. Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (in thousands, except per share data) Revenues $ 110,398 $ 60,065 $ 207,140 $ 114,754 Net Income (Loss) and Comprehensive Income (Loss) (45,629 ) (19,180 ) (69,733 ) (31,879 ) Net Income (Loss) per Common Share, Basic and Diluted (0.22 ) (0.11 ) (0.33 ) (0.18 )

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2018
Debt Disclosure [Abstract]
Outstanding Debt	The Company's outstanding debt is summarized below: As of June 30, 2018 As of December 31, 2017 Maturity Date Principal Debt Issuance Costs Carrying Amount Principal Debt Issuance Costs Carrying Amount (in thousands) Amended Credit Facility April 8, 2020 $ — $ — $ — $ — $ — $ — 7.0% Senior Notes (1) October 15, 2022 350,000 (3,628 ) 346,372 350,000 (4,033 ) 345,967 8.75% Senior Notes (2) June 15, 2025 275,000 (4,747 ) 270,253 275,000 (5,080 ) 269,920 Lease Financing Obligation (3) August 10, 2020 2,096 — 2,096 2,328 (2 ) 2,326 Total Debt $ 627,096 $ (8,375 ) $ 618,721 $ 627,328 $ (9,115 ) $ 618,213 Less: Current Portion of Long-Term Debt (4) 2,096 — 2,096 469 — 469 Total Long-Term Debt $ 625,000 $ (8,375 ) $ 616,625 $ 626,859 $ (9,115 ) $ 617,744 (1) The aggregate estimated fair value of the 7.0% Senior Notes was approximately $353.5 million and $356.1 million as of June 30, 2018 and December 31, 2017 , respectively, based on reported market trades of these instruments. (2) The aggregate estimated fair value of the 8.75% Senior Notes was approximately $294.3 million and $305.3 million as of June 30, 2018 and December 31, 2017 , respectively, based on reported market trades of these instruments. (3) The aggregate estimated fair value of the Lease Financing Obligation was approximately $1.9 million and $2.1 million as of June 30, 2018 and December 31, 2017 , respectively. As there is no active, public market for the Lease Financing Obligation, the aggregate estimated fair value was based on market-based parameters of comparable term secured financing instruments. (4) The current portion of long-term debt includes the current portion of the Lease Financing Obligation. The Company has elected to exercise the early buyout option pursuant to which the Company will purchase the equipment for $1.8 million on February 10, 2019.

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2018
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Asset Retirement Obligations	A reconciliation of the Company's asset retirement obligations for the six months ended June 30, 2018 is as follows (in thousands): As of December 31, 2017 $ 17,586 Liabilities incurred (1) 8,454 Liabilities settled (727 ) Disposition of properties (66 ) Accretion expense 574 Revisions to estimate 226 As of June 30, 2018 $ 26,047 Less: Current asset retirement obligations 1,281 Long-term asset retirement obligations $ 24,766 (1) Includes $7.4 million associated with properties acquired in the Merger during the six months ended June 30, 2018 . See Note 4 for additional information regarding this Merger.

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value Measurements, Nonrecurring	Information about impaired assets is as follows: Level 1 Level 2 Level 3 Net Book (1) Impairment (in thousands) As of June 30, 2018 Proved and unproved properties $ — $ — $ — $ — $ — As of December 31, 2017 Uinta Basin oil and gas properties (2) — — 106,587 144,532 37,945 DJ Basin unproved properties (3) — — 18,832 20,887 2,055 Piceance Basin unproved properties (4) — — — 9,098 9,098 (1) Amount represents net book value at the date of assessment. (2) The Company recognized a non-cash impairment charge associated with the Company's Uinta Oil Program proved properties during the year ended December 31, 2017. The properties were sold on December 29, 2017. (3) As a result of having no future plans to develop certain acreage and/or estimated market values below carrying value, the Company recognized non-cash impairment charges of $2.1 million associated with certain non-core unproved properties in the DJ Basin during the year ended December 31, 2017 . (4) As a result of having no future plans to develop certain acreage and/or estimated market values below carrying value, the Company recognized non-cash impairment charges of $9.1 million associated with certain unproved properties in the Cottonwood Gulch area of the Piceance Basin during the year ended December 31, 2017 .
Fair Value, Balance Sheet Grouping	The following tables set forth by level within the fair value hierarchy the Company's non-financial assets and liabilities that were measured at fair value on a recurring basis in the Unaudited Consolidated Balance Sheets. Level 1 Level 2 Level 3 Total (in thousands) As of June 30, 2018 Financial Assets Cash equivalents $ 74,842 $ — $ — $ 74,842 Deferred compensation plan 1,412 — — 1,412 Commodity derivatives — 766 — 766 Financial Liabilities Commodity derivatives — 86,019 — 86,019 As of December 31, 2017 Financial Assets Cash equivalents 271,027 — — 271,027 Deferred compensation plan 1,749 — — 1,749 Commodity derivatives — 656 — 656 Financial Liabilities Commodity derivatives — 25,714 — 25,714

Derivative Instruments (Tables)

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Fair Value Amounts of Derivative Instruments	The following table summarizes the location, as well as the gross and net fair value amounts, of all derivative instruments presented on the Unaudited Consolidated Balance Sheets as of the dates indicated. As of June 30, 2018 Balance Sheet Gross Amounts of Gross Amounts Net Amounts of (in thousands) Derivative assets $ 433 $ (433 ) (1) $ — Deferred financing costs and other noncurrent assets 333 (333 ) (1) — Total derivative assets $ 766 $ (766 ) $ — Gross Amounts of Gross Amounts Net Amounts of (in thousands) Derivative liabilities $ (66,839 ) $ 433 (1) $ (66,406 ) Derivatives and other noncurrent liabilities (19,180 ) 333 (1) (18,847 ) Total derivative liabilities $ (86,019 ) $ 766 $ (85,253 ) As of December 31, 2017 Balance Sheet Gross Amounts of Gross Amounts Net Amounts of (in thousands) Derivative assets $ 594 $ (594 ) (1) $ — Deferred financing costs and other noncurrent assets 62 (62 ) (1) — Total derivative assets $ 656 $ (656 ) $ — Gross Amounts of Gross Amounts Net Amounts of (in thousands) Derivative liabilities $ (21,534 ) $ 594 (1) $ (20,940 ) Derivatives and other noncurrent liabilities (4,180 ) 62 (1) (4,118 ) Total derivative liabilities $ (25,714 ) $ 656 $ (25,058 ) (1) Asset and liability balances with the same counterparty are presented as a net asset or liability on the Unaudited Consolidated Balance Sheets.
Financial Instruments for Hedging Volumes	As of June 30, 2018 , the Company had financial instruments in place to hedge the following volumes for the periods indicated: July – December 2018 For the year 2019 For the year 2020 Derivative Weighted Average Price Derivative Volumes Weighted Average Price Derivative Volumes Weighted Average Price Oil (Bbls) 2,543,651 $ 54.63 6,017,934 $ 58.09 549,000 $ 57.25 Natural Gas (MMbtu) 920,000 $ 2.68 912,500 $ 2.05 — $ —

Income Taxes (Tables)

Income Taxes (Tables)	6 Months Ended
	Jun. 30, 2018
Income Tax Disclosure [Abstract]
Components of Deferred Tax Assets and Deferred Tax Liabilities	The tax effects of temporary differences that give rise to significant components of the deferred tax assets and deferred tax liabilities as of June 30, 2018 and December 31, 2017 are presented below: As of June 30, 2018 As of December 31, 2017 (in thousands) Deferred tax assets: Net operating loss carryforward $ 117,540 $ 170,536 Stock-based compensation 3,105 3,826 Deferred rent — 163 Deferred compensation 872 1,824 State tax credit carryforwards — 6,499 Financing obligation 649 705 Accrued expenses 593 248 Investment in partnership 1,255 — Derivative instruments 21,003 6,158 Other assets 2,203 228 Less: Valuation allowance (62,988 ) (114,530 ) Total deferred tax assets 84,232 75,657 Deferred tax liabilities: Oil and gas properties (221,129 ) (75,409 ) Prepaid expenses (214 ) (248 ) Total deferred tax assets (liabilities) (221,343 ) (75,657 ) Net deferred tax assets (liabilities) $ (137,111 ) $ —

Equity Incentive Compensation30

Equity Incentive Compensation Plans and Other Long-term Incentive Programs (Tables)	6 Months Ended
	Jun. 30, 2018
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-Cash Stock-Based Compensation Cost Related to Equity Awards	The following table presents the long-term equity and cash incentive compensation related to awards for the periods indicated: Three Months Ended June 30, Six Months Ended June 30, 2018 2017 2018 2017 (in thousands) Nonvested common stock (1) $ 1,520 $ 1,553 $ 2,850 $ 3,003 Nonvested common stock units (1) 277 172 447 342 Nonvested performance-based shares (1) — 89 — 558 Nonvested performance cash units (2)(3) 451 (139 ) 378 (1,100 ) Total $ 2,248 $ 1,675 $ 3,675 $ 2,803 (1) Unrecognized compensation expense as of June 30, 2018 was $11.2 million , which related to grants of nonvested shares of common stock that are expected to be recognized over a weighted-average period of 2.0 years . (2) The nonvested performance-based cash units are accounted for as liability awards with $1.4 million in accounts payable and accrued liabilities as of December 31, 2017 and $0.6 million and $3.0 million in derivatives and other noncurrent liabilities as of June 30, 2018 and December 31, 2017 , respectively, in the Unaudited Consolidated Balance Sheets. (3) Liability awards are fair valued at each reporting date. For the three months ended June 30, 2018 , the weighted average fair value share price increased from $5.08 as of March 31, 2018 to $6.08 as of June 30, 2018 . For the three months ended June 30, 2017 , the weighted average fair value share price decreased from $4.55 as of March 31, 2017 to $3.41 as of June 30, 2017 . For the six months ended June 30, 2018 , the weighted average fair value share price increased from $5.10 as of December 31, 2017 to $6.08 as of June 30, 2018 and included the 2016 and 2017 Program conversion as an offset. See "2016 Program" and "2017 Program" below for additional information regarding the conversion. For the six months ended June 30, 2017 , the weighted average fair value share price decreased from $8.89 as of December 31, 2016 to $3.41 as of June 30, 2017 .
Nonvested Equity Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Schedule of Nonvested Share Activity	A summary of the Company's nonvested common stock awards for the three and six months ended June 30, 2018 and 2017 is presented below: Three Months Ended June 30, 2018 Three Months Ended June 30, 2017 Nonvested Common Stock Awards Shares Weighted Average Shares Weighted Average Outstanding at April 1, 2,657,535 $ 5.14 1,441,939 $ 7.25 Granted 221,025 7.08 28,017 3.62 Vested (15,724 ) 5.45 (26,289 ) 11.12 Forfeited or expired (4,558 ) 7.38 (43,407 ) 7.48 Outstanding at June 30, 2,858,278 5.28 1,400,260 7.10 Six Months Ended June 30, 2018 Six Months Ended June 30, 2017 Nonvested Common Stock Awards Shares Weighted Average Shares Weighted Average Outstanding at January 1, 1,394,868 $ 7.00 1,169,099 $ 9.33 Granted 1,017,448 5.45 777,244 6.01 Modified (1) 1,146,305 4.84 — — Vested (667,932 ) 8.28 (494,892 ) 10.58 Forfeited or expired (32,411 ) 6.73 (51,191 ) 7.79 Outstanding at June 30, 2,858,278 5.28 1,400,260 7.10 (1) Due to the closing of the Merger, the 2016 and 2017 Performance Cash Programs were converted from nonvested performance-based cash units to nonvested common stock awards, resulting in an increase of nonvested common stock awards for the six months ended June 30, 2018 .
Nonvested Performance Cash Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Schedule of Nonvested Performance-based Units Activity	A summary of the Company's nonvested performance-based cash unit awards for the three and six months ended June 30, 2018 and 2017 is presented below: Three Months Ended June 30, 2018 Three Months Ended June 30, 2017 Nonvested Performance-Based Cash Unit Awards Units Weighted Average Units Weighted Average Outstanding at April 1, 796,423 1,567,400 Granted 49,833 25,017 Forfeited or expired — (55,219 ) Outstanding at June 30, 846,256 $ 6.08 1,537,198 $ 3.07 Six Months Ended June 30, 2018 Six Months Ended June 30, 2017 Nonvested Performance-Based Cash Unit Awards Units Weighted Average Units Weighted Average Outstanding at January 1, 1,548,083 942,326 Granted 846,256 658,158 Performance goal adjustment (1) 11,289 — Modified (2) (1,211,478 ) — Vested (286,652 ) — Forfeited or expired (61,242 ) (63,286 ) Outstanding at June 30, 846,256 $ 6.08 1,537,198 $ 3.07 (1) The 2015 Program vested at 104.1% in excess of target level and resulted in additional units vested in March 2018. These units are included in the vested line item for the six months ended June 30, 2018 . (2) Due to the closing of the Merger, the 2016 and 2017 Performance Cash Programs were converted from nonvested performance-based cash units to nonvested common stock awards, resulting in a decrease in nonvested performance-based cash units for the six months ended June 30, 2018 . The 2016 Program converted based on its performance through March 19, 2018, which resulted in 89% of the units converting to nonvested common stock awards or a reduction of 65,173 units converting to nonvested common stock awards.
Director [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Schedule of Nonvested Share Activity	A summary of the Company's nonvested common stock unit awards for the three and six months ended June 30, 2018 and 2017 is presented below: Three Months Ended June 30, 2018 Three Months Ended June 30, 2017 Nonvested Common Stock Unit Awards Units Weighted Average Units Weighted Average Outstanding at April 1, 272,559 $ 6.37 147,167 $ 10.09 Granted 158,885 6.87 183,353 3.50 Vested (129,027 ) 4.62 (57,961 ) 6.75 Outstanding at June 30, 302,417 7.37 272,559 6.37 Six Months Ended June 30, 2018 Six Months Ended June 30, 2017 Nonvested Common Stock Unit Awards Units Weighted Average Units Weighted Average Outstanding at January 1, 272,559 $ 6.37 147,167 $ 10.09 Granted 162,083 6.83 186,924 3.52 Vested (132,225 ) 4.63 (61,532 ) 6.62 Outstanding at June 30, 302,417 7.37 272,559 6.37

Commitments and Contingencies (

Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 2018
Commitments and Contingencies Disclosure [Abstract]
Schedule Of Gross Future Minimum Volume Charges [Table Text Block]	The amounts in the table below represent the Company's future minimum volume charges: As of June 30, 2018 (in thousands) 2018 $ 1,308 2019 2,365 2020 2,167 2021 1,996 Thereafter — Total $ 7,836
Schedule of Aggregate Undiscounted Minimum Future Lease Payments	The Company has a Lease Financing Obligation with Bank of America Leasing & Capital, LLC as the lead bank as discussed in Note 5 . The aggregate undiscounted minimum future lease payments, including both principal and interest components, are presented below. The Company has elected to exercise the early buyout option pursuant to which the Company will purchase the equipment for $1.8 million on February 10, 2019. As of June 30, 2018 (in thousands) 2018 $ 269 2019 1,869 Thereafter — Total $ 2,138
Gross Future Minimum Transportation Demand and Firm Processing Charges	The amounts in the table below represent the Company's future minimum transportation charges: As of June 30, 2018 (in thousands) 2018 $ 9,211 2019 18,691 2020 18,691 2021 10,904 Thereafter — Total $ 57,497
Future Minimum Annual Payments Under Drilling, Lease and Other Agreements	Future minimum annual payments under lease and other agreements are as follows: As of June 30, 2018 (in thousands) 2018 $ 5,132 2019 2,793 2020 2,405 2021 2,734 2022 2,764 Thereafter 13,087 Total $ 28,915

Guarantor Subsidiaries (Tables)

Guarantor Subsidiaries (Tables)	6 Months Ended
	Jun. 30, 2018
Condensed Financial Information Disclosure [Abstract]
Schedule of Condensed Consolidating Balance Sheets	Condensed Consolidating Balance Sheets As of June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Assets: Cash and cash equivalents $ — $ 107,379 $ — $ — $ 107,379 Accounts receivable, net of allowance for doubtful accounts — 63,443 — — 63,443 Other current assets — 2,697 — — 2,697 Property and equipment, net — 1,903,726 1,894 — 1,905,620 Intercompany receivable — 854 — (854 ) — Investment in subsidiaries 1,015,203 1,040 — (1,016,243 ) — Noncurrent assets — 3,814 — — 3,814 Total assets $ 1,015,203 $ 2,082,953 $ 1,894 $ (1,017,097 ) $ 2,082,953 Liabilities and Stockholders' Equity: Accounts payable and other accrued liabilities $ — $ 113,638 $ — $ — $ 113,638 Other current liabilities — 150,609 — — 150,609 Intercompany payable — — 854 (854 ) — Long-term debt — 616,625 — — 616,625 Deferred income taxes — 137,111 — — 137,111 Other noncurrent liabilities — 49,767 — — 49,767 Stockholders' equity 1,015,203 1,015,203 1,040 (1,016,243 ) 1,015,203 Total liabilities and stockholders' equity $ 1,015,203 $ 2,082,953 $ 1,894 $ (1,017,097 ) $ 2,082,953 As of December 31, 2017 Parent Subsidiary Intercompany Consolidated (in thousands) Assets: Cash and cash equivalents $ 314,466 $ — $ — $ 314,466 Accounts receivable, net of allowance for doubtful accounts 51,415 — — 51,415 Other current assets 1,782 — — 1,782 Property and equipment, net 1,016,986 1,894 — 1,018,880 Intercompany receivable 854 — (854 ) — Investment in subsidiaries 1,040 — (1,040 ) — Noncurrent assets 4,163 — — 4,163 Total assets $ 1,390,706 $ 1,894 $ (1,894 ) $ 1,390,706 Liabilities and Stockholders' Equity: Accounts payable and other accrued liabilities $ 84,055 $ — $ — $ 84,055 Other current liabilities 64,879 — — 64,879 Intercompany payable — 854 (854 ) — Long-term debt 617,744 — — 617,744 Other noncurrent liabilities 25,474 — — 25,474 Stockholders' equity 598,554 1,040 (1,040 ) 598,554 Total liabilities and stockholders' equity $ 1,390,706 $ 1,894 $ (1,894 ) $ 1,390,706
Schedule of Condensed Consolidating Statements of Operations	Condensed Consolidating Statements of Operations Three Months Ended June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Operating and other revenues $ — $ 110,398 $ — $ — $ 110,398 Operating expenses — (75,725 ) — — (75,725 ) General and administrative — (11,624 ) — — (11,624 ) Merger transaction expense — (1,277 ) — — (1,277 ) Interest expense — (13,093 ) — — (13,093 ) Interest income and other income (expense) — (55,585 ) — — (55,585 ) Income (loss) before income taxes and equity in earnings (loss) of subsidiaries — (46,906 ) — — (46,906 ) (Provision for) benefit from income taxes — — — — — Equity in earnings (loss) of subsidiaries (46,906 ) — — 46,906 — Net income (loss) $ (46,906 ) $ (46,906 ) $ — $ 46,906 $ (46,906 ) Six Months Ended June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Operating and other revenues $ — $ 191,208 $ — $ — $ 191,208 Operating expenses — (133,870 ) — — (133,870 ) General and administrative — (21,731 ) — — (21,731 ) Merger transaction expense — (6,040 ) — — (6,040 ) Interest expense — (26,183 ) — — (26,183 ) Interest income and other income (expense) — (75,227 ) — — (75,227 ) Income (loss) before income taxes and equity in earnings (loss) of subsidiaries — (71,843 ) — — (71,843 ) (Provision for) benefit from income taxes — — — — — Equity in earnings (loss) of subsidiaries (71,843 ) — — 71,843 — Net income (loss) $ (71,843 ) $ (71,843 ) $ — $ 71,843 $ (71,843 ) Three Months Ended June 30, 2017 Parent Subsidiary Intercompany Consolidated (in thousands) Operating and other revenues $ 50,919 $ 147 $ — $ 51,066 Operating expenses (52,452 ) (167 ) — (52,619 ) General and administrative (8,943 ) — — (8,943 ) Interest expense (16,137 ) — — (16,137 ) Interest income and other income (expense) 8,186 — — 8,186 Income (loss) before income taxes and equity in earnings (loss) of subsidiaries (18,427 ) (20 ) — (18,447 ) (Provision for) benefit from income taxes — — — — Equity in earnings (loss) of subsidiaries (20 ) — 20 — Net income (loss) $ (18,447 ) $ (20 ) $ 20 $ (18,447 ) Six Months Ended June 30, 2017 Parent Subsidiary Intercompany Eliminations Consolidated (in thousands) Operating and other revenues $ 101,344 $ 258 $ — $ 101,602 Operating expenses (109,310 ) (330 ) — (109,640 ) General and administrative (18,292 ) — — (18,292 ) Interest expense (30,088 ) — — (30,088 ) Interest income and other income (expense) 24,856 — — 24,856 Income (loss) before income taxes and equity in earnings (loss) of subsidiaries (31,490 ) (72 ) — (31,562 ) (Provision for) benefit from income taxes — — — — Equity in earnings (loss) of subsidiaries (72 ) — 72 — Net income (loss) $ (31,562 ) $ (72 ) $ 72 $ (31,562 )
Schedule of Condensed Consolidating Statements of Comprehensive Income (Loss)	Condensed Consolidating Statements of Comprehensive Income (Loss) Three Months Ended June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Net income (loss) $ (46,906 ) $ (46,906 ) $ — $ 46,906 $ (46,906 ) Other comprehensive loss — — — — — Comprehensive income (loss) $ (46,906 ) $ (46,906 ) $ — $ 46,906 $ (46,906 ) Six Months Ended June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Net income (loss) $ (71,843 ) $ (71,843 ) $ — $ 71,843 $ (71,843 ) Other comprehensive loss — — — — — Comprehensive income (loss) $ (71,843 ) $ (71,843 ) $ — $ 71,843 $ (71,843 ) Three Months Ended June 30, 2017 Parent Subsidiary Intercompany Eliminations Consolidated (in thousands) Net income (loss) $ (18,447 ) $ (20 ) $ 20 $ (18,447 ) Other comprehensive loss — — — — Comprehensive income (loss) $ (18,447 ) $ (20 ) $ 20 $ (18,447 ) Six Months Ended June 30, 2017 Parent Subsidiary Intercompany Consolidated (in thousands) Net income (loss) $ (31,562 ) $ (72 ) $ 72 $ (31,562 ) Other comprehensive loss — — — — Comprehensive income (loss) $ (31,562 ) $ (72 ) $ 72 $ (31,562 )
Schedule of Condensed Consolidating Statements of Cash Flows	Condensed Consolidating Statements of Cash Flows Six Months Ended June 30, 2018 Parent Subsidiary Subsidiary Intercompany Consolidated (in thousands) Cash flows from operating activities $ — $ 68,887 $ — $ — $ 68,887 Cash flows from investing activities: Additions to oil and gas properties, including acquisitions — (220,816 ) — — (220,816 ) Additions to furniture, fixtures and other — (470 ) — — (470 ) Repayment of debt associated with merger, net of cash acquired — (53,357 ) — — (53,357 ) Proceeds from sale of properties and other investing activities — 530 — — 530 Intercompany transfers — — — — — Cash flows from financing activities: Principal payments on debt — (232 ) — — (232 ) Intercompany transfers — — — — — Other financing activities — (1,629 ) — — (1,629 ) Change in cash and cash equivalents — (207,087 ) — — (207,087 ) Beginning cash and cash equivalents — 314,466 — — 314,466 Ending cash and cash equivalents $ — $ 107,379 $ — $ — $ 107,379 Six Months Ended June 30, 2017 Parent Subsidiary Intercompany Consolidated (in thousands) Cash flows from operating activities $ 37,975 $ 224 $ — $ 38,199 Cash flows from investing activities: Additions to oil and gas properties, including acquisitions (104,236 ) — — (104,236 ) Additions to furniture, fixtures and other (201 ) — — (201 ) Proceeds from sale of properties and other investing activities (615 ) — — (615 ) Intercompany transfers 224 — (224 ) — Cash flows from financing activities: Proceeds from debt 275,000 — — 275,000 Principal payments on debt (322,113 ) — — (322,113 ) Proceeds from sale of common stock, net of offering costs (298 ) — — (298 ) Intercompany transfers — (224 ) 224 — Other financing activities (6,012 ) — — (6,012 ) Change in cash and cash equivalents (120,276 ) — — (120,276 ) Beginning cash and cash equivalents 275,841 — — 275,841 Ending cash and cash equivalents $ 155,565 $ — $ — $ 155,565

Summary of Significant Accoun33

Summary of Significant Accounting Policies - Summary of Accounts Receivable (Detail) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Accounts, Notes, Loans and Financing Receivable [Line Items]
Allowance for doubtful accounts	$ (1)	$ (203)
Accounts receivable	63,443	51,415
Accrued Oil, Gas, and NGL Sales
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable gross	41,998	36,569
Due from Joint Interest Owners
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable gross	21,381	14,779
Other
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable gross	$ 65	$ 270

Summary of Significant Accoun34

Summary of Significant Accounting Policies - Net Capitalized Costs and Associated Accumulated Depreciation, Depletion & Amortization and Non Cash Impairments (Detail) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Business Acquisition [Line Items]
Proved properties	$ 348,607	$ 230,800
Wells and related equipment and facilities	1,264,134	1,088,692
Support equipment and facilities	52,976	38,776
Materials and supplies	10,351	2,900
Total proved oil and gas properties (1)	1,676,068	1,361,168
Unproved properties (1)	620,403	18,832
Wells and facilities in progress	112,072	65,844
Total unproved oil and gas properties, excluded from amortization	732,475	84,676
Accumulated depreciation, depletion, amortization and impairment	(510,029)	(433,234)
Total oil and gas properties, net	1,898,514	$ 1,012,610
Fifth Creek [Member]
Business Acquisition [Line Items]
Total proved oil and gas properties (1)	105,700
Unproved properties (1)	$ 608,600

Summary of Significant Accoun35

Summary of Significant Accounting Policies - Non-Cash Impairment Charges, Included within Impairment, Dry Hole Costs and Abandonment Expense in Consolidated Statements of Operations (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Summary Of Significant Accounting Policies [Line Items]
Impairment of Oil and Gas Properties			$ 0
Dry hole costs	$ 0	$ 0	0	$ 2
Abandonment expense and lease expirations	108	1	425	63
Impairment, dry hole costs and abandonment expense	108	1	425	8,075
Unproved Oil And Gas Properties
Summary Of Significant Accounting Policies [Line Items]
Impairment of Oil and Gas Properties	$ 0	$ 0	$ 0	$ 8,010

Summary of Significant Accoun36

Summary of Significant Accounting Policies - Accounts Payable and Accrued Liabilities (Detail) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Accounting Policies [Abstract]
Accrued drilling, completion and facility costs	$ 77,133	$ 35,856
Accrued lease operating, gathering, transportation and processing expenses	6,275	4,360
Accrued general and administrative expenses	8,744	11,134
Accrued interest payable	6,482	6,484
Accrued merger transaction expenses	503	8,278
Accrued hedge settlements	4,996	65
Prepayments from partners	1,069	2,524
Trade payables	4,098	10,067
Other	4,338	5,287
Total accounts payable and other accrued liabilities	$ 113,638	$ 84,055

Summary of Significant Accoun37

Summary of Significant Accounting Policies - Revenue Recognition (Details)	6 Months Ended
	Jun. 30, 2018
Revenue from External Customer [Line Items]
Contract payment term	1 month
Minimum
Revenue from External Customer [Line Items]
Revenue contract term	1 month
Maximum
Revenue from External Customer [Line Items]
Revenue contract term	20 years

Summary of Significant Accoun38

Summary of Significant Accounting Policies - Calculation of Basic and Diluted Earnings (Loss) Per Share (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Accounting Policies [Abstract]
Net Income (Loss)	$ (46,906)	$ (18,447)	$ (71,843)	$ (31,562)	$ (138,225)
Basic weighted-average common shares outstanding in period (in shares)	209,393,002	74,794,448	166,731,287	74,669,806
Diluted weighted-average common shares outstanding in period (in shares)	209,393,002	74,794,448	166,731,287	74,669,806
Net Income (Loss) Per Common Share, Basic (in dollars per share)	$ (0.22)	$ (0.25)	$ (0.43)	$ (0.42)
Net Income (Loss) Per Common Share, Diluted (in dollars per share)	$ (0.22)	$ (0.25)	$ (0.43)	$ (0.42)

Supplemental Disclosures of C39

Supplemental Disclosures of Cash Flow Information - Supplemental Cash Flow Information (Detail) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Supplemental Cash Flow Information [Abstract]
Cash paid for interest	$ 25,058	$ 30,976
Cash paid for income taxes	0	0
Supplemental disclosures of non-cash investing and financing activities:
Accrued liabilities - oil and gas properties	79,792	37,175
Change in asset retirement obligations, net of disposals	7,887	10,545
Retirement of treasury stock	(1,490)	(1,230)
Properties exchanged in non-cash transactions	0	11,790
Issuance of common stock for Merger	$ 484,000	$ 0

Mergers - Additional Informatio

Mergers - Additional Information (Detail) $ in Thousands	Mar. 19, 2018USD ($)awellshares	Jun. 30, 2018USD ($)MMBoe	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)MMBoe	Jun. 30, 2017USD ($)	Dec. 31, 2017USD ($)	Jun. 30, 2018USD ($)MMBoe
Business Acquisition [Line Items]
Merger transaction expense		$ 1,277	$ 0	$ 6,040	$ 0	$ 8,700	$ 14,700
Fifth Creek [Member]
Business Acquisition [Line Items]
Net acreage acquired | a	81,000
Productive standard-length wells acquired | well	62
Productive extended reach wells acquired | well	10
Additional net proved reserves | MMBoe		9.3		9.3			9.3
Additional net proved developed reserves | MMBoe		4.7		4.7			4.7
Additional net proved undeveloped reserves | MMBoe		4.6		4.6			4.6
Common shares issued to effect the merger (shares) | shares	100,000,000
Fair value of common stock issued	$ 484,000
Repayment of Fifth Creek debt	$ 53,900
Revenue generated from acquired assets since acquisition date		$ 12,300		$ 14,300
Expenses incurred from acquired assets since acquisition date		9,500		11,300
Merger-related costs adjustment
Business Acquisition [Line Items]
Merger transaction expense		1,300		6,000
Fifth Creek [Member] | Merger-related costs adjustment
Business Acquisition [Line Items]
Merger transaction expense		$ 0		$ 4,000

Mergers - Assets and Liabilitie

Mergers - Assets and Liabilities Acquired (Detail) - Fifth Creek [Member] $ in Thousands	Mar. 19, 2018USD ($)
Purchase Price:
Fair value of common stock issued	$ 484,000
Plus: Repayment of Fifth Creek debt	53,900
Total purchase price	537,900
Plus Liabilities Assumed:
Accounts payable and accrued liabilities	25,382
Current unfavorable contract	2,651
Other current liabilities	13,797
Asset retirement obligations	7,361
Long-term deferred tax liability	137,111
Long-term unfavorable contract	4,449
Other noncurrent liabilities	2,354
Total purchase price plus liabilities assumed	731,005
Fair Value of Assets Acquired:
Cash	543
Accounts receivable	7,831
Proved oil and gas properties	105,702
Unproved oil and gas properties	608,572
Asset Retirement Obligations	7,361
Furniture, equipment and other	931
Other noncurrent assets	65
Total asset value	$ 731,005

Mergers - Proforma Information

Mergers - Proforma Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended	18 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017	Jun. 30, 2018
Pro Forma Financial Information
Revenues	$ 110,398	$ 60,065	$ 207,140	$ 114,754
Net Income (Loss) and Comprehensive Income (Loss)	$ (45,629)	$ (19,180)	$ (69,733)	$ (31,879)
Net Income (Loss) per Common Share, Basic (in dollars per share)	$ (0.22)	$ (0.11)	$ (0.33)	$ (0.18)
Net Income (Loss) per Common Share, Diluted (in dollars per share)	$ (0.22)	$ (0.11)	$ (0.33)	$ (0.18)
Pro Forma Financial Information
Merger transaction expense	$ 1,277	$ 0	$ 6,040	$ 0	$ 8,700	$ 14,700
Merger-related costs adjustment
Pro Forma Financial Information
Merger transaction expense	1,300		6,000
Merger-related costs adjustment | Fifth Creek [Member]
Pro Forma Financial Information
Merger transaction expense	$ 0		$ 4,000

Long-Term Debt - Outstanding De

Long-Term Debt - Outstanding Debt (Detail) - USD ($)	6 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Debt Instrument [Line Items]
Principal amount of debt instrument	$ 625,000,000	$ 626,859,000
Unamortized Debt Issuance Expense	(8,375,000)	(9,115,000)
Carrying Amount	616,625,000	617,744,000
Debt, fair value	647,800,000	661,400,000
Amended Credit Facility
Debt Instrument [Line Items]
Principal amount of debt instrument	0	0
Unamortized Debt Issuance Expense	0	0
Carrying Amount	0	0
Debt, fair value	$ 0
7.0% Senior Notes
Debt Instrument [Line Items]
Maturity Date	Oct. 15, 2022
Principal amount of debt instrument	$ 350,000,000	350,000,000
Unamortized Debt Issuance Expense	(3,628,000)	(4,033,000)
Carrying Amount	$ 346,372,000	345,967,000
Debt, stated interest rate	7.00%
Debt, fair value	$ 353,500,000	356,100,000
8.75% Senior Notes
Debt Instrument [Line Items]
Maturity Date	Jun. 15, 2025
Principal amount of debt instrument	$ 275,000,000	275,000,000
Unamortized Debt Issuance Expense	(4,747,000)	(5,080,000)
Carrying Amount	$ 270,253,000	269,920,000
Debt, stated interest rate	8.75%
Debt, fair value	$ 294,300,000	305,300,000
Lease Financing Obligation
Debt Instrument [Line Items]
Maturity Date	Aug. 10, 2020
Principal amount of debt instrument	$ 2,096,000	2,328,000
Unamortized Debt Issuance Expense	0	(2,000)
Carrying Amount	2,096,000	2,326,000
Debt, fair value	1,900,000	2,100,000
Long-term Debt
Debt Instrument [Line Items]
Principal amount of debt instrument	627,096,000	627,328,000
Unamortized Debt Issuance Expense	(8,375,000)	(9,115,000)
Carrying Amount	618,721,000	618,213,000
Current Portion of Long-Term Debt
Debt Instrument [Line Items]
Principal amount of debt instrument	2,096,000	469,000
Unamortized Debt Issuance Expense	0	0
Carrying Amount	$ 2,096,000	$ 469,000

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2018USD ($)lender	Dec. 31, 2017USD ($)
Debt Instrument [Line Items]
Principal amount	$ 625,000,000	$ 626,859,000
Debt, fair value	647,800,000	661,400,000
Purchase of equipment	$ 1,800,000
Minimum
Debt Instrument [Line Items]
Revolving credit facility interest rate percent above LIBOR alternate interest rate	0.50%
Commitment fee percentage	0.375%
Revolving Credit Facility Interest Rate Percent Above Libor	1.50%
Maximum
Debt Instrument [Line Items]
Revolving credit facility interest rate percent above LIBOR alternate interest rate	1.50%
Commitment fee percentage	0.50%
Revolving Credit Facility Interest Rate Percent Above Libor	2.50%
Amended Credit Facility
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	$ 300,000,000
Number of Lenders, Credit Facility | lender	13
Letters of credit issued amount	$ 26,000,000
Line of credit facility, remaining borrowing capacity	274,000,000
Principal amount	0	0
Debt, fair value	$ 0
7.0% Senior Notes
Debt Instrument [Line Items]
Debt instrument, maturity date	Oct. 15, 2022
Principal amount	$ 350,000,000	350,000,000
Debt, stated interest rate	7.00%
Debt, fair value	$ 353,500,000	356,100,000
8.75% Senior Notes
Debt Instrument [Line Items]
Debt instrument, maturity date	Jun. 15, 2025
Principal amount	$ 275,000,000	275,000,000
Debt, stated interest rate	8.75%
Debt, fair value	$ 294,300,000	305,300,000
Lease Financing Obligation
Debt Instrument [Line Items]
Debt instrument, maturity date	Aug. 10, 2020
Principal amount	$ 2,096,000	2,328,000
Debt, fair value	$ 1,900,000	$ 2,100,000
Weighted average implicit rate based on interest expense	3.30%
2017 [Member] | 7.0% Senior Notes
Debt Instrument [Line Items]
Par value of senior notes	103.50%
2018 [Member] | 7.0% Senior Notes
Debt Instrument [Line Items]
Par value of senior notes	102.333%
2019 [Member] | 7.0% Senior Notes
Debt Instrument [Line Items]
Par value of senior notes	101.167%
2020 [Member] | 7.0% Senior Notes
Debt Instrument [Line Items]
Par value of senior notes	100.00%
2020 [Member] | 8.75% Senior Notes
Debt Instrument [Line Items]
Par value of senior notes	106.563%
2021 [Member] | 8.75% Senior Notes
Debt Instrument [Line Items]
Par value of senior notes	104.375%
2022 [Member] | 8.75% Senior Notes
Debt Instrument [Line Items]
Par value of senior notes	102.188%
2023 [Member] | 8.75% Senior Notes
Debt Instrument [Line Items]
Par value of senior notes	100.00%
Prior to June 15, 2020 [Member] | 8.75% Senior Notes
Debt Instrument [Line Items]
Par value of senior notes	100.00%
Debt Instrument, Redemption Price, Percentage of Principal Amount Redeemed	35.00%
Redemption Price As Percentage Of Principal Redeemed If Equity Offering Proceeds Used	108.75%

Asset Retirement Obligations -

Asset Retirement Obligations - Schedule of Asset Retirement Obligations (Detail) $ in Thousands	6 Months Ended
	Jun. 30, 2018USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
As of December 31, 2017	$ 17,586
Liabilities incurred	8,454
Liabilities settled	(727)
Disposition of properties	(66)
Accretion expense	574
Revisions to estimate	226
As of June 30, 2018	26,047
Less: Current asset retirement obligations	1,281
Long-term asset retirement obligations	$ 24,766

Fair Value Measurements - Fair

Fair Value Measurements - Fair Value, Balance Sheet Grouping (Detail) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017	Jun. 30, 2017	Dec. 31, 2016
Financial Assets
Cash equivalents	$ 107,379	$ 314,466	$ 155,565	$ 275,841
Commodity derivatives	0	0
Financial Liabilities
Commodity derivatives	85,253	25,058
Total
Financial Assets
Cash equivalents	74,842	271,027
Deferred compensation plan	1,412	1,749
Commodity derivatives	766	656
Financial Liabilities
Commodity derivatives	86,019	25,714
Level 1
Financial Assets
Cash equivalents	74,842	271,027
Deferred compensation plan	1,412	1,749
Commodity derivatives	0	0
Financial Liabilities
Commodity derivatives	0	0
Level 2
Financial Assets
Cash equivalents	0	0
Deferred compensation plan	0	0
Commodity derivatives	766	656
Financial Liabilities
Commodity derivatives	86,019	25,714
Level 3
Financial Assets
Cash equivalents	0	0
Deferred compensation plan	0	0
Commodity derivatives	0	0
Financial Liabilities
Commodity derivatives	$ 0	$ 0

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Detail) - USD ($)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Fair Value Measurements [Line Items]
Unproved Oil and Gas Property, Successful Effort Method	$ 732,475,000		$ 732,475,000		$ 84,676,000
Debt, fair value	$ 647,800,000		647,800,000		661,400,000
Impairment of Oil and Gas Properties			$ 0
7.0% Senior Notes
Fair Value Measurements [Line Items]
Debt, stated interest rate	7.00%		7.00%
Debt, fair value	$ 353,500,000		$ 353,500,000		356,100,000
8.75% Senior Notes
Fair Value Measurements [Line Items]
Debt, stated interest rate	8.75%		8.75%
Debt, fair value	$ 294,300,000		$ 294,300,000		305,300,000
Amended Credit Facility
Fair Value Measurements [Line Items]
Debt, fair value	0		0
Lease Financing Obligation
Fair Value Measurements [Line Items]
Debt, fair value	1,900,000		1,900,000		2,100,000
DJ Basin, non-core [Member]
Fair Value Measurements [Line Items]
Impairment of Oil and Gas Properties					2,100,000
Unproved Oil And Gas Properties
Fair Value Measurements [Line Items]
Impairment of Oil and Gas Properties	$ 0	$ 0	$ 0	$ 8,010,000
Piceance [Member]
Fair Value Measurements [Line Items]
Impairment of Oil and Gas Properties					$ 9,100,000

Fair Value Measurements Nonrecu

Fair Value Measurements Nonrecurring (Detail) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net Book Value Prior To Impairment	$ 0
Impairment of Oil and Gas Properties	0
Fair Value, Measurements, Nonrecurring [Member] | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net	0
Fair Value, Measurements, Nonrecurring [Member] | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net	0
Fair Value, Measurements, Nonrecurring [Member] | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net	$ 0
Uinta Basin [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net Book Value Prior To Impairment		$ 144,532
Impairment of Oil and Gas Properties		37,945
Uinta Basin [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net		0
Uinta Basin [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net		0
Uinta Basin [Member] | Fair Value, Measurements, Nonrecurring [Member] | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net		106,587
DJ Basin, Unproved [Domain]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net Book Value Prior To Impairment		20,887
Impairment of Oil and Gas Properties		2,055
DJ Basin, Unproved [Domain] | Fair Value, Measurements, Nonrecurring [Member] | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net		0
DJ Basin, Unproved [Domain] | Fair Value, Measurements, Nonrecurring [Member] | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net		0
DJ Basin, Unproved [Domain] | Fair Value, Measurements, Nonrecurring [Member] | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net		18,832
Piceance Basin, Unproved [Domain]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net Book Value Prior To Impairment		9,098
Impairment of Oil and Gas Properties		9,098
Piceance Basin, Unproved [Domain] | Fair Value, Measurements, Nonrecurring [Member] | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net		0
Piceance Basin, Unproved [Domain] | Fair Value, Measurements, Nonrecurring [Member] | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net		0
Piceance Basin, Unproved [Domain] | Fair Value, Measurements, Nonrecurring [Member] | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Oil and Gas Property, Successful Effort Method, Net		$ 0

Derivative Instruments - Fair V

Derivative Instruments - Fair Value Amounts of Derivative Instruments (Detail) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets	$ 766	$ 656
Gross Amounts Offset in the Balance Sheet	(766)	(656)
Net Amounts of Assets Presented in the Balance Sheet	0	0
Gross Amounts of Recognized Liabilities	(86,019)	(25,714)
Gross Amounts Offset in the Balance Sheet	766	656
Net Amounts of Liabilities Presented in the Balance Sheet	(85,253)	(25,058)
Derivative assets
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets	433	594
Gross Amounts Offset in the Balance Sheet	(433)	(594)
Net Amounts of Assets Presented in the Balance Sheet	0	0
Deferred financing costs and other noncurrent assets
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets	333	62
Gross Amounts Offset in the Balance Sheet	(333)	(62)
Net Amounts of Assets Presented in the Balance Sheet	0	0
Derivative liabilities
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Liabilities	(66,839)	(21,534)
Gross Amounts Offset in the Balance Sheet	433	594
Net Amounts of Liabilities Presented in the Balance Sheet	(66,406)	(20,940)
Derivatives and other noncurrent liabilities
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Liabilities	(19,180)	(4,180)
Gross Amounts Offset in the Balance Sheet	333	62
Net Amounts of Liabilities Presented in the Balance Sheet	$ (18,847)	$ (4,118)

Derivative Instruments - Financ

Derivative Instruments - Financial Instruments for Hedging Volume (Detail)	Jun. 30, 2018MMBTU$ / unitbbl
July – December 2018
Derivative Instruments, Gain (Loss) [Line Items]
Oil (Bbls) | bbl	2,543,651
Weighted Average Price, Hedge Backed Oil Volumes	54.63
Natural Gas (MMbtu) | MMBTU	920,000
Weighted Average Price, Hedge Backed Gas Volumes	2.68
For the year 2019
Derivative Instruments, Gain (Loss) [Line Items]
Oil (Bbls) | bbl	6,017,934
Weighted Average Price, Hedge Backed Oil Volumes	58.09
Natural Gas (MMbtu) | MMBTU	912,500
Weighted Average Price, Hedge Backed Gas Volumes	2.05
For the year 2020
Derivative Instruments, Gain (Loss) [Line Items]
Oil (Bbls) | bbl	549,000
Weighted Average Price, Hedge Backed Oil Volumes	57.25
Natural Gas (MMbtu) | MMBTU	0
Weighted Average Price, Hedge Backed Gas Volumes	0

Derivative Instruments - Additi

Derivative Instruments - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2018counterparty
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Number of counterparties for hedges at period end	7

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($) $ in Thousands	6 Months Ended	12 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Operating Loss Carryforwards [Line Items]
Operating Loss Carryforward, Annual limitation	$ 11,700
Valuation Allowance, Deferred Tax Asset, Increase (Decrease), Amount	64,500
Deferred income tax asset (liability)	137,111	$ 0
Operating Loss Carryforwards	476,600
Deferred Tax Assets, Operating Loss Carryforwards, State and Local	$ 476,900
U.S. federal income tax rate	21.00%	35.00%
Domestic Tax Authority [Member]
Operating Loss Carryforwards [Line Items]
Decrease in Operating Loss Carryforward	$ 274,600
State and Local Jurisdiction [Member]
Operating Loss Carryforwards [Line Items]
Decrease in Operating Loss Carryforward	10,000
Decrease in Tax Credit Carryforward	$ 8,200

Income Taxes - Components of De

Income Taxes - Components of Deferred Tax Assets and Deferred Tax Liabilities (Detail) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Components of Deferred Tax Assets and Liabilities [Abstract]
Net operating loss carryforward	$ 117,540	$ 170,536
Stock-based compensation	3,105	3,826
Deferred rent	0	163
Deferred compensation	872	1,824
State tax credit carryforwards	0	6,499
Financing obligation	649	705
Accrued expenses	593	248
Investment in partnership	1,255	0
Derivative instruments	21,003	6,158
Other assets	2,203	228
Less: Valuation allowance	(62,988)	(114,530)
Total deferred tax assets	84,232	75,657
Oil and gas properties	(221,129)	(75,409)
Prepaid expenses	(214)	(248)
Total deferred tax assets (liabilities)	(221,343)	(75,657)
Net deferred tax assets (liabilities)	$ (137,111)	$ 0

Stockholders' Equity (Detail)

Stockholders' Equity (Detail) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Mar. 31, 2018	Dec. 31, 2017	Mar. 31, 2017	Dec. 31, 2016
Class of Stock [Line Items]
Preferred Stock, Shares Authorized	75,000,000		75,000,000
Common Stock, Par or Stated Value Per Share (in dollars per share)	$ 0.001		$ 0.001			$ 0.001
Preferred Stock, Par or Stated Value Per Share (in dollars per share)	$ 0.001		$ 0.001
Common Stock, Shares Authorized	400,000,000		400,000,000			300,000,000
Preferred stock, shares issued (in shares)	0		0
Preferred stock, shares outstanding (in shares)	0		0
Common Stock, Shares, Issued	212,349,072		212,349,072			110,363,539
7.0% Senior Notes
Class of Stock [Line Items]
Debt, stated interest rate	7.00%		7.00%
Nonvested Equity Shares [Member]
Class of Stock [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number (in shares)	2,858,278	1,400,260	2,858,278	1,400,260	2,657,535	1,394,868	1,441,939	1,169,099
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value (in dollars per share)	$ 5.28	$ 7.10	$ 5.28	$ 7.10	$ 5.14	$ 7	$ 7.25	$ 9.33
Total shares granted (in shares)	221,025	28,017	1,017,448	777,244
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value (in dollars per share)	$ 7.08	$ 3.62	$ 5.45	$ 6.01
Share-based Compensation Arrangement by Share-based Payment Award, Shares Modified in Period			1,146,305	0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Modified Shares in Period, Weighted Average Grant Date Fair Value (in dollars per share)			$ 4.84	$ 0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares)	(15,724)	(26,289)	(667,932)	(494,892)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value (in dollars per share)	$ 5.45	$ 11.12	$ 8.28	$ 10.58
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period (in shares)	(4,558)	(43,407)	(32,411)	(51,191)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value (in dollars per share)	$ 7.38	$ 7.48	$ 6.73	$ 7.79
Merger [Member]
Class of Stock [Line Items]
Common Stock, Shares, Issued	100,000,000		100,000,000

Equity Incentive Compensation55

Equity Incentive Compensation Plans and Other Long-term Incentive Programs - Non-Cash Stock-Based Compensation Cost Related to Equity Awards (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Stock Based Compensation [Line Items]
Non-cash stock-based compensation equity awards	$ 2,248	$ 1,675	$ 3,675	$ 2,803
Nonvested Equity Shares [Member]
Stock Based Compensation [Line Items]
Non-cash stock-based compensation equity awards	1,520	1,553	2,850	3,003
Nonvested Equity Common Stock Units
Stock Based Compensation [Line Items]
Non-cash stock-based compensation equity awards	277	172	447	342
Nonvested Performance-Based Equity
Stock Based Compensation [Line Items]
Non-cash stock-based compensation equity awards	0	89	0	558
Nonvested Performance Cash Units
Stock Based Compensation [Line Items]
Cash Unit Based Compensation Awards	$ 451	$ (139)	$ 378	$ (1,100)

Equity Incentive Compensation56

Equity Incentive Compensation Plans and Other Long-term Incentive Programs - Additional Information (Detail) $ / shares in Units, $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2018USD ($)$ / shares$ / unitshares	Jun. 30, 2017$ / unitshares	Jun. 30, 2018USD ($)integerunit$ / shares$ / unitshares	Jun. 30, 2017$ / unitshares	Dec. 31, 2017USD ($)$ / shares$ / unit	Dec. 31, 2015unit	Mar. 31, 2018$ / unit	Mar. 31, 2017$ / unit	Dec. 31, 2016$ / unit
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Derivatives and other noncurrent liabilities	$ (25,001)		$ (25,001)		$ (9,377)
Preferred Stock, Par or Stated Value Per Share (in dollars per share) | $ / shares	$ 0.001		$ 0.001
Common Stock, Par or Stated Value Per Share (in dollars per share) | $ / shares	$ 0.001		$ 0.001		$ 0.001
Weighted Average Fair Value Price Per Unit, Liability Awards (in dollars per share) | $ / unit	6.08	3.41	6.08	3.41	5.10		5.08	4.55	8.89
Unrecognized compensation cost	$ 11,200		$ 11,200
Weighted-average period (years)			2 years
Nonvested Performance Cash Units
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Deferred Compensation Cash-based Arrangements, Liability, Current					$ 1,400
Deferred Compensation Cash-based Arrangements, Liability, Classified, Noncurrent	$ 600		$ 600		$ 3,000
Total shares granted (in shares) | shares	49,833	25,017	846,256	658,158
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares) | shares			286,652	0
Performance Shares
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Award vesting period			3 years
Two Thousand And Seventeen Performance Program [Domain]
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Derivatives and other noncurrent liabilities	$ 900		$ 900
Percentage Of Original Award Converted To Nonvested Common Stock Award			100.00%
Number Of Units Converted To Nonvested Common Stock | integer			619,006
Number Of Shares, Converted From Performance Cash Units | shares			619,006
Adjustments to Additional Paid in Capital, Other			$ 900
Two Thousand And Sixteen Performance Program [Member]
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Derivatives and other noncurrent liabilities	$ 1,800		$ 1,800
Percentage Of Original Award Converted To Nonvested Common Stock Award			89.00%
Number Of Units Not Converted To Nonvested Common Stock | integer			65,173
Number Of Units Converted To Nonvested Common Stock | integer			592,472
Number Of Shares, Converted From Performance Cash Units | shares			527,299
Adjustments to Additional Paid in Capital, Other			$ 1,800
Two Thousand And Fifteen Performance Program [Member]
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Number Of Performance Cash Units Granted (in shares) | unit						422,345
Weighted Percentage Of Stockholders Return Related To Performance Goals			60.00%
Performance Goals Percentage for Change In Discretionary Cash Flow Per Debt Adjusted Share Relative To Defined Peer Groups Percentage			40.00%
Maximum Number Of Cash Units Vest As Percentage Of Performance Cash Units Granted			200.00%
Percent of Performance Based Shares Vested					104.10%
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares) | shares			286,652
Two Thousand And Fifteen Performance Program [Member] | Minimum
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Percentage Of Grant That Will Vest For Performance Met At Threshold Level	25.00%		25.00%
Two Thousand And Fifteen Performance Program [Member] | Maximum
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Percentage Of Grant That Will Vest For Performance Met At Threshold Level	50.00%		50.00%
Percentage Of Grant That Will Vest For Metrics Met At Target Level	100.00%		100.00%
Percentage Of Grant That Will Vest For Metrics Met At Stretch Level			200.00%
Two Thousand Eighteen Performance Program [Domain]
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Cash program vesting period			3 years
Closing Share Price (in dollars per share) | $ / shares	$ 5.13		$ 5.13
Payout If Share Price Less Than $5.13 | unit			0
One Percent Vest For Each One Percent Growth			1.00%
Payout If Relative TSR Is Less Than Median | unit			0
Two Thousand Eighteen Performance Program [Domain] | Absolute Performance
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Award vesting rights, percentage			150.00%
Two Thousand Eighteen Performance Program [Domain] | Relative TSR
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Award vesting rights, percentage			50.00%
Two Thousand Eighteen Performance Program [Domain] | Absolute Performance and Relative TSR | Maximum
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Award vesting rights, percentage			200.00%

Equity Incentive Compensation57

Equity Incentive Compensation Plans and Other Long-term Incentive Programs - Stock Options and Nonvested Equity Shares, Equity Awards Granted (Detail) - $ / shares	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Mar. 31, 2018	Dec. 31, 2017	Mar. 31, 2017	Dec. 31, 2016
Nonvested Equity Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number (in shares)	2,858,278	1,400,260	2,858,278	1,400,260	2,657,535	1,394,868	1,441,939	1,169,099
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares)	(15,724)	(26,289)	(667,932)	(494,892)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value (in dollars per share)	$ 5.45	$ 11.12	$ 8.28	$ 10.58
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period (in shares)	(4,558)	(43,407)	(32,411)	(51,191)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value (in dollars per share)	$ 7.38	$ 7.48	$ 6.73	$ 7.79
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value (in dollars per share)	$ 5.28	$ 7.10	$ 5.28	$ 7.10	$ 5.14	$ 7	$ 7.25	$ 9.33
Total shares granted (in shares)	221,025	28,017	1,017,448	777,244
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value (in dollars per share)	$ 7.08	$ 3.62	$ 5.45	$ 6.01
Share-based Compensation Arrangement by Share-based Payment Award, Shares Modified in Period			1,146,305	0
Nonvested Performance Cash Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number (in shares)	846,256	1,537,198	846,256	1,537,198	796,423	1,548,083	1,567,400	942,326
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares)			(286,652)	0
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period (in shares)	0	(55,219)	(61,242)	(63,286)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value (in dollars per share)	$ 6.08	$ 3.07	$ 6.08	$ 3.07
Total shares granted (in shares)	49,833	25,017	846,256	658,158
Share-Based Compensation, Performance Goal Adjustment (in shares)			11,289	0
Share Based Compensation, Modification (in shares)			(1,211,478)	0
Director [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number (in shares)	302,417	272,559	302,417	272,559	272,559	272,559	147,167	147,167
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares)	(129,027)	(57,961)	(132,225)	(61,532)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value (in dollars per share)	$ 4.62	$ 6.75	$ 4.63	$ 6.62
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value (in dollars per share)	$ 7.37	$ 6.37	$ 7.37	$ 6.37	$ 6.37	$ 6.37	$ 10.09	$ 10.09
Total shares granted (in shares)	158,885	183,353	162,083	186,924
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value (in dollars per share)	$ 6.87	$ 3.50	$ 6.83	$ 3.52

Commitments and Contingencies -

Commitments and Contingencies - Schedule of Aggregate Undiscounted Minimum Future Lease Payments (Detail) - Lease Financing Obligation $ in Thousands	Jun. 30, 2018USD ($)
Future Minimum Lease Payments Under Capital Leases And Operating Leases For Continuing Operations [Line Items]
2,018	$ 269
2,019	1,869
Thereafter	0
Total	$ 2,138

Commitments and Contingencies59

Commitments and Contingencies - Additional Information (Detail) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2018USD ($)	Jun. 30, 2017USD ($)	Jun. 30, 2018USD ($)integeragreement	Jun. 30, 2017USD ($)
Contingencies And Commitments [Line Items]
Operating Leases, Rent Expense	$ 0.6	$ 0.5	$ 1.1	$ 1
Minimum Volume Commitment | integer			1
Sale Leaseback Transaction Early Buyout Option To Purchase Equipment	$ 1.8		$ 1.8
Number of Firm Transportation Contracts | agreement			2

Commitments and Contingencies60

Commitments and Contingencies - Gross Future Minimum Transportation Demand and Firm Processing Charges (Detail) $ in Thousands	Jun. 30, 2018USD ($)
Commitments and Contingencies Disclosure [Abstract]
2,018	$ 9,211
2,019	18,691
2,020	18,691
2,021	10,904
Thereafter	0
Total	$ 57,497

Commitments and Contingencies61

Commitments and Contingencies - Future Minimum Annual Payments under Drilling, Lease and Other Agreements (Detail) - Office & Equipment Leases $ in Thousands	Jun. 30, 2018USD ($)
Operating Leased Assets [Line Items]
2,018	$ 5,132
2,019	2,793
2,020	2,405
2,021	2,734
2,022	2,764
Thereafter	13,087
Total	$ 28,915

Commitments and Contingencies C

Commitments and Contingencies Commitments And Contingencies - Gross Future Minimum Volume Charges (Details) $ in Thousands	Jun. 30, 2018USD ($)
Commitments and Contingencies - Gross Future Minimum Volume Charges [Abstract]
2,018	$ 1,308
2,019	2,365
2,020	2,167
2,021	1,996
Thereafter	0
Total	$ 7,836

Guarantor Subsidiaries - Additi

Guarantor Subsidiaries - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2018
Condensed Financial Information Disclosure [Abstract]
Percentage of guarantor subsidiaries	100.00%

Guarantor Subsidiaries - Schedu

Guarantor Subsidiaries - Schedule of Condensed Consolidating Balance Sheets (Detail) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017	Jun. 30, 2017	Dec. 31, 2016
Assets:
Cash and cash equivalents	$ 107,379	$ 314,466	$ 155,565	$ 275,841
Accounts receivable, net of allowance for doubtful accounts	63,443	51,415
Other current assets	2,697	1,782
Property and equipment, net	1,905,620	1,018,880
Intercompany receivable (payable)	0	0
Investment in subsidiaries	0	0
Noncurrent assets	3,814	4,163
Total	2,082,953	1,390,706
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	113,638	84,055
Other current liabilities	150,609	64,879
Intercompany payable	0	0
Long-term debt, net of debt issuance costs	616,625	617,744
Deferred income taxes	137,111	0
Other noncurrent liabilities	49,767	25,474
Stockholders' equity	1,015,203	598,554		571,543
Total liabilities and stockholders' equity	2,082,953	1,390,706
Intercompany Eliminations
Assets:
Cash and cash equivalents	0	0	0	0
Accounts receivable, net of allowance for doubtful accounts	0	0
Other current assets	0	0
Property and equipment, net	0	0
Intercompany receivable (payable)	(854)	(854)
Investment in subsidiaries	(1,016,243)	(1,040)
Noncurrent assets	0	0
Total	(1,017,097)	(1,894)
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	0	0
Other current liabilities	0	0
Intercompany payable	(854)	(854)
Long-term debt, net of debt issuance costs	0	0
Deferred income taxes	0
Other noncurrent liabilities	0	0
Stockholders' equity	(1,016,243)	(1,040)
Total liabilities and stockholders' equity	(1,017,097)	(1,894)
Parent Guarantor | Reportable Legal Entities
Assets:
Cash and cash equivalents	0	0
Accounts receivable, net of allowance for doubtful accounts	0
Other current assets	0
Property and equipment, net	0
Intercompany receivable (payable)	0
Investment in subsidiaries	1,015,203
Noncurrent assets	0
Total	1,015,203
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	0
Other current liabilities	0
Intercompany payable	0
Long-term debt, net of debt issuance costs	0
Deferred income taxes	0
Other noncurrent liabilities	0
Stockholders' equity	1,015,203
Total liabilities and stockholders' equity	1,015,203
Parent Issuer | Reportable Legal Entities
Assets:
Cash and cash equivalents		314,466	155,565	275,841
Accounts receivable, net of allowance for doubtful accounts		51,415
Other current assets		1,782
Property and equipment, net		1,016,986
Intercompany receivable (payable)		854
Investment in subsidiaries		1,040
Noncurrent assets		4,163
Total		1,390,706
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities		84,055
Other current liabilities		64,879
Intercompany payable		0
Long-term debt, net of debt issuance costs		617,744
Other noncurrent liabilities		25,474
Stockholders' equity		598,554
Total liabilities and stockholders' equity		1,390,706
Subsidiary Issuer | Reportable Legal Entities
Assets:
Cash and cash equivalents	107,379	314,466
Accounts receivable, net of allowance for doubtful accounts	63,443
Other current assets	2,697
Property and equipment, net	1,903,726
Intercompany receivable (payable)	854
Investment in subsidiaries	1,040
Noncurrent assets	3,814
Total	2,082,953
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	113,638
Other current liabilities	150,609
Intercompany payable	0
Long-term debt, net of debt issuance costs	616,625
Deferred income taxes	137,111
Other noncurrent liabilities	49,767
Stockholders' equity	1,015,203
Total liabilities and stockholders' equity	2,082,953
Subsidiary Guarantor
Liabilities and Stockholders' Equity:
Deferred income taxes	0
Subsidiary Guarantor | Reportable Legal Entities
Assets:
Cash and cash equivalents	0	0	$ 0	$ 0
Accounts receivable, net of allowance for doubtful accounts	0	0
Other current assets	0	0
Property and equipment, net	1,894	1,894
Intercompany receivable (payable)	0	0
Investment in subsidiaries	0	0
Noncurrent assets	0	0
Total	1,894	1,894
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	0	0
Other current liabilities	0	0
Intercompany payable	854	854
Long-term debt, net of debt issuance costs	0	0
Other noncurrent liabilities	0	0
Stockholders' equity	1,040	1,040
Total liabilities and stockholders' equity	$ 1,894	$ 1,894

Guarantor Subsidiaries - Sche65

Guarantor Subsidiaries - Schedule of Condensed Consolidating Statements of Operations (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended	18 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017	Jun. 30, 2018
Condensed Financial Statements, Captions [Line Items]
Operating revenues	$ 110,398	$ 51,066	$ 191,208	$ 101,602
Operating expenses	(75,725)	(52,619)	(133,870)	(109,640)
General and administrative	(11,624)	(8,943)	(21,731)	(18,292)
Merger transaction expense	(1,277)	0	(6,040)	0	$ (8,700)	$ (14,700)
Interest Expense	(13,093)	(16,137)	(26,183)	(30,088)
Interest income and other income (expense)	(55,585)	8,186	(75,227)	24,856
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	(46,906)	(18,447)	(71,843)	(31,562)
(Provision for) Benefit from Income Taxes	0	0	0	0
Equity in earnings (loss) of subsidiaries	0	0	0	0
Net Income (Loss)	(46,906)	(18,447)	(71,843)	(31,562)	$ (138,225)
Intercompany Eliminations
Condensed Financial Statements, Captions [Line Items]
Operating revenues	0	0	0	0
Operating expenses	0	0	0	0
General and administrative	0	0	0	0
Merger transaction expense	0		0
Interest Expense	0	0	0	0
Interest income and other income (expense)	0	0	0	0
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	0	0	0	0
(Provision for) Benefit from Income Taxes	0	0	0	0
Equity in earnings (loss) of subsidiaries	46,906	20	71,843	72
Net Income (Loss)	46,906	20	71,843	72
Parent Guarantor | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Operating revenues	0		0
Operating expenses	0		0
General and administrative	0		0
Merger transaction expense	0		0
Interest Expense	0		0
Interest income and other income (expense)	0		0
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	0		0
(Provision for) Benefit from Income Taxes	0		0
Equity in earnings (loss) of subsidiaries	(46,906)		(71,843)
Net Income (Loss)	(46,906)		(71,843)
Parent Issuer | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Operating revenues		50,919		101,344
Operating expenses		(52,452)		(109,310)
General and administrative		(8,943)		(18,292)
Interest Expense		(16,137)		(30,088)
Interest income and other income (expense)		8,186		24,856
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries		(18,427)		(31,490)
(Provision for) Benefit from Income Taxes		0		0
Equity in earnings (loss) of subsidiaries		(20)		(72)
Net Income (Loss)		(18,447)		(31,562)
Subsidiary Issuer | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Operating revenues	110,398		191,208
Operating expenses	(75,725)		(133,870)
General and administrative	(11,624)		(21,731)
Merger transaction expense	(1,277)		(6,040)
Interest Expense	(13,093)		(26,183)
Interest income and other income (expense)	(55,585)		(75,227)
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	(46,906)		(71,843)
(Provision for) Benefit from Income Taxes	0		0
Equity in earnings (loss) of subsidiaries	0		0
Net Income (Loss)	(46,906)		(71,843)
Subsidiary Guarantor | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Operating revenues	0	147	0	258
Operating expenses	0	(167)	0	(330)
General and administrative	0	0	0	0
Merger transaction expense	0		0
Interest Expense	0	0	0	0
Interest income and other income (expense)	0	0	0	0
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	0	(20)	0	(72)
(Provision for) Benefit from Income Taxes	0	0	0	0
Equity in earnings (loss) of subsidiaries	0	0	0	0
Net Income (Loss)	$ 0	$ (20)	$ 0	$ (72)

Guarantor Subsidiaries - Sche66

Guarantor Subsidiaries - Schedule of Condensed Consolidating Statements of Comprehensive Income (Loss) (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	$ (46,906)	$ (18,447)	$ (71,843)	$ (31,562)	$ (138,225)
Other comprehensive income (loss)	0	0	0	0
Comprehensive Income (Loss)	(46,906)	(18,447)	(71,843)	(31,562)
Intercompany Eliminations
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	46,906	20	71,843	72
Other comprehensive income (loss)	0	0		0
Comprehensive Income (Loss)	46,906	20	71,843	72
Parent Guarantor | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(46,906)		(71,843)
Other comprehensive income (loss)	0		0
Comprehensive Income (Loss)	(46,906)		(71,843)
Parent Issuer | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Net income (loss)		(18,447)		(31,562)
Other comprehensive income (loss)		0		0
Comprehensive Income (Loss)		(18,447)		(31,562)
Subsidiary Issuer | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	(46,906)		(71,843)
Other comprehensive income (loss)	0		0
Comprehensive Income (Loss)	(46,906)		(71,843)
Subsidiary Guarantor | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Net income (loss)	0	(20)	0	(72)
Other comprehensive income (loss)	0	0	0	0
Comprehensive Income (Loss)	$ 0	$ (20)	$ 0	$ (72)

Guarantor Subsidiaries - Sche67

Guarantor Subsidiaries - Schedule of Condensed Consolidating Statements of Cash Flows (Detail) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	$ 68,887	$ 38,199
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	(220,816)	(104,236)
Additions to furniture, fixtures and other	(470)	(201)
Repayment of debt associated with merger, net of cash acquired	(53,357)	0
Proceeds from sale of properties and other investing activities	530	(615)
Intercompany transfers	0	0
Cash flows from financing activities:
Proceeds from debt		275,000
Principal payments on debt	(232)	(322,113)
Proceeds from sale of common stock, net of offering costs	0	(298)
Intercompany transfers	0	0
Other financing activities	(1,629)	(6,012)
Increase (Decrease) in Cash and Cash Equivalents	(207,087)	(120,276)
Beginning Cash and Cash Equivalents	314,466	275,841
Ending Cash and Cash Equivalents	107,379	155,565
Intercompany Eliminations
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	0	0
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	0	0
Additions to furniture, fixtures and other	0	0
Repayment of debt associated with merger, net of cash acquired	0
Proceeds from sale of properties and other investing activities	0	0
Intercompany transfers	0	(224)
Cash flows from financing activities:
Proceeds from debt		0
Principal payments on debt	0	0
Proceeds from sale of common stock, net of offering costs		0
Intercompany transfers	0	224
Other financing activities	0	0
Increase (Decrease) in Cash and Cash Equivalents	0	0
Beginning Cash and Cash Equivalents	0	0
Ending Cash and Cash Equivalents	0	0
Parent Guarantor | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	0
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	0
Additions to furniture, fixtures and other	0
Repayment of debt associated with merger, net of cash acquired	0
Proceeds from sale of properties and other investing activities	0
Intercompany transfers	0
Cash flows from financing activities:
Principal payments on debt	0
Intercompany transfers	0
Other financing activities	0
Increase (Decrease) in Cash and Cash Equivalents	0
Beginning Cash and Cash Equivalents	0
Ending Cash and Cash Equivalents	0
Parent Issuer | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities		37,975
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions		(104,236)
Additions to furniture, fixtures and other		(201)
Proceeds from sale of properties and other investing activities		(615)
Intercompany transfers		224
Cash flows from financing activities:
Proceeds from debt		275,000
Principal payments on debt		(322,113)
Proceeds from sale of common stock, net of offering costs		(298)
Intercompany transfers		0
Other financing activities		(6,012)
Increase (Decrease) in Cash and Cash Equivalents		(120,276)
Beginning Cash and Cash Equivalents	314,466	275,841
Ending Cash and Cash Equivalents		155,565
Subsidiary Issuer | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	68,887
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	(220,816)
Additions to furniture, fixtures and other	(470)
Repayment of debt associated with merger, net of cash acquired	(53,357)
Proceeds from sale of properties and other investing activities	530
Intercompany transfers	0
Cash flows from financing activities:
Principal payments on debt	(232)
Intercompany transfers	0
Other financing activities	(1,629)
Increase (Decrease) in Cash and Cash Equivalents	(207,087)
Beginning Cash and Cash Equivalents	314,466
Ending Cash and Cash Equivalents	107,379
Subsidiary Guarantor
Cash flows from financing activities:
Proceeds from debt		0
Subsidiary Guarantor | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	0	224
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	0	0
Additions to furniture, fixtures and other	0	0
Repayment of debt associated with merger, net of cash acquired	0
Proceeds from sale of properties and other investing activities	0	0
Intercompany transfers	0	0
Cash flows from financing activities:
Principal payments on debt	0	0
Proceeds from sale of common stock, net of offering costs		0
Intercompany transfers	0	(224)
Other financing activities	0	0
Increase (Decrease) in Cash and Cash Equivalents	0	0
Beginning Cash and Cash Equivalents	0	0
Ending Cash and Cash Equivalents	$ 0	$ 0