HighPoint Resources (HPR) 10-Q 3 Aug 20 2020 Q2 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	6 Months Ended
	Jun. 30, 2020	Jul. 20, 2020
Document Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2020
Document Transition Report	false
Entity File Number	001-38435
Entity Registrant Name	HighPoint Resources Corp
Entity Central Index Key	0001725526
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q2
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	82-3620361
Entity Address, Address Line One	555 17th Street, Suite 3700
Entity Address, City or Town	Denver
Entity Address, State or Province	CO
Entity Address, Postal Zip Code	80202
City Area Code	303
Local Phone Number	293-9100
Title of 12(b) Security	Common stock, $0.001 par value
Trading Symbol	HPR
Security Exchange Name	NYSE
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		215,264,180

CONSOLIDATED BALANCE SHEETS (UN

CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Current Assets:
Cash and cash equivalents	$ 2,736	$ 16,449
Accounts receivable, net of allowance	59,277	62,120
Derivative assets	72,236	3,916
Prepayments and other current assets	5,962	3,952
Total current assets	140,211	86,437
Property and equipment - at cost, successful efforts method for oil and gas properties:
Proved oil and gas properties	2,749,042	2,644,129
Unproved oil and gas properties, excluded from amortization	243,309	357,793
Furniture, equipment and other	30,739	29,804
Property, plant and equipment, gross	3,023,090	3,031,726
Accumulated depreciation, depletion, amortization and impairment	(2,235,234)	(967,552)
Total property and equipment, net	787,856	2,064,174
Derivative assets	15,546	0
Other noncurrent assets	8,375	5,441
Total	951,988	2,156,052
Current Liabilities:
Accounts payable and accrued liabilities	42,077	71,638
Amounts payable to oil and gas property owners	25,226	37,922
Production taxes payable	46,985	61,507
Derivative liabilities	0	4,411
Total current liabilities	114,288	175,478
Long-term debt, net of debt issuance costs	794,673	758,911
Asset retirement obligations	23,950	23,491
Deferred income taxes	2,137	97,418
Other noncurrent liabilities	14,761	17,436
Commitments and contingencies (Note 11)
Stockholders’ Equity:
Common stock, $0.001 par value; authorized 400,000,000 shares; 215,409,996 and 213,669,597 shares issued and outstanding at June 30, 2020 and December 31, 2019, respectively, with 3,168,704 and 2,968,497 shares subject to restrictions, respectively	212	211
Additional paid-in capital	1,779,906	1,777,779
Retained earnings (accumulated deficit)	(1,777,939)	(694,672)
Treasury stock, at cost: zero shares at June 30, 2020 and December 31, 2019	0	0
Total stockholders’ equity	2,179	1,083,318
Total	$ 951,988	$ 2,156,052

CONSOLIDATED BALANCE SHEETS (_2

CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) - $ / shares	Jun. 30, 2020	Dec. 31, 2019
Statement of Financial Position [Abstract]
Common stock, par value (in dollars per share)	$ 0.001	$ 0.001
Common stock, shares authorized (in shares)	400,000,000	400,000,000
Common stock, shares issued (in shares)	215,409,996	213,669,597
Common stock, shares outstanding (in shares)	215,409,996	213,669,597
Common stock, shares subject to restrictions (in shares)	3,168,704	2,968,497
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, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Operating Revenues:
Total operating revenues	$ 43,300	$ 107,584	$ 122,866	$ 209,564
Operating Expenses:
Production tax expense	1,449	8,905	(1,059)	12,798
Exploration expense	21	12	52	37
Impairment and abandonment expense	810	995	1,266,236	1,317
(Gain) loss on sale of properties	4,779	2,906	4,779	2,901
Depreciation, depletion and amortization	24,908	72,612	99,833	145,222
Unused commitments	4,378	4,352	8,836	8,821
General and administrative expense	12,890	12,401	23,105	25,061
Merger transaction expense	0	0	0	2,414
Other operating expenses, net	(557)	4	(502)	(20)
Total operating expenses	62,006	114,701	1,430,101	224,065
Operating Income (Loss)	(18,706)	(7,117)	(1,307,235)	(14,501)
Other Income and Expense:
Interest and other income (expense)	259	154	64	468
Interest expense	(15,388)	(14,381)	(29,771)	(28,060)
Commodity derivative gain (loss)	(33,793)	19,544	158,395	(85,647)
Total other income and expense	(48,922)	5,317	128,688	(113,239)
Income (Loss) before Income Taxes	(67,628)	(1,800)	(1,178,547)	(127,740)
(Provision for) Benefit from Income Taxes	0	(110)	95,280	29,601
Net Income (Loss)	$ (67,628)	$ (1,910)	$ (1,083,267)	$ (98,139)
Net Income (Loss) Per Common Share, Basic (in dollars per share)	$ (0.32)	$ (0.01)	$ (5.12)	$ (0.47)
Net Income (Loss) Per Common Share, Diluted (in dollars per share)	$ (0.32)	$ (0.01)	$ (5.12)	$ (0.47)
Weighted Average Common Shares Outstanding, Basic (in shares)	211,894,790	210,377,152	211,503,310	210,155,678
Weighted Average Common Shares Outstanding, Diluted (in shares)	211,894,790	210,377,152	211,503,310	210,155,678
Oil, gas and NGL production
Operating Revenues:
Production and other revenues	$ 43,300	$ 107,486	$ 122,866	$ 209,191
Other operating revenues, net
Operating Revenues:
Production and other revenues	0	98	0	373
Lease operating expense
Operating Expenses:
Cost of goods and services	9,074	10,772	20,155	22,049
Gathering, transportation and processing expense
Operating Expenses:
Cost of goods and services	$ 4,254	$ 1,742	$ 8,666	$ 3,465

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Operating Activities:
Net Income (Loss)	$ (1,083,267)	$ (98,139)
Adjustments to reconcile to net cash provided by operations:
Depreciation, depletion and amortization	99,833	145,222
Deferred income taxes	(95,280)	(29,601)
Impairment and abandonment expense	1,266,236	1,317
Commodity derivative (gain) loss	(158,395)	85,647
Settlements of commodity derivatives	69,447	3,656
Stock compensation and other non-cash charges	2,645	6,980
Amortization of deferred financing costs	2,287	1,275
(Gain) loss on sale of properties	4,779	2,901
Change in operating assets and liabilities:
Accounts receivable	(2,413)	18,475
Prepayments and other assets	(1,905)	(1,463)
Accounts payable, accrued and other liabilities	(16,441)	(6,733)
Amounts payable to oil and gas property owners	(12,696)	(22,923)
Production taxes payable	(14,522)	(8,069)
Net cash provided by (used in) operating activities	60,308	98,545
Investing Activities:
Additions to oil and gas properties, including acquisitions	(110,841)	(258,153)
Additions of furniture, equipment and other	(653)	(3,574)
Other investing activities	3,189	(98)
Net cash provided by (used in) investing activities	(108,305)	(261,825)
Financing Activities:
Proceeds from debt	120,000	150,000
Principal payments on debt	(85,000)	(1,859)
Other financing activities	(716)	(1,523)
Net cash provided by (used in) financing activities	34,284	146,618
Increase (Decrease) in Cash and Cash Equivalents	(13,713)	(16,662)
Beginning Cash and Cash Equivalents	16,449	32,774
Ending Cash and Cash Equivalents	$ 2,736	$ 16,112

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
Balance at Dec. 31, 2018	$ 1,212,098	$ 210	$ 1,771,730	$ (559,842)	$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Restricted stock activity and shares exchanged for tax withholding	(1,506)				(1,506)
Stock-based compensation	3,940		3,940
Retirement of treasury stock	0		(1,506)		1,506
Net income (loss)	(98,139)			(98,139)
Balance at Jun. 30, 2019	1,116,393	210	1,774,164	(657,981)	0
Balance at Mar. 31, 2019	1,116,475	210	1,772,336	(656,071)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Restricted stock activity and shares exchanged for tax withholding	(22)				(22)
Stock-based compensation	1,850		1,850
Retirement of treasury stock	0		(22)		22
Net income (loss)	(1,910)			(1,910)
Balance at Jun. 30, 2019	1,116,393	210	1,774,164	(657,981)	0
Balance at Dec. 31, 2019	1,083,318	211	1,777,779	(694,672)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Restricted stock activity and shares exchanged for tax withholding	(653)	1			(654)
Stock-based compensation	2,781		2,781
Retirement of treasury stock	0		(654)		654
Net income (loss)	(1,083,267)			(1,083,267)
Balance at Jun. 30, 2020	2,179	212	1,779,906	(1,777,939)	0
Balance at Mar. 31, 2020	68,472	212	1,778,571	(1,710,311)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Restricted stock activity and shares exchanged for tax withholding	(18)				(18)
Stock-based compensation	1,353		1,353
Retirement of treasury stock	0		(18)		18
Net income (loss)	(67,628)			(67,628)
Balance at Jun. 30, 2020	$ 2,179	$ 212	$ 1,779,906	$ (1,777,939)	$ 0

Organization

Organization	6 Months Ended
	Jun. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization	OrganizationHighPoint 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 Energy 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, 2020
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 Company’s Annual Report on Form 10-K for the year ended December 31, 2019 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 Annual Report on Form 10-K. 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 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, right-of-use assets and lease liabilities, deferred income taxes, the timing of dry hole costs, impairments of proved and unproved oil and gas properties and fair values of derivative instruments and stock-based payment awards. Further, these estimates and other factors, including those outside of the Company’s control, such as the impact of lower commodity prices, may have a significant adverse impact to the Company’s business, financial condition, results of operations and cash flows. Accounts Receivable. Accounts receivable is comprised of the following: As of June 30, 2020 As of December 31, 2019 (in thousands) Oil, gas and NGL sales $ 32,383 $ 50,171 Due from joint interest owners (1) 23,796 9,551 Other 3,129 2,419 Allowance for doubtful accounts (31) (21) Total accounts receivable $ 59,277 $ 62,120 (1) Includes $12.9 million associated with one joint interest partner. In the event of nonpayment, the Company expects to net the outstanding amount against certain revenues payable to this joint interest partner. Oil and Gas Properties. 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, 2020 As of December 31, 2019 (in thousands) Proved properties $ 721,174 $ 725,964 Wells and related equipment and facilities 1,910,527 1,805,136 Support equipment and facilities 105,397 99,540 Materials and supplies 11,944 13,489 Total proved oil and gas properties $ 2,749,042 $ 2,644,129 Unproved properties 182,605 265,387 Wells and facilities in progress 60,704 92,406 Total unproved oil and gas properties, excluded from amortization $ 243,309 $ 357,793 Accumulated depreciation, depletion, amortization and impairment (2,224,428) (958,475) Total oil and gas properties, net $ 767,923 $ 2,043,447 The Company reviews proved 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 an analysis of quantitative and qualitative factors existing as of the balance sheet date including 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. 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, income taxes and various discount rates commensurate with the risk and current market conditions associated with realizing the projected cash flows. 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. In early 2020, global health care systems and economies began to experience strain from the spread of COVID-19, a highly transmissible and pathogenic coronavirus (the “COVID-19 pandemic”). As the virus spread, global economic activity began to slow and future economic activity was forecast to slow with a resulting decline in oil demand. In response, the Organization of Petroleum Exporting Countries (“OPEC”), along with non-OPEC oil-producing countries (collectively known as “OPEC+”), initiated discussions to lower production to support energy prices. With OPEC+ unable to agree on cuts, crude oil prices declined to an average of $30.45 per barrel for the month of March 2020, compared to an average of $59.80 per barrel for the month of December 2019. These events led to a decline in the recoverability of the carrying value of the Company’s oil and gas properties during the three months ended March 31, 2020. Since the carrying amount of the oil and gas properties was no longer recoverable, the Company impaired the carrying value to fair value. Therefore, the Company recognized non-cash impairment charges during the three months ended March 31, 2020, which were included within impairment and abandonment expense in the Unaudited Consolidated Statements of Operations. For the three months ended March 31, 2020, the Company contracted with an independent third party to assist the Company in the Company’s determination of fair value associated with the Company’s proved and unproved oil and gas properties. Through the use of the Company’s production and price forecast, the third party used the income valuation technique to assist the Company in the determination of fair value for the proved developed producing (“PDP”) and proved developed non-producing (“PDN”) reserves and a market approach utilizing sales prices of comparable properties to assist the Company in the determination of fair value of the proved undeveloped (“PUD”), probable (“PROB”) and possible (“POSS”) reserves. The Company’s impairment and abandonment expense for the three and six months ended June 30, 2020 and 2019 is summarized below: Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 (in thousands) Impairment of proved oil and gas properties $ — $ — $ 1,188,566 $ — Impairment of unproved oil and gas properties — — 76,298 — Abandonment expense 810 995 1,372 1,317 Total impairment and abandonment expense $ 810 $ 995 $ 1,266,236 $ 1,317 Accounts Payable and Accrued Liabilities. Accounts payable and accrued liabilities are comprised of the following: As of June 30, 2020 As of December 31, 2019 (in thousands) Accrued drilling, completion and facility costs $ 12,957 $ 25,667 Accrued lease operating, gathering, transportation and processing expenses 7,364 8,046 Accrued general and administrative expenses 6,910 6,612 Accrued interest payable 6,681 6,832 Trade payables 3,951 17,488 Operating lease liability 1,954 1,287 Other 2,260 5,706 Total accounts payable and accrued liabilities $ 42,077 $ 71,638 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. Under Wyoming law, the Company is exposed to potential obligations for plugging and abandoning wells, and associated reclamation, for assets that were sold to other industry parties in prior years. When such third parties are unable to fulfill their contractual obligations to the Company as provided for in purchase and sale agreements, landowners, as well as the Bureau of Land Management, may demand 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, 2020, the Company had open contracts with customers with terms of 1 month to 17 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 therefore are 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 were not 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. A valuation allowance is recorded if it is more likely than not that all or some portion of the Company’s deferred tax assets will not be realized. The Company regularly assesses the realizability of the deferred tax assets considering all positive and negative evidence, including scheduled reversals of deferred tax liabilities, projected future taxable income, planning strategies and results of recent operations. The assumptions about future taxable income require significant judgment to determine if a valuation allowance is required. Changes to the Company’s development plans, changes in market prices for hydrocarbons, changes in operating results, or other factors including changes in tax law could change the valuation allowance in future periods, resulting in recognition of a tax expense or 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, 2020. Comprehensive Income. The Company has no elements of other comprehensive income, therefore, the Company’s net income (loss) on the Unaudited Consolidated Statements of Operations represents comprehensive income. 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. The Company was in a net loss position for the three and six months ended June 30, 2020 and 2019; therefore, all potentially dilutive securities were anti-dilutive. 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, 2020 2019 2020 2019 (in thousands, except per share amounts) Net income (loss) $ (67,628) $ (1,910) $ (1,083,267) $ (98,139) Basic weighted-average common shares outstanding in period 211,895 210,377 211,503 210,156 Diluted weighted-average common shares outstanding in period 211,895 210,377 211,503 210,156 Basic net income (loss) per common share $ (0.32) $ (0.01) $ (5.12) $ (0.47) Diluted net income (loss) per common share $ (0.32) $ (0.01) $ (5.12) $ (0.47) New Accounting Pronouncements. In April 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2020-04, Facilitation of the Effects of Reference Rate Reform on Financial Reporting . In response to the cessation of the London Interbank Offered Rate (“LIBOR”) by December 31, 2022, the FASB issued this update to provide optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other affected transactions. The Company currently has only one contract, its credit facility, that may be impacted by this ASU. Modifications of debt contracts should be accounted for by prospectively adjusting the effective interest rate. This update has an effective period of March 12, 2020 through December 31, 2022 and allows for elections to be made by the Company in terms of how the ASU is adopted. Once elected for a Topic or Industry Subtopic, the update must be applied prospectively for all eligible contract modifications for that Topic or Industry Subtopic. The Company does not believe the standard will have a material impact on the Company’s financial statements. In August 2018, the FASB issued ASU 2018-13, Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement . The objective of this update is to improve the effectiveness of fair value measurement disclosures. ASU 2018-13 is effective for annual periods beginning after December 15, 2019 and interim periods within those annual periods. The standard was adopted on January 1, 2020 and did not have a material impact on the Company’s disclosures. In June 2016, the FASB issued ASU 2016-13, Financial Instruments, Credit Losses

Supplemental Disclosures of Cas

Supplemental Disclosures of Cash Flow Information	6 Months Ended
	Jun. 30, 2020
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, 2020 2019 (in thousands) Cash paid for interest $ 27,635 $ 26,689 Cash paid for income taxes — — Cash paid for amounts included in the measurements of lease liabilities: Cash paid for operating leases 873 595 Non-cash operating activities: Right-of-use assets obtained in exchange for lease obligations Operating leases (1)(2) 777 14,955 Non-cash investing and financing activities: Accounts payable and accrued liabilities - oil and gas properties 11,746 87,109 Change in asset retirement obligations, net of disposals (12) (5,022) Retirement of treasury stock (654) (1,506) Properties exchanged in non-cash transactions 4,753 4,561 (1) Excludes the reclassifications of lease incentives and deferred rent balances. (2) The six months ended June 30, 2019 included $14.0 million of right-of-use assets established with the adoption of ASC 842, Leases , effective January 1, 2019.

Long-Term Debt

Long-Term Debt	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Long-Term Debt	Long-Term Debt The Company’s outstanding debt is summarized below: As of June 30, 2020 As of December 31, 2019 Maturity Date Principal Debt Issuance Costs Carrying Principal Debt Issuance Costs Carrying (in thousands) Amended Credit Facility September 14, 2023 $ 175,000 $ — $ 175,000 $ 140,000 $ — $ 140,000 7.0% Senior Notes October 15, 2022 350,000 (1,954) 348,046 350,000 (2,372) 347,628 8.75% Senior Notes June 15, 2025 275,000 (3,373) 271,627 275,000 (3,717) 271,283 Total Long-Term Debt $ 800,000 $ (5,327) $ 794,673 $ 765,000 $ (6,089) $ 758,911 Amended Credit Facility On May 21, 2020, the Company entered into an amendment to the fourth amended and restated credit facility (the “Amended Credit Facility”), which decreased the aggregate elected commitment amount and the borrowing base from $500.0 million to $300.0 million, increased the applicable margins for interest and commitment fee rates and added provisions requiring the availability under the Amended Credit Facility to be at least $50.0 million and the Company’s weekly cash balance (subject to certain exceptions) to not exceed $35.0 million. The Company had $175.0 million and $140.0 million outstanding under the Amended Credit Facility as of June 30, 2020 and December 31, 2019, respectively. As credit support for future payments under a contractual obligation, a $21.7 million letter of credit has been issued under the Amended Credit Facility, which reduced the available borrowing capacity under the Amended Credit Facility as of June 30, 2020 to $53.3 million after taking into account the $50.0 million availability requirement. While the stated maturity date in the Amended Credit Facility is September 14, 2023, the maturity date is accelerated if the Company has more than $100.0 million of “Permitted Debt” or “Permitted Refinancing Debt” (as those terms are defined in the Amended Credit Facility) that matures prior to December 14, 2023. If that is the case, the accelerated maturity date is 91 days prior to the earliest maturity of such Permitted Debt or Permitted Refinancing Debt. Because the Company’s 7.0% Senior Notes will mature on October 15, 2022, the aggregate amount of those notes exceeds $100.0 million and the notes represent “Permitted Debt”, the maturity date specified in the Amended Credit Facility is accelerated to the date that is 91 days prior to the maturity date of those notes, or July 16, 2022. As of May 21, 2020, interest rates on outstanding loans under the Amended Credit Facility are either adjusted LIBOR plus applicable margins of 2.5% to 3.5% or an alternate base rate, which is generally the prime rate, plus applicable margins of 1.5% to 2.5%, and the unused commitment fee is 0.5%. The applicable margins and the unused commitment fee rate are determined based on borrowing base utilization. The weighted average annual interest rate incurred on the Amended Credit Facility was 2.7% and 4.2% for the three months ended June 30, 2020 and 2019, respectively, and 3.0% and 4.1% for the six months ended June 30, 2020 and 2019, respectively. The borrowing base under the Amended Credit Facility is determined at the discretion of the lenders and is subject to regular re-determination on or about April 1 and October 1 of each year, as well as following any property sales. The lenders can also request an interim redetermination during each six month period. The borrowing base is computed based on proved oil, natural gas and NGL reserves that have been mortgaged to the lenders, hedge positions and estimated future cash flows from the reserves calculated using future commodity pricing provided by the lenders, as well as any other outstanding debt. The Company has financial covenants associated with its Amended Credit Facility that are measured each fiscal quarter. The Company is currently in compliance with all financial covenants and has complied with all financial covenants since issuance. However, if current market conditions continue, the Company may not be able to maintain compliance with these financial covenants. In particular, the Company may breach the debt-to-EBITDAX ratio and the current ratio covenants in the Amended Credit Facility in the latter part of 2021. Further, if the Company’s independent auditor were to include an explanatory paragraph regarding the Company’s ability to continue as a “going concern” in the auditors’ report on the Company’s financial statements for the year ending December 31, 2020, this would also cause a default under the Amended Credit Facility. If a covenant breach occurs or is likely, the Company may attempt to obtain a waiver from the lenders under the Amended Credit Facility, seek to amend the terms of the Amended Credit Facility to prevent the breach or seek to obtain alternative financing to repay the Amended Credit Facility balance outstanding. If these efforts are unsuccessful, all or a portion of the amount borrowed under the Amended Credit Facility could become due, and cross-defaults could occur under the Company’s senior notes and the Company may not have other sources of capital to repay the amounts due. Senior Notes The issuer of the 7.0% Senior Notes and the 8.75% Senior Notes is HighPoint Operating Corporation (f/k/a Bill Barrett), or Subsidiary Issuer. Pursuant to supplemental indentures entered into in connection with the Merger, HighPoint Resources Corporation, or the Parent Guarantor, became a guarantor of the 7.0% Senior Notes and the 8.75% Senior Notes in March 2018. In addition, Fifth Pocket Production, LLC, or the Subsidiary Guarantor, became a subsidiary of the Subsidiary Issuer on August 1, 2019 and also guarantees the 7.0% Senior Notes and the 8.75% Senior Notes. The Parent Guarantor and the Subsidiary Guarantor, on a joint and several basis, fully and unconditionally guarantee the debt securities of the Subsidiary Issuer. The Company has no additional subsidiaries or non-guarantor subsidiaries. All covenants in the indentures governing the notes limit the activities of the Subsidiary Issuer and the Subsidiary Guarantor, including limitations on the ability to pay dividends, incur additional indebtedness, make restricted payments, create liens, sell assets or make loans to the Parent Guarantor, but in most cases the covenants in the indentures are not applicable to the Parent Guarantor. 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.

Asset Retirement Obligations

Asset Retirement Obligations	6 Months Ended
	Jun. 30, 2020
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, 2020 is as follows (in thousands): As of December 31, 2019 $ 25,709 Liabilities incurred 488 Liabilities settled (766) Disposition of properties (143) Accretion expense 872 Revisions to estimate 409 As of June 30, 2020 $ 26,569 Less: Current asset retirement obligations 2,619 Long-term asset retirement obligations $ 23,950

Fair Value Measurements

Fair Value Measurements	6 Months Ended
	Jun. 30, 2020
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 the Company’s Unaudited Consolidated Balance Sheets. 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 and cashless collars 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 Company currently utilizes an independent third party to perform the valuation. 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, 2020 Financial Assets Deferred compensation plan $ 1,167 $ — $ — $ 1,167 Commodity derivatives — 91,150 — 91,150 Financial Liabilities Commodity derivatives — 3,368 — 3,368 As of December 31, 2019 Financial Assets Deferred compensation plan $ 2,033 $ — $ — $ 2,033 Commodity derivatives — 8,890 — 8,890 Financial Liabilities Commodity derivatives — 10,056 — 10,056 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 the Company’s consolidated balance sheets. The following methods and assumptions were used to estimate the fair values: Oil and gas properties – Proved oil and natural gas properties are evaluated 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. Whenever the Company concludes the carrying value may not be recoverable, 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 its 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. 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. During the three months ended March 31, 2020, the Company’s proved oil and gas properties with a carrying value of $1.7 billion were reduced to a fair value of $0.5 billion, resulting in an impairment of $1.2 billion which was included in impairment and abandonment expense on the Unaudited Statement of Operations for the three months ended March 31, 2020. For the three months ended March 31, 2020, the Company contracted with an independent third party to assist with the Company’s determination of fair value associated with its proved oil and gas properties. Through the use of the Company’s production and price forecast, the third party used the income valuation technique to assist the Company in the determination of fair value for the PDP and PDN reserves and a market approach utilizing sales prices of comparable properties to assist the Company in the determination of fair value of the PUD reserves. The following table includes quantitative information about the significant unobservable inputs, categorized within Level 3 of the fair value hierarchy, that were used in the fair value measurement. Level 3 Unobservable Inputs As of March 31, 2020 Price (1) Oil (per Bbl) $29 to $60 Gas (per MMbtu) $2.03 to $2.52 NGL (percentage of oil price) 24% to 31% Reserve adjustment factors PDP 100% PDN 95% Discount rate 11% (1) These prices were adjusted for location and quality differentials. 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. During the three months ended March 31, 2020, due to substantial commodity price declines, certain unproved oil and gas properties with a carrying value of $256.0 million were reduced to a fair value of $179.7 million, resulting in an impairment of $76.3 million which was included in impairment and abandonment expense on the Unaudited Statement of Operations for the three months ended March 31, 2020. For the three months ended March 31, 2020, the Company contracted with an independent third party to assist the Company in the Company’s determination of fair value of the Company’s unproved oil and gas properties. The third party used the market approach utilizing sales prices of comparable properties to determine the fair value of the unproved oil and gas properties. 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 estimated fair value of the 7.0% Senior Notes was approximately $286.1 million and $335.0 million as of June 30, 2020 and December 31, 2019, respectively. The estimated fair value of the 8.75% Senior Notes was approximately $147.1 million and $251.2 million as of June 30, 2020 and December 31, 2019, respectively. The fair values of the Company’s fixed rate Senior Notes are based on active market quotes, which represent Level 1 inputs.

Derivative Instruments

Derivative Instruments	6 Months Ended
	Jun. 30, 2020
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 and swaption contracts related to the sale of a portion of the Company’s production. A swap allows the Company to receive a fixed price for its production and pay a variable market price to the counterparty. A swaption allows the counterparty, on a specific date, to extend an existing fixed-price swap for a certain period of time or to increase the notional volumes of an existing fixed-price swap. The Company has also entered into crude oil swaps to fix the differential in pricing between the NYMEX WTI calendar month average and the physical crude delivery month (“oil roll swaps”). 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, 2020 Balance Sheet Gross Amounts of Gross Amounts Offset in the Balance Sheet (1) Net Amounts of (in thousands) Derivative assets (current) $ 73,466 $ (1,230) $ 72,236 Derivative assets (noncurrent) 17,684 (2,138) 15,546 Total derivative assets $ 91,150 $ (3,368) $ 87,782 Gross Amounts of Gross Amounts Offset in the Balance Sheet (1) Net Amounts of (in thousands) Accounts payable and accrued liabilities $ (1,230) $ 1,230 $ — Other noncurrent liabilities (2,138) 2,138 — Total derivative liabilities $ (3,368) $ 3,368 $ — As of December 31, 2019 Balance Sheet Gross Amounts of Gross Amounts Offset in the Balance Sheet (1) Net Amounts of (in thousands) Derivative assets (current) $ 8,477 $ (4,561) $ 3,916 Derivative assets (noncurrent) 413 (413) — Total derivative assets $ 8,890 $ (4,974) $ 3,916 Gross Amounts of Gross Amounts Offset in the Balance Sheet (1) Net Amounts of (in thousands) Accounts payable and accrued liabilities $ (8,972) $ 4,561 $ (4,411) Other noncurrent liabilities (1,084) 413 (671) Total derivative liabilities $ (10,056) $ 4,974 $ (5,082) (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, 2020, the Company had swap and swaption contracts in place to hedge the following volumes for the periods indicated: July – December 2020 For the year 2021 For the year 2022 Derivative Weighted Average Price Derivative Volumes Weighted Average Price Derivative Volumes Weighted Average Price Swaps Oil (Bbls) 2,760,000 $ 56.59 3,098,000 $ 54.30 — $ — Natural Gas (MMbtu) 3,680,000 $ 1.83 5,790,000 $ 2.13 — $ — Oil Roll Swaps (1) Oil (Bbls) 276,500 $ (1.47) — — — — Swaptions Oil (Bbls) — $ — — $ — 1,092,000 $ 55.08 (1) These contracts establish a fixed amount for the differential between the NYMEX WTI calendar month average and the physical crude oil delivery month. The weighted average differential represents the amount of reduction to NYMEX WTI prices for the notional volumes covered by the swap contracts. 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 eight different counterparties as of June 30, 2020. 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 its 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, 2020
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes The Company accounts for uncertainty in income taxes for tax positions taken or expected to be taken in a tax return in accordance with the FASB’s rules on income taxes. The Company recognizes the tax benefit from an uncertain tax position only if it is more likely than not that the tax position will be sustained upon examination by the taxing authorities. During the three and six months ended June 30, 2020 and 2019, the Company had no uncertain tax positions. The Company’s policy is to classify accrued penalties and interest related to unrecognized tax benefits in the Company’s income tax provision. The Company did not record any accrued interest or penalties associated with unrecognized tax benefits during the three and six months ended June 30, 2020 and 2019. Income tax benefit for the three and six months ended June 30, 2020 and 2019 differs from the amounts that would be provided by applying the U.S. statutory income tax rates to pretax income or loss principally due to stock-based compensation, political lobbying expense, political contributions, nondeductible officer compensation, state income taxes, and for 2020, the effect of deferred tax asset valuation allowances. For the three and six months ended June 30, 2020, the Company recognized zero and $95.3 million of income tax benefit, respectively. For the three and six months ended June 30, 2019, the Company recognized $0.1 million of income tax expense and $29.6 million of income tax benefit, respectively. The Company considers all available evidence (both positive and negative) to estimate whether sufficient future taxable income will be generated to permit the use of the existing deferred tax assets. Such evidence includes the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning strategies in making this assessment, and judgment is required in considering the relative weight of negative and positive evidence. For the three and six months ended June 30, 2020, the Company determined that there would not be sufficient future taxable income to use existing deferred tax assets and has recorded a valuation allowance against the existing net deferred tax assets. For the six months ended June 30, 2020, the Company has recorded a deferred tax liability of $2.1 million for projected taxable income in future periods in which only 80% of taxable income can be offset by net operating losses. The Company continues to monitor facts and circumstances in the reassessment of the likelihood that operating loss carryforwards, credits and other deferred tax assets will be utilized prior to their expiration. In response to the COVID-19 pandemic, President Trump signed the Coronavirus Aid, Relief, and Economic Security Act (the “CARES Act”) on March 27, 2020. Several of the provisions included in the CARES Act apply to the Company. The primary impact is the accelerated refundability of the Company’s $1.4 million income tax receivable related to minimum tax credit carryforwards to 2019. The depreciable lives related to 2018 and 2019 qualified improvement property will be adjusted and result in accelerated tax depreciation. In addition, the CARES Act temporarily suspends the 80% income limitation for net operating losses generated and utilized in years beginning prior to January 1, 2021.

Equity Incentive Compensation P

Equity Incentive Compensation Plans and Other Long-term Incentive Programs	6 Months Ended
	Jun. 30, 2020
Share-based Payment Arrangement [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, 2020 2019 2020 2019 (in thousands) Nonvested common stock (1) $ 1,150 $ 1,533 $ 2,300 $ 3,329 Nonvested common stock units (1) 202 318 482 612 Nonvested performance cash units (2)(3) 198 445 (776) 1,077 Total $ 1,550 $ 2,296 $ 2,006 $ 5,018 (1) Unrecognized compensation expense as of June 30, 2020 was $5.1 million, which related to grants of nonvested shares of common stock that are expected to be recognized over a weighted-average period of 1.8 years. (2) The nonvested performance-based cash units are accounted for as liability awards with $0.3 million and $1.2 million in other noncurrent liabilities as of June 30, 2020 and December 31, 2019, respectively, in the Unaudited Consolidated Balance Sheets. (3) Liability awards are fair valued at each reporting date. The expense for the period will increase or decrease based on updated fair values of these awards at each reporting date. 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, 2020 and 2019 is presented below: Three Months Ended June 30, 2020 Three Months Ended June 30, 2019 Nonvested Common Stock Awards Shares Weighted Average Shares Weighted Average Outstanding at April 1, 3,531,812 $ 2.10 3,431,780 $ 3.90 Granted — — 6,000 2.66 Vested (112,677) 4.26 (30,031) 5.81 Forfeited or expired (250,431) 1.52 (1,615) 7.14 Outstanding at June 30, 3,168,704 2.07 3,406,134 3.88 Six Months Ended June 30, 2020 Six Months Ended June 30, 2019 Nonvested Common Stock Awards Shares Weighted Average Shares Weighted Average Outstanding at January 1, 2,968,497 $ 3.81 2,912,166 $ 5.27 Granted 2,028,617 1.14 1,841,700 2.64 Vested (1,568,491) 4.25 (1,329,630) 5.20 Forfeited or expired (259,919) 1.59 (18,102) 4.96 Outstanding at June 30, 3,168,704 2.07 3,406,134 3.88 A summary of the Company’s nonvested common stock unit awards for the three and six months ended June 30, 2020 and 2019 is presented below: Three Months Ended June 30, 2020 Three Months Ended June 30, 2019 Nonvested Common Stock Unit Awards Units Weighted Average Units Weighted Average Outstanding at April 1, 796,103 $ 3.27 311,237 $ 7.26 Granted 530,940 0.27 628,380 1.87 Vested (638,355) 2.63 (143,514) 5.77 Forfeited or expired (79,423) 0.25 — — Outstanding at June 30, 609,265 1.72 796,103 3.27 Six Months Ended June 30, 2020 Six Months Ended June 30, 2019 Nonvested Common Stock Unit Awards Units Weighted Average Units Weighted Average Outstanding at January 1, 796,103 $ 3.27 311,237 $ 7.26 Granted 530,940 0.27 643,084 1.88 Vested (638,355) 2.63 (158,218) 5.44 Forfeited or expired (79,423) 0.25 — — Outstanding at June 30, 609,265 1.72 796,103 3.27 A summary of the Company’s nonvested performance-based cash unit awards for the three and six months ended June 30, 2020 and 2019 is presented below: Three Months Ended June 30, 2020 Three Months Ended June 30, 2019 Nonvested Performance-Based Cash Unit Awards Units Weighted Average Units Weighted Average Outstanding at April 1, 6,096,230 2,868,634 Forfeited or expired (656,430) — Outstanding at June 30, 5,439,800 $ 0.30 2,868,634 $ 1.82 Six Months Ended June 30, 2020 Six Months Ended June 30, 2019 Nonvested Performance-Based Cash Unit Awards Units Weighted Average Units Weighted Average Outstanding at January 1, 2,576,062 909,585 Granted 3,569,434 2,026,521 Forfeited or expired (705,696) (67,472) Outstanding at June 30, 5,439,800 $ 0.30 2,868,634 $ 1.82 Performance Cash Program

Leases

Leases	6 Months Ended
	Jun. 30, 2020
Leases [Abstract]
Leases	Leases A contract is or contains a lease when, (1) the contract contains an explicitly or implicitly identified asset and (2) the customer obtains substantially all of the economic benefits from the use of that underlying asset and directs how and for what purpose the asset is used during the term of the contract in exchange for consideration. The Company assesses whether an arrangement is or contains a lease at inception of the contract. For all leases, other than those that qualify for the short-term recognition exemption, the Company recognizes as of the lease commencement date on the balance sheet a liability for its obligation related to the lease and a corresponding asset representing the Company’s right to use the underlying asset over the period of use. The Company currently has leases for office space and other equipment, all of which are classified as operating leases. The Company’s leases have remaining terms of up to eight years. Certain lease agreements contain options to extend or early terminate the agreement. These options are used to calculate right-of-use asset and lease liability balances when it is reasonably certain that the Company will exercise these options. The discount rate used to calculate the present value of the future minimum lease payments is the Company’s incremental borrowing rate. The Company elected, for all classes of underlying assets, to not apply the balance sheet recognition requirements of ASC 842 to leases with a term of one year or less, and instead, recognize the lease payments in the income statement on a straight-line basis over the lease term. The Company also elected, for certain classes of underlying assets, to combine lease and non-lease components. Therefore, the Company elected to combine lease and non-lease components for drilling rig and gathering system asset classes. These assets are not reported on the Unaudited Consolidated Balance Sheets as the Company’s lease contracts for drilling rigs are currently classified as short-term and the Company’s lease contract for a gathering system includes variable payments. For the three and six months ended June 30, 2020 and 2019, lease cost were as follows: Three Months Ended June 30, Six Months Ended June 30, Lease Cost 2020 2019 2020 2019 (in thousands) Operating lease cost (1)(3) $ 529 $ 569 $ 1,039 $ 1,117 Short-term lease cost (2)(3) 789 4,167 3,052 10,386 Variable lease cost (4) 373 — 693 — Total lease cost $ 1,691 $ 4,736 $ 4,784 $ 11,503 (1) Operating lease cost was primarily included in general and administrative expense or lease operating expense on the Unaudited Consolidated Statements of Operations. (2) Short-term lease cost primarily includes leases for drilling rigs, which were capitalized to property, plant and equipment on the Unaudited Consolidated Balance Sheets. (3) A portion of the operating lease cost and a majority of the short-term lease cost represent gross amounts that the Company was financially committed to pay. However, the Company recorded in the financial statements its proportionate share based on the Company’s working interest, which varies from property to property. (4) Variable lease cost is related to a gathering agreement and is included in oil, gas, and NGL production on the Unaudited Consolidated Statements of Operations. Supplemental balance sheet information related to leases as of June 30, 2020 and December 31, 2019, were as follows: Operating Leases As of June 30, 2020 As of December 31, 2019 (in thousands) Right-of-use assets (1) $ 9,906 $ 9,287 Accumulated amortization (2) (1,621) (1,142) Total right-of-use assets, net (3) $ 8,285 $ 8,145 Current lease liabilities (4) (1,954) (1,287) Noncurrent lease liabilities (5) (12,834) (13,195) Total lease liabilities (3) $ (14,788) $ (14,482) Weighted average remaining lease term Operating leases (in years) 7.3 7.8 Weighted average discount rate Operating leases 5.6 % 5.6 % (1) Included in furniture, equipment and other in the Unaudited Consolidated Balance Sheets. (2) Included in accumulated depreciation, depletion, amortization and impairment in the Unaudited Consolidated Balance Sheets. (3) The difference between the right-of-use assets and total lease liabilities is primarily related to lease incentives and deferred rent balances, which were required to be netted against the right-of-use assets as of the ASC 842 implementation date of January 1, 2019. (4) Included in accounts payable and accrued liabilities in the Unaudited Consolidated Balance Sheets. (5) Included in other noncurrent liabilities in the Unaudited Consolidated Balance Sheets. Maturities of lease liabilities as of June 30, 2020 and December 31, 2019 were as follows: As of June 30, 2020 As of December 31, 2019 (in thousands) 2020 $ 1,377 $ 2,056 2021 2,635 2,355 2022 2,324 2,044 2023 2,101 2,024 2024 2,078 2,078 Thereafter 7,576 7,577 Total $ 18,091 $ 18,134 Less: Interest (3,303) (3,652) Present value of lease liabilities $ 14,788 $ 14,482

Commitments and Contingencies

Commitments and Contingencies	6 Months Ended
	Jun. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Firm Transportation Agreements. The Company is party to two firm transportation contracts to provide capacity on natural gas pipeline systems. The contracts require the Company to pay minimum volume transportation charges through July 2021 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 Company is party to one firm pipeline transportation contract to provide capacity on an oil pipeline system. The contract requires the Company to pay minimum volume transportation charges from May 2020 through April 2025 regardless of the amount of pipeline capacity utilized by the Company. The amounts in the table below represent the Company’s future minimum transportation charges: As of June 30, 2020 (in thousands) 2020 $ 12,732 2021 19,777 2022 13,064 2023 14,600 2024 14,640 Thereafter 4,800 Total $ 79,613 Gas Gathering and Processing Agreements. The Company is party to one minimum volume commitment and two reimbursement obligations. The minimum volume commitment 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 the contracted volumes regardless of the amount delivered. The reimbursement obligations require the Company to pay monthly gathering and processing fees per Mcf of production to reimburse midstream entities for their costs to construct gas gathering and processing facilities. If the costs are not reimbursed by the Company via the monthly gathering and processing fees, the Company must pay the difference. The amounts in the table below represent the Company’s future minimum charges under both types of agreements: As of June 30, 2020 (in thousands) 2020 $ 1,089 2021 5,268 Thereafter — Total $ 6,357 Other Commitments. The Company has one drilling commitment with a joint interest partner that requires the Company to drill and complete two wells by July 2022 and three wells by July 2023. If the drilling commitment is not met, the Company must return the associated leases that are not held by production to the joint interest partner, which cover approximately 13,000 acres. The Company is party to two minimum volume commitments for fresh water. The minimum volume commitments require the Company to purchase a minimum volume of fresh water from a water supplier. The contracts require the Company pay a fee associated with the contracted volumes regardless of the amount delivered. The Company also has non-cancellable agreements for information technology services. Future minimum annual payments under these agreements are as follows: As of June 30, 2020 (in thousands) 2020 $ 1,098 2021 1,285 2022 (1) 11,485 2023 (1) 16,285 Thereafter — Total $ 30,153 (1) Includes $10.2 million in 2022 and $15.3 million in 2023 related to a drilling commitment. 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, other than the following. Sterling Energy Investments LLC v. HighPoint Operating Corporation , 2020CV32034, District Court in Denver, Colorado. On June 15, 2020, Sterling Energy Investments LLC (“Sterling”) filed a complaint against HighPoint Operating Corporation, a subsidiary of the Company, for breach of contract related to a Gas Purchase Agreement dated effective November 1, 2017, by and between HighPoint Operating Corporation and Sterling. Sterling alleges that HighPoint Operating Corporation breached the contract by failing to use reasonable commercial efforts to deliver to Sterling at Sterling’s receipt points all quantities of gas not otherwise dedicated to other gas purchase agreements. The Company vigorously denies Sterling’s claims. Sterling seeks monetary damages in an amount not yet specified. On July 31, 2020, the Company filed a counterclaim against Sterling for breach of Sterling’s obligations under the Gas Gathering Agreement. The Company is seeking monetary damages in an amount not yet specified.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	6 Months Ended
	Jun. 30, 2020
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 Company’s Annual Report on Form 10-K for the year ended December 31, 2019 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 Annual Report on Form 10-K.
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 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, right-of-use assets and lease liabilities, deferred income taxes, the timing of dry hole costs, impairments of proved and unproved oil and gas properties and fair values of derivative instruments and stock-based payment awards. Further, these estimates and other factors, including those outside of the Company’s control, such as the impact of lower commodity prices, may have a significant adverse impact to the Company’s business, financial condition, results of operations and cash flows.
Oil and Gas Properties	Oil and Gas Properties. 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, 2020 As of December 31, 2019 (in thousands) Proved properties $ 721,174 $ 725,964 Wells and related equipment and facilities 1,910,527 1,805,136 Support equipment and facilities 105,397 99,540 Materials and supplies 11,944 13,489 Total proved oil and gas properties $ 2,749,042 $ 2,644,129 Unproved properties 182,605 265,387 Wells and facilities in progress 60,704 92,406 Total unproved oil and gas properties, excluded from amortization $ 243,309 $ 357,793 Accumulated depreciation, depletion, amortization and impairment (2,224,428) (958,475) Total oil and gas properties, net $ 767,923 $ 2,043,447 The Company reviews proved 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 an analysis of quantitative and qualitative factors existing as of the balance sheet date including 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. 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, income taxes and various discount rates commensurate with the risk and current market conditions associated with realizing the projected cash flows. 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. In early 2020, global health care systems and economies began to experience strain from the spread of COVID-19, a highly transmissible and pathogenic coronavirus (the “COVID-19 pandemic”). As the virus spread, global economic activity began to slow and future economic activity was forecast to slow with a resulting decline in oil demand. In response, the Organization of Petroleum Exporting Countries (“OPEC”), along with non-OPEC oil-producing countries (collectively known as “OPEC+”), initiated discussions to lower production to support energy prices. With OPEC+ unable to agree on cuts, crude oil prices declined to an average of $30.45 per barrel for the month of March 2020, compared to an average of $59.80 per barrel for the month of December 2019. These events led to a decline in the recoverability of the carrying value of the Company’s oil and gas properties during the three months ended March 31, 2020. Since the carrying amount of the oil and gas properties was no longer recoverable, the Company impaired the carrying value to fair value. Therefore, the Company recognized non-cash impairment charges during the three months ended March 31, 2020, which were included within impairment and abandonment expense in the Unaudited Consolidated Statements of Operations. For the three months ended March 31, 2020, the Company contracted with an independent third party to assist the Company in the Company’s determination of fair value associated with the Company’s proved and unproved oil and gas properties. Through the use of the Company’s production and price forecast, the third party used the income valuation technique to assist the Company in the determination of fair value for the proved developed producing (“PDP”) and proved developed non-producing (“PDN”) reserves and a market approach utilizing sales prices of comparable properties to assist the Company in the determination of fair value of the proved undeveloped (“PUD”), probable (“PROB”) and possible (“POSS”) reserves. The Company’s impairment and abandonment expense for the three and six months ended June 30, 2020 and 2019 is summarized below: Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 (in thousands) Impairment of proved oil and gas properties $ — $ — $ 1,188,566 $ — Impairment of unproved oil and gas properties — — 76,298 — Abandonment expense 810 995 1,372 1,317 Total impairment and abandonment expense $ 810 $ 995 $ 1,266,236 $ 1,317
Accounts Payable and Accrued Liabilities	Accounts Payable and Accrued Liabilities. Accounts payable and accrued liabilities are comprised of the following: As of June 30, 2020 As of December 31, 2019 (in thousands) Accrued drilling, completion and facility costs $ 12,957 $ 25,667 Accrued lease operating, gathering, transportation and processing expenses 7,364 8,046 Accrued general and administrative expenses 6,910 6,612 Accrued interest payable 6,681 6,832 Trade payables 3,951 17,488 Operating lease liability 1,954 1,287 Other 2,260 5,706 Total accounts payable and accrued liabilities $ 42,077 $ 71,638
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. Under Wyoming law, the Company is exposed to potential obligations for plugging and abandoning wells, and associated reclamation, for assets that were sold to other industry parties in prior years. When such third parties are unable to fulfill their contractual obligations to the Company as provided for in purchase and sale agreements, landowners, as well as the Bureau of Land Management, may demand 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, 2020, the Company had open contracts with customers with terms of 1 month to 17 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 therefore are 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 were not 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. A valuation allowance is recorded if it is more likely than not that all or some portion of the Company’s deferred tax assets will not be realized. The Company regularly assesses the realizability of the deferred tax assets considering all positive and negative evidence, including scheduled reversals of deferred tax liabilities, projected future taxable income, planning strategies and results of recent operations. The assumptions about future taxable income require significant judgment to determine if a valuation allowance is required. Changes to the Company’s development plans, changes in market prices for hydrocarbons, changes in operating results, or other factors including changes in tax law could change the valuation allowance in future periods, resulting in recognition of a tax expense or 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, 2020.
Comprehensive Income	Comprehensive Income. The Company has no elements of other comprehensive income, therefore, the Company’s net income (loss) on the Unaudited Consolidated Statements of Operations represents comprehensive income.
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. The Company was in a net loss position for the three and six months ended June 30, 2020 and 2019; therefore, all potentially dilutive securities were anti-dilutive. 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, 2020 2019 2020 2019 (in thousands, except per share amounts) Net income (loss) $ (67,628) $ (1,910) $ (1,083,267) $ (98,139) Basic weighted-average common shares outstanding in period 211,895 210,377 211,503 210,156 Diluted weighted-average common shares outstanding in period 211,895 210,377 211,503 210,156 Basic net income (loss) per common share $ (0.32) $ (0.01) $ (5.12) $ (0.47) Diluted net income (loss) per common share $ (0.32) $ (0.01) $ (5.12) $ (0.47)
New Accounting Pronouncements	New Accounting Pronouncements. In April 2020, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2020-04, Facilitation of the Effects of Reference Rate Reform on Financial Reporting . In response to the cessation of the London Interbank Offered Rate (“LIBOR”) by December 31, 2022, the FASB issued this update to provide optional expedients and exceptions for applying GAAP to contracts, hedging relationships, and other affected transactions. The Company currently has only one contract, its credit facility, that may be impacted by this ASU. Modifications of debt contracts should be accounted for by prospectively adjusting the effective interest rate. This update has an effective period of March 12, 2020 through December 31, 2022 and allows for elections to be made by the Company in terms of how the ASU is adopted. Once elected for a Topic or Industry Subtopic, the update must be applied prospectively for all eligible contract modifications for that Topic or Industry Subtopic. The Company does not believe the standard will have a material impact on the Company’s financial statements. In August 2018, the FASB issued ASU 2018-13, Disclosure Framework-Changes to the Disclosure Requirements for Fair Value Measurement . The objective of this update is to improve the effectiveness of fair value measurement disclosures. ASU 2018-13 is effective for annual periods beginning after December 15, 2019 and interim periods within those annual periods. The standard was adopted on January 1, 2020 and did not have a material impact on the Company’s disclosures. In June 2016, the FASB issued ASU 2016-13, Financial Instruments, Credit Losses
Leases	A contract is or contains a lease when, (1) the contract contains an explicitly or implicitly identified asset and (2) the customer obtains substantially all of the economic benefits from the use of that underlying asset and directs how and for what purpose the asset is used during the term of the contract in exchange for consideration. The Company assesses whether an arrangement is or contains a lease at inception of the contract. For all leases, other than those that qualify for the short-term recognition exemption, the Company recognizes as of the lease commencement date on the balance sheet a liability for its obligation related to the lease and a corresponding asset representing the Company’s right to use the underlying asset over the period of use.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	6 Months Ended
	Jun. 30, 2020
Accounting Policies [Abstract]
Schedule of Accounts Receivable	Accounts receivable is comprised of the following: As of June 30, 2020 As of December 31, 2019 (in thousands) Oil, gas and NGL sales $ 32,383 $ 50,171 Due from joint interest owners (1) 23,796 9,551 Other 3,129 2,419 Allowance for doubtful accounts (31) (21) Total accounts receivable $ 59,277 $ 62,120
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, 2020 As of December 31, 2019 (in thousands) Proved properties $ 721,174 $ 725,964 Wells and related equipment and facilities 1,910,527 1,805,136 Support equipment and facilities 105,397 99,540 Materials and supplies 11,944 13,489 Total proved oil and gas properties $ 2,749,042 $ 2,644,129 Unproved properties 182,605 265,387 Wells and facilities in progress 60,704 92,406 Total unproved oil and gas properties, excluded from amortization $ 243,309 $ 357,793 Accumulated depreciation, depletion, amortization and impairment (2,224,428) (958,475) Total oil and gas properties, net $ 767,923 $ 2,043,447
Schedule Of Noncash Impairment Charges	The Company’s impairment and abandonment expense for the three and six months ended June 30, 2020 and 2019 is summarized below: Three Months Ended June 30, Six Months Ended June 30, 2020 2019 2020 2019 (in thousands) Impairment of proved oil and gas properties $ — $ — $ 1,188,566 $ — Impairment of unproved oil and gas properties — — 76,298 — Abandonment expense 810 995 1,372 1,317 Total impairment and abandonment expense $ 810 $ 995 $ 1,266,236 $ 1,317
Accounts Payable and Accrued Liabilities	Accounts payable and accrued liabilities are comprised of the following: As of June 30, 2020 As of December 31, 2019 (in thousands) Accrued drilling, completion and facility costs $ 12,957 $ 25,667 Accrued lease operating, gathering, transportation and processing expenses 7,364 8,046 Accrued general and administrative expenses 6,910 6,612 Accrued interest payable 6,681 6,832 Trade payables 3,951 17,488 Operating lease liability 1,954 1,287 Other 2,260 5,706 Total accounts payable and accrued liabilities $ 42,077 $ 71,638
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, 2020 2019 2020 2019 (in thousands, except per share amounts) Net income (loss) $ (67,628) $ (1,910) $ (1,083,267) $ (98,139) Basic weighted-average common shares outstanding in period 211,895 210,377 211,503 210,156 Diluted weighted-average common shares outstanding in period 211,895 210,377 211,503 210,156 Basic net income (loss) per common share $ (0.32) $ (0.01) $ (5.12) $ (0.47) Diluted net income (loss) per common share $ (0.32) $ (0.01) $ (5.12) $ (0.47)

Supplemental Disclosures of C_2

Supplemental Disclosures of Cash Flow Information (Tables)	6 Months Ended
	Jun. 30, 2020
Supplemental Cash Flow Elements [Abstract]
Supplemental Cash Flow Information	Supplemental cash flow information is as follows: Six Months Ended June 30, 2020 2019 (in thousands) Cash paid for interest $ 27,635 $ 26,689 Cash paid for income taxes — — Cash paid for amounts included in the measurements of lease liabilities: Cash paid for operating leases 873 595 Non-cash operating activities: Right-of-use assets obtained in exchange for lease obligations Operating leases (1)(2) 777 14,955 Non-cash investing and financing activities: Accounts payable and accrued liabilities - oil and gas properties 11,746 87,109 Change in asset retirement obligations, net of disposals (12) (5,022) Retirement of treasury stock (654) (1,506) Properties exchanged in non-cash transactions 4,753 4,561 (1) Excludes the reclassifications of lease incentives and deferred rent balances. (2) The six months ended June 30, 2019 included $14.0 million of right-of-use assets established with the adoption of ASC 842, Leases , effective January 1, 2019.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	6 Months Ended
	Jun. 30, 2020
Debt Disclosure [Abstract]
Outstanding Debt	The Company’s outstanding debt is summarized below: As of June 30, 2020 As of December 31, 2019 Maturity Date Principal Debt Issuance Costs Carrying Principal Debt Issuance Costs Carrying (in thousands) Amended Credit Facility September 14, 2023 $ 175,000 $ — $ 175,000 $ 140,000 $ — $ 140,000 7.0% Senior Notes October 15, 2022 350,000 (1,954) 348,046 350,000 (2,372) 347,628 8.75% Senior Notes June 15, 2025 275,000 (3,373) 271,627 275,000 (3,717) 271,283 Total Long-Term Debt $ 800,000 $ (5,327) $ 794,673 $ 765,000 $ (6,089) $ 758,911

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	6 Months Ended
	Jun. 30, 2020
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, 2020 is as follows (in thousands): As of December 31, 2019 $ 25,709 Liabilities incurred 488 Liabilities settled (766) Disposition of properties (143) Accretion expense 872 Revisions to estimate 409 As of June 30, 2020 $ 26,569 Less: Current asset retirement obligations 2,619 Long-term asset retirement obligations $ 23,950

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	6 Months Ended
	Jun. 30, 2020
Fair Value Disclosures [Abstract]
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, 2020 Financial Assets Deferred compensation plan $ 1,167 $ — $ — $ 1,167 Commodity derivatives — 91,150 — 91,150 Financial Liabilities Commodity derivatives — 3,368 — 3,368 As of December 31, 2019 Financial Assets Deferred compensation plan $ 2,033 $ — $ — $ 2,033 Commodity derivatives — 8,890 — 8,890 Financial Liabilities Commodity derivatives — 10,056 — 10,056
Fair Value, Assets Measured on Nonrecurring Basis, Level 3 Unobservable Inputs	The following table includes quantitative information about the significant unobservable inputs, categorized within Level 3 of the fair value hierarchy, that were used in the fair value measurement. Level 3 Unobservable Inputs As of March 31, 2020 Price (1) Oil (per Bbl) $29 to $60 Gas (per MMbtu) $2.03 to $2.52 NGL (percentage of oil price) 24% to 31% Reserve adjustment factors PDP 100% PDN 95% Discount rate 11% (1) These prices were adjusted for location and quality differentials.

Derivative Instruments (Tables)

Derivative Instruments (Tables)	6 Months Ended
	Jun. 30, 2020
Derivative Instruments and Hedging Activities Disclosures [Line Items]
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, 2020 Balance Sheet Gross Amounts of Gross Amounts Offset in the Balance Sheet (1) Net Amounts of (in thousands) Derivative assets (current) $ 73,466 $ (1,230) $ 72,236 Derivative assets (noncurrent) 17,684 (2,138) 15,546 Total derivative assets $ 91,150 $ (3,368) $ 87,782 Gross Amounts of Gross Amounts Offset in the Balance Sheet (1) Net Amounts of (in thousands) Accounts payable and accrued liabilities $ (1,230) $ 1,230 $ — Other noncurrent liabilities (2,138) 2,138 — Total derivative liabilities $ (3,368) $ 3,368 $ — As of December 31, 2019 Balance Sheet Gross Amounts of Gross Amounts Offset in the Balance Sheet (1) Net Amounts of (in thousands) Derivative assets (current) $ 8,477 $ (4,561) $ 3,916 Derivative assets (noncurrent) 413 (413) — Total derivative assets $ 8,890 $ (4,974) $ 3,916 Gross Amounts of Gross Amounts Offset in the Balance Sheet (1) Net Amounts of (in thousands) Accounts payable and accrued liabilities $ (8,972) $ 4,561 $ (4,411) Other noncurrent liabilities (1,084) 413 (671) Total derivative liabilities $ (10,056) $ 4,974 $ (5,082) (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, 2020, the Company had swap and swaption contracts in place to hedge the following volumes for the periods indicated: July – December 2020 For the year 2021 For the year 2022 Derivative Weighted Average Price Derivative Volumes Weighted Average Price Derivative Volumes Weighted Average Price Swaps Oil (Bbls) 2,760,000 $ 56.59 3,098,000 $ 54.30 — $ — Natural Gas (MMbtu) 3,680,000 $ 1.83 5,790,000 $ 2.13 — $ — Oil Roll Swaps (1) Oil (Bbls) 276,500 $ (1.47) — — — — Swaptions Oil (Bbls) — $ — — $ — 1,092,000 $ 55.08 (1) These contracts establish a fixed amount for the differential between the NYMEX WTI calendar month average and the physical crude oil delivery month. The weighted average differential represents the amount of reduction to NYMEX WTI prices for the notional volumes covered by the swap contracts.

Equity Incentive Compensation_2

Equity Incentive Compensation Plans and Other Long-term Incentive Programs (Tables)	6 Months Ended
	Jun. 30, 2020
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, 2020 2019 2020 2019 (in thousands) Nonvested common stock (1) $ 1,150 $ 1,533 $ 2,300 $ 3,329 Nonvested common stock units (1) 202 318 482 612 Nonvested performance cash units (2)(3) 198 445 (776) 1,077 Total $ 1,550 $ 2,296 $ 2,006 $ 5,018 (1) Unrecognized compensation expense as of June 30, 2020 was $5.1 million, which related to grants of nonvested shares of common stock that are expected to be recognized over a weighted-average period of 1.8 years. (2) The nonvested performance-based cash units are accounted for as liability awards with $0.3 million and $1.2 million in other noncurrent liabilities as of June 30, 2020 and December 31, 2019, respectively, in the Unaudited Consolidated Balance Sheets.
Nonvested Equity Shares
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, 2020 and 2019 is presented below: Three Months Ended June 30, 2020 Three Months Ended June 30, 2019 Nonvested Common Stock Awards Shares Weighted Average Shares Weighted Average Outstanding at April 1, 3,531,812 $ 2.10 3,431,780 $ 3.90 Granted — — 6,000 2.66 Vested (112,677) 4.26 (30,031) 5.81 Forfeited or expired (250,431) 1.52 (1,615) 7.14 Outstanding at June 30, 3,168,704 2.07 3,406,134 3.88 Six Months Ended June 30, 2020 Six Months Ended June 30, 2019 Nonvested Common Stock Awards Shares Weighted Average Shares Weighted Average Outstanding at January 1, 2,968,497 $ 3.81 2,912,166 $ 5.27 Granted 2,028,617 1.14 1,841,700 2.64 Vested (1,568,491) 4.25 (1,329,630) 5.20 Forfeited or expired (259,919) 1.59 (18,102) 4.96 Outstanding at June 30, 3,168,704 2.07 3,406,134 3.88
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, 2020 and 2019 is presented below: Three Months Ended June 30, 2020 Three Months Ended June 30, 2019 Nonvested Performance-Based Cash Unit Awards Units Weighted Average Units Weighted Average Outstanding at April 1, 6,096,230 2,868,634 Forfeited or expired (656,430) — Outstanding at June 30, 5,439,800 $ 0.30 2,868,634 $ 1.82 Six Months Ended June 30, 2020 Six Months Ended June 30, 2019 Nonvested Performance-Based Cash Unit Awards Units Weighted Average Units Weighted Average Outstanding at January 1, 2,576,062 909,585 Granted 3,569,434 2,026,521 Forfeited or expired (705,696) (67,472) Outstanding at June 30, 5,439,800 $ 0.30 2,868,634 $ 1.82
Director
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, 2020 and 2019 is presented below: Three Months Ended June 30, 2020 Three Months Ended June 30, 2019 Nonvested Common Stock Unit Awards Units Weighted Average Units Weighted Average Outstanding at April 1, 796,103 $ 3.27 311,237 $ 7.26 Granted 530,940 0.27 628,380 1.87 Vested (638,355) 2.63 (143,514) 5.77 Forfeited or expired (79,423) 0.25 — — Outstanding at June 30, 609,265 1.72 796,103 3.27 Six Months Ended June 30, 2020 Six Months Ended June 30, 2019 Nonvested Common Stock Unit Awards Units Weighted Average Units Weighted Average Outstanding at January 1, 796,103 $ 3.27 311,237 $ 7.26 Granted 530,940 0.27 643,084 1.88 Vested (638,355) 2.63 (158,218) 5.44 Forfeited or expired (79,423) 0.25 — — Outstanding at June 30, 609,265 1.72 796,103 3.27

Leases (Tables)

Leases (Tables)	6 Months Ended
	Jun. 30, 2020
Leases [Abstract]
Lease, Cost	For the three and six months ended June 30, 2020 and 2019, lease cost were as follows: Three Months Ended June 30, Six Months Ended June 30, Lease Cost 2020 2019 2020 2019 (in thousands) Operating lease cost (1)(3) $ 529 $ 569 $ 1,039 $ 1,117 Short-term lease cost (2)(3) 789 4,167 3,052 10,386 Variable lease cost (4) 373 — 693 — Total lease cost $ 1,691 $ 4,736 $ 4,784 $ 11,503 (1) Operating lease cost was primarily included in general and administrative expense or lease operating expense on the Unaudited Consolidated Statements of Operations. (2) Short-term lease cost primarily includes leases for drilling rigs, which were capitalized to property, plant and equipment on the Unaudited Consolidated Balance Sheets. (3) A portion of the operating lease cost and a majority of the short-term lease cost represent gross amounts that the Company was financially committed to pay. However, the Company recorded in the financial statements its proportionate share based on the Company’s working interest, which varies from property to property. (4) Variable lease cost is related to a gathering agreement and is included in oil, gas, and NGL production on the Unaudited Consolidated Statements of Operations.
Supplemental Balance Sheet Information, Leases	Supplemental balance sheet information related to leases as of June 30, 2020 and December 31, 2019, were as follows: Operating Leases As of June 30, 2020 As of December 31, 2019 (in thousands) Right-of-use assets (1) $ 9,906 $ 9,287 Accumulated amortization (2) (1,621) (1,142) Total right-of-use assets, net (3) $ 8,285 $ 8,145 Current lease liabilities (4) (1,954) (1,287) Noncurrent lease liabilities (5) (12,834) (13,195) Total lease liabilities (3) $ (14,788) $ (14,482) Weighted average remaining lease term Operating leases (in years) 7.3 7.8 Weighted average discount rate Operating leases 5.6 % 5.6 % (1) Included in furniture, equipment and other in the Unaudited Consolidated Balance Sheets. (2) Included in accumulated depreciation, depletion, amortization and impairment in the Unaudited Consolidated Balance Sheets. (3) The difference between the right-of-use assets and total lease liabilities is primarily related to lease incentives and deferred rent balances, which were required to be netted against the right-of-use assets as of the ASC 842 implementation date of January 1, 2019. (4) Included in accounts payable and accrued liabilities in the Unaudited Consolidated Balance Sheets. (5) Included in other noncurrent liabilities in the Unaudited Consolidated Balance Sheets.
Lessee, Operating Lease, Liability, Maturity	Maturities of lease liabilities as of June 30, 2020 and December 31, 2019 were as follows: As of June 30, 2020 As of December 31, 2019 (in thousands) 2020 $ 1,377 $ 2,056 2021 2,635 2,355 2022 2,324 2,044 2023 2,101 2,024 2024 2,078 2,078 Thereafter 7,576 7,577 Total $ 18,091 $ 18,134 Less: Interest (3,303) (3,652) Present value of lease liabilities $ 14,788 $ 14,482

Commitments and Contingencies (

Commitments and Contingencies (Tables)	6 Months Ended
	Jun. 30, 2020
Commitments and Contingencies Disclosure [Abstract]
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, 2020 (in thousands) 2020 $ 12,732 2021 19,777 2022 13,064 2023 14,600 2024 14,640 Thereafter 4,800 Total $ 79,613
Schedule Of Gross Future Minimum Volume Charges	The amounts in the table below represent the Company’s future minimum charges under both types of agreements: As of June 30, 2020 (in thousands) 2020 $ 1,089 2021 5,268 Thereafter — Total $ 6,357
Other Commitments	Future minimum annual payments under these agreements are as follows: As of June 30, 2020 (in thousands) 2020 $ 1,098 2021 1,285 2022 (1) 11,485 2023 (1) 16,285 Thereafter — Total $ 30,153

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Additional Information (Detail) $ in Millions	Jun. 30, 2020USD ($)
Property, Plant and Equipment [Line Items]
Accounts Receivable, Due from One Joint Interest Partner	$ 12.9

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Summary of Accounts Receivable (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Accounts, Notes, Loans and Financing Receivable [Line Items]
Allowance for doubtful accounts	$ (31)	$ (21)
Total accounts receivable	59,277	62,120
Oil, gas and NGL sales
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable gross	32,383	50,171
Due from joint interest owners (1)
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable gross	23,796	9,551
Other
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable gross	$ 3,129	$ 2,419

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Net Capitalized Costs and Associated Accumulated Depreciation, Depletion & Amortization and Non Cash Impairments (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Accounting Policies [Abstract]
Proved properties	$ 721,174	$ 725,964
Wells and related equipment and facilities	1,910,527	1,805,136
Support equipment and facilities	105,397	99,540
Materials and supplies	11,944	13,489
Total proved oil and gas properties	2,749,042	2,644,129
Unproved properties	182,605	265,387
Wells and facilities in progress	60,704	92,406
Total unproved oil and gas properties, excluded from amortization	243,309	357,793
Accumulated depreciation, depletion, amortization and impairment	(2,224,428)	(958,475)
Total oil and gas properties, net	$ 767,923	$ 2,043,447

Summary of Significant Accoun_7

Summary of Significant Accounting Policies - Non-cash Impairment Charges (Details) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Schedule of Non-cash Impairment Charges [Line Items]
Abandonment expense	$ 810		$ 995	$ 1,372	$ 1,317
Impairment and abandonment expense	810		995	1,266,236	1,317
Unproved Oil and Gas Properties
Schedule of Non-cash Impairment Charges [Line Items]
Impairment of Oil and Gas Properties	0	$ 76,300	0	76,298	0
Proved Oil and Gas Properties
Schedule of Non-cash Impairment Charges [Line Items]
Impairment of Oil and Gas Properties	$ 0	$ 1,200,000	$ 0	$ 1,188,566	$ 0

Summary of Significant Accoun_8

Summary of Significant Accounting Policies - Accounts Payable and Accrued Liabilities (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Accounting Policies [Abstract]
Accrued drilling, completion and facility costs	$ 12,957	$ 25,667
Accrued lease operating, gathering, transportation and processing expenses	7,364	8,046
Accrued general and administrative expenses	6,910	6,612
Accrued interest payable	6,681	6,832
Trade payables	3,951	17,488
Operating lease liability	1,954	1,287
Other	2,260	5,706
Total accounts payable and accrued liabilities	$ 42,077	$ 71,638

Summary of Significant Accoun_9

Summary of Significant Accounting Policies - Revenue Recognition (Details)	6 Months Ended
	Jun. 30, 2020
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	17 years

Summary of Significant Accou_10

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
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Accounting Policies [Abstract]
Net Income (Loss)	$ (67,628)	$ (1,910)	$ (1,083,267)	$ (98,139)
Basic weighted-average common shares outstanding in period (in shares)	211,894,790	210,377,152	211,503,310	210,155,678
Diluted weighted-average common shares outstanding in period (in shares)	211,894,790	210,377,152	211,503,310	210,155,678
Basic net income (loss) per common share (in dollars per share)	$ (0.32)	$ (0.01)	$ (5.12)	$ (0.47)
Diluted net income (loss) per common share (in dollars per share)	$ (0.32)	$ (0.01)	$ (5.12)	$ (0.47)

Supplemental Disclosures of C_3

Supplemental Disclosures of Cash Flow Information - Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019
Supplemental Cash Flow Information [Abstract]
Cash paid for interest	$ 27,635	$ 26,689
Cash paid for income taxes	0	0
Cash paid for operating leases	873	595
Non-cash operating activities:
Operating leases	777	14,955
Non-cash investing and financing activities:
Accounts payable and accrued liabilities - oil and gas properties	11,746	87,109
Change in asset retirement obligations, net of disposals	(12)	(5,022)
Retirement of treasury stock	(654)	(1,506)
Properties exchanged in non-cash transactions	$ 4,753	$ 4,561

Supplemental Disclosures of C_4

Supplemental Disclosures of Cash Flow Information - Additional Information (Details) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019	Jan. 01, 2019
Additional Cash Flow Elements and Supplemental Cash Flow Information [Abstract]
Right-of-use assets	$ 8,285	$ 8,145	$ 14,000

Long-Term Debt - Outstanding De

Long-Term Debt - Outstanding Debt (Detail) - USD ($)	6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Principal	$ 800,000,000		$ 765,000,000
Debt Issuance Costs	(5,327,000)		(6,089,000)
Carrying Amount	$ 794,673,000		758,911,000
Amended Credit Facility
Debt Instrument [Line Items]
Maturity Date	Sep. 14, 2023
Principal	$ 175,000,000		140,000,000
Debt Issuance Costs	0		0
Carrying Amount	175,000,000		140,000,000
Line of credit facility, maximum borrowing capacity	$ 300,000,000	$ 500,000,000
7.0% Senior Notes
Debt Instrument [Line Items]
Maturity Date	Oct. 15, 2022
Principal	$ 350,000,000		350,000,000
Debt Issuance Costs	(1,954,000)		(2,372,000)
Carrying Amount	$ 348,046,000		347,628,000
Debt, stated interest rate	7.00%
8.75% Senior Notes
Debt Instrument [Line Items]
Maturity Date	Jun. 15, 2025
Principal	$ 275,000,000		275,000,000
Debt Issuance Costs	(3,373,000)		(3,717,000)
Carrying Amount	$ 271,627,000		$ 271,283,000
Debt, stated interest rate	8.75%

Long-Term Debt - Additional Inf

Long-Term Debt - Additional Information (Detail) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Mar. 31, 2020	Dec. 31, 2019
Debt Instrument [Line Items]
Principal amount	$ 800,000,000		$ 800,000,000			$ 765,000,000
Weighted average interest rate	2.70%	4.20%	3.00%	4.10%
Minimum
Debt Instrument [Line Items]
Interest rate margin			2.50%
Revolving credit facility interest rate percent above LIBOR alternate interest rate			1.50%
Commitment fee percentage	0.50%		0.50%
Maximum
Debt Instrument [Line Items]
Interest rate margin			3.50%
Revolving credit facility interest rate percent above LIBOR alternate interest rate			2.50%
Amended Credit Facility
Debt Instrument [Line Items]
Debt instrument, maturity date			Sep. 14, 2023
Line of credit facility, maximum borrowing capacity	$ 300,000,000		$ 300,000,000		$ 500,000,000
Principal amount	175,000,000		175,000,000			$ 140,000,000
Letters of credit issued amount	21,700,000		21,700,000
Line of credit facility, remaining borrowing capacity	53,300,000		53,300,000
Permitted Debt Resulting in Accelerated Maturity Date	100,000,000		100,000,000
Line of Credit Facility, Required Availability under the Credit Facility	50,000,000		50,000,000
Line of Credit Facility, Maximum Weekly Cash Balance	$ 35,000,000		$ 35,000,000

Asset Retirement Obligations -

Asset Retirement Obligations - Schedule of Asset Retirement Obligations (Detail) $ in Thousands	6 Months Ended
	Jun. 30, 2020USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
As of December 31, 2019	$ 25,709
Liabilities incurred	488
Liabilities settled	(766)
Disposition of properties	(143)
Accretion expense	872
Revisions to estimate	409
As of June 30, 2020	26,569
Less: Current asset retirement obligations	2,619
Long-term asset retirement obligations	$ 23,950

Fair Value Measurements - Fair

Fair Value Measurements - Fair Value, Balance Sheet Grouping (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Financial Assets
Commodity derivatives	$ 87,782	$ 3,916
Financial Liabilities
Commodity derivatives	0	5,082
Total
Financial Assets
Deferred compensation plan	1,167	2,033
Commodity derivatives	91,150	8,890
Financial Liabilities
Commodity derivatives	3,368	10,056
Level 1
Financial Assets
Deferred compensation plan	1,167	2,033
Commodity derivatives	0	0
Financial Liabilities
Commodity derivatives	0	0
Level 2
Financial Assets
Deferred compensation plan	0	0
Commodity derivatives	91,150	8,890
Financial Liabilities
Commodity derivatives	3,368	10,056
Level 3
Financial Assets
Deferred compensation plan	0	0
Commodity derivatives	0	0
Financial Liabilities
Commodity derivatives	$ 0	$ 0

Fair Value Measures - Level 3 U

Fair Value Measures - Level 3 Unobservable Inputs (Details)	3 Months Ended
	Mar. 31, 2020
Fair Value Disclosures [Abstract]
Fair Value, Unobservable Input, Level 3, Oil Price Range	$29 to $60
Fair Value, Unobservable Input, Level 3, Gas Price Range	$2.03 to $2.52
Fair Value, Unobservable Input, Level 3, NGL Price Range, % of Oil Price	24% to 31%
Fair Value, Unobservable Input, Level 3, % of PDP Reserves Adjusted	1
Fair Value, Unobservable Input, Level 3, % of PDN Reserves Adjusted	0.95
Fair Value, Unobservable Input, Level 3, Discount Rate	0.11

Fair Value Measurements - Nonre

Fair Value Measurements - Nonrecurring (Details) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Fair Value Measurements [Line Items]
Proved Oil and Gas Properties, Carrying Value, Before Impairment		$ 1,700,000
Unproved Oil and Gas Properties, Net Book Value Prior to Impairment		256,000
Proved Oil and Gas Properties
Fair Value Measurements [Line Items]
Impairment of Oil and Gas Properties	$ 0	1,200,000	$ 0	$ 1,188,566	$ 0
Proved Oil and Gas Properties | Level 3
Fair Value Measurements [Line Items]
Oil and Gas Property, Successful Effort Method, Net		500,000
Unproved Oil and Gas Properties
Fair Value Measurements [Line Items]
Impairment of Oil and Gas Properties	$ 0	76,300	$ 0	$ 76,298	$ 0
Unproved Oil and Gas Properties | Level 3
Fair Value Measurements [Line Items]
Oil and Gas Property, Successful Effort Method, Net		$ 179,700

Fair Value Measurements - Addit

Fair Value Measurements - Additional Information (Detail) - USD ($)	3 Months Ended			6 Months Ended
	Jun. 30, 2020	Mar. 31, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Fair Value Measurements [Line Items]
Proved Oil and Gas Properties, Carrying Value, Before Impairment		$ 1,700,000,000
Principal amount	$ 800,000,000			$ 800,000,000		$ 765,000,000
7.0% Senior Notes
Fair Value Measurements [Line Items]
Debt, stated interest rate	7.00%			7.00%
Debt, fair value	$ 286,100,000			$ 286,100,000		335,000,000
Principal amount	$ 350,000,000			$ 350,000,000		350,000,000
8.75% Senior Notes
Fair Value Measurements [Line Items]
Debt, stated interest rate	8.75%			8.75%
Debt, fair value	$ 147,100,000			$ 147,100,000		251,200,000
Principal amount	275,000,000			275,000,000		275,000,000
Amended Credit Facility
Fair Value Measurements [Line Items]
Principal amount	175,000,000			175,000,000		$ 140,000,000
Proved Oil and Gas Properties
Fair Value Measurements [Line Items]
Impairment of Oil and Gas Properties	0	1,200,000,000	$ 0	1,188,566,000	$ 0
Unproved Oil and Gas Properties
Fair Value Measurements [Line Items]
Impairment of Oil and Gas Properties	$ 0	76,300,000	$ 0	$ 76,298,000	$ 0
Level 3 | Proved Oil and Gas Properties
Fair Value Measurements [Line Items]
Oil and Gas Property, Successful Effort Method, Net		500,000,000
Oil and Gas Property, Successful Effort Method, Net		500,000,000
Level 3 | Unproved Oil and Gas Properties
Fair Value Measurements [Line Items]
Oil and Gas Property, Successful Effort Method, Net		179,700,000
Oil and Gas Property, Successful Effort Method, Net		$ 179,700,000

Derivative Instruments - Fair V

Derivative Instruments - Fair Value Amounts of Derivative Instruments (Detail) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets	$ 91,150	$ 8,890
Gross Amounts Offset in the Balance Sheet (1)	(3,368)	(4,974)
Net Amounts of Assets Presented in the Balance Sheet	87,782	3,916
Gross Amounts of Recognized Liabilities	(3,368)	(10,056)
Gross Amounts Offset in the Balance Sheet (1)	3,368	4,974
Net Amounts of Liabilities Presented in the Balance Sheet	0	(5,082)
Derivative assets (current)
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets	73,466	8,477
Gross Amounts Offset in the Balance Sheet (1)	(1,230)	(4,561)
Net Amounts of Assets Presented in the Balance Sheet	72,236	3,916
Derivative assets (noncurrent)
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets	17,684	413
Gross Amounts Offset in the Balance Sheet (1)	(2,138)	(413)
Net Amounts of Assets Presented in the Balance Sheet	15,546	0
Accounts payable and accrued liabilities
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Liabilities	(1,230)	(8,972)
Gross Amounts Offset in the Balance Sheet (1)	1,230	4,561
Net Amounts of Liabilities Presented in the Balance Sheet	0	(4,411)
Other noncurrent liabilities
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Liabilities	(2,138)	(1,084)
Gross Amounts Offset in the Balance Sheet (1)	2,138	413
Net Amounts of Liabilities Presented in the Balance Sheet	$ 0	$ (671)

Derivative Instruments - Financ

Derivative Instruments - Financial Instruments for Hedging Volume (Detail)	Jun. 30, 2020$ / unitbbl
Derivative, Swap Type | Oil (Bbls) | July – December 2020
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	2,760,000
Weighted Average Price (usd per unit) | $ / unit	56.59
Derivative, Swap Type | Oil (Bbls) | For the year 2021
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	3,098,000
Weighted Average Price (usd per unit) | $ / unit	54.30
Derivative, Swap Type | Oil (Bbls) | For the year 2022
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	0
Weighted Average Price (usd per unit) | $ / unit	0
Derivative, Swap Type | Natural Gas (MMbtu) | July – December 2020
Derivative Instruments, Gain (Loss) [Line Items]
Weighted Average Price (usd per unit) | $ / unit	1.83
Hedge Backed Gas Volume | bbl	3,680,000
Derivative, Swap Type | Natural Gas (MMbtu) | For the year 2021
Derivative Instruments, Gain (Loss) [Line Items]
Weighted Average Price (usd per unit) | $ / unit	2.13
Hedge Backed Gas Volume | bbl	5,790,000
Derivative, Swap Type | Natural Gas (MMbtu) | For the year 2022
Derivative Instruments, Gain (Loss) [Line Items]
Weighted Average Price (usd per unit) | $ / unit	0
Hedge Backed Gas Volume | bbl	0
Derivative, Roll Swaps | Oil (Bbls) | July – December 2020
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	276,500
Weighted Average Price (usd per unit) | $ / unit	(1.47)
Derivative, Roll Swaps | Oil (Bbls) | For the year 2021
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	0
Weighted Average Price (usd per unit) | $ / unit	0
Derivative, Roll Swaps | Oil (Bbls) | For the year 2022
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	0
Weighted Average Price (usd per unit) | $ / unit	0
Swaption | Oil (Bbls) | July – December 2020
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	0
Weighted Average Price (usd per unit) | $ / unit	0
Swaption | Oil (Bbls) | For the year 2021
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	0
Weighted Average Price (usd per unit) | $ / unit	0
Swaption | Oil (Bbls) | For the year 2022
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	1,092,000
Weighted Average Price (usd per unit) | $ / unit	55.08

Derivative Instruments - Additi

Derivative Instruments - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2020counterparty
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Number of counterparties for hedges at period end	8

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Income Tax Disclosure [Abstract]
(Provision for) Benefit from Income Taxes	$ 0	$ (110)	$ 95,280	$ 29,601
Deferred income taxes	2,137		2,137		$ 97,418
Income Taxes Receivable	$ 1,400		$ 1,400

Equity Incentive Compensation_3

Equity Incentive Compensation Plans and Other Long-term Incentive Programs - Additional Information (Detail)	6 Months Ended
	Jun. 30, 2020$ / shares
Nonvested Equity Shares
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Award vesting period	3 years
Nonvested Equity Common Stock Units
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Award vesting period	1 year
Cash-Based Award
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Award vesting period	3 years
2020 Program [Member]
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Performance goal measurement period	3 years
Payout if absolute performance is 100%	100.00%
Relative TSR is less than 30%	30.00%
Payout if relative TSR is less than 30%	0.00%
Relative TSR is 30% or greater	30.00%
Payout if relative TSR is 30% or greater	100.00%
Closing Share Price, December 31, 2019	$ 1.69
2020 Program [Member] | 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 Compensation_4

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, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019	Dec. 31, 2019
Stock Based Compensation [Line Items]
Non-cash stock-based compensation equity awards	$ 1,550	$ 2,296	$ 2,006	$ 5,018
Unrecognized compensation expense	5,100		$ 5,100
Unrecognized compensation expense, recognition period			1 year 9 months 18 days
Nonvested Equity Shares
Stock Based Compensation [Line Items]
Non-cash stock-based compensation equity awards	1,150	1,533	$ 2,300	3,329
Nonvested Equity Common Stock Units
Stock Based Compensation [Line Items]
Non-cash stock-based compensation equity awards	202	318	482	612
Nonvested Performance Cash Units
Stock Based Compensation [Line Items]
Nonvested performance cash units	198	$ 445	(776)	$ 1,077
Nonvested performance-based cash units accounted for as liability awards	$ 300		$ 300		$ 1,200

Equity Incentive Compensation_5

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, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Nonvested Equity Shares
Units
Beginning balance (in shares)	3,531,812	3,431,780	2,968,497	2,912,166
Granted (in shares)	0	6,000	2,028,617	1,841,700
Vested (in shares)	(112,677)	(30,031)	(1,568,491)	(1,329,630)
Forfeited or expired (in shares)	(250,431)	(1,615)	(259,919)	(18,102)
Ending balance (in shares)	3,168,704	3,406,134	3,168,704	3,406,134
Weighted Average Grant Date Fair Value
Beginning balance (in dollars per share)	$ 2.10	$ 3.90	$ 3.81	$ 5.27
Granted (in dollars per share)	0	2.66	1.14	2.64
Vested (in dollars per share)	4.26	5.81	4.25	5.20
Forfeited or expired (in dollars per share)	1.52	7.14	1.59	4.96
Ending balance (in dollars per share)	$ 2.07	$ 3.88	$ 2.07	$ 3.88
Nonvested Performance Cash Units
Units
Beginning balance (in shares)	6,096,230	2,868,634	2,576,062	909,585
Granted (in shares)			3,569,434	2,026,521
Forfeited or expired (in shares)	(656,430)	0	(705,696)	(67,472)
Ending balance (in shares)	5,439,800	2,868,634	5,439,800	2,868,634
Weighted Average Grant Date Fair Value
Ending balance (in dollars per share)	$ 0.30	$ 1.82	$ 0.30	$ 1.82
Director
Units
Beginning balance (in shares)	796,103	311,237	796,103	311,237
Granted (in shares)	530,940	628,380	530,940	643,084
Vested (in shares)	(638,355)	(143,514)	(638,355)	(158,218)
Forfeited or expired (in shares)	(79,423)	0	(79,423)	0
Ending balance (in shares)	609,265	796,103	609,265	796,103
Weighted Average Grant Date Fair Value
Beginning balance (in dollars per share)	$ 3.27	$ 7.26	$ 3.27	$ 7.26
Granted (in dollars per share)	0.27	1.87	0.27	1.88
Vested (in dollars per share)	2.63	5.77	2.63	5.44
Forfeited or expired (in dollars per share)	0.25	0	0.25	0
Ending balance (in dollars per share)	$ 1.72	$ 3.27	$ 1.72	$ 3.27

Leases Additional Details (Deta

Leases Additional Details (Details)	Jun. 30, 2020
Leases [Abstract]
Term of contract	8 years

Leases Lease Cost (Details)

Leases Lease Cost (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2020	Jun. 30, 2019	Jun. 30, 2020	Jun. 30, 2019
Leases [Abstract]
Operating lease cost	$ 529	$ 569	$ 1,039	$ 1,117
Short-term lease cost	789	4,167	3,052	10,386
Variable Lease, Cost	373	0	693	0
Total lease cost	$ 1,691	$ 4,736	$ 4,784	$ 11,503

Leases Supplemental Balance She

Leases Supplemental Balance Sheet (Details) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019	Jan. 01, 2019
Leases [Abstract]
Right-of-use assets	$ 9,906	$ 9,287
Accumulated amortization	(1,621)	(1,142)
Total right-of-use assets, net	8,285	8,145	$ 14,000
Current lease liabilities	1,954	1,287
Noncurrent lease liabilities	12,834	13,195
Total lease liabilities	$ 14,788	$ 14,482
Weighted average remaining lease term
Operating leases (in years)	7 years 3 months 18 days	7 years 9 months 18 days
Weighted average discount rate
Operating leases	5.60%	5.60%

Leases Maturity (Details)

Leases Maturity (Details) - USD ($) $ in Thousands	Jun. 30, 2020	Dec. 31, 2019
Leases [Abstract]
2020	$ 1,377	$ 2,056
2021	2,635	2,355
2022	2,324	2,044
2023	2,101	2,024
2024	2,078	2,078
Thereafter	7,576	7,577
Total	18,091	18,134
Less: Interest	(3,303)	(3,652)
Present value of lease liabilities	$ 14,788	$ 14,482

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Detail) a in Thousands, $ in Millions	6 Months Ended
	Jun. 30, 2020USD ($)aagreementinteger
Commitments and Contingencies Disclosure [Abstract]
Number of firm transportation contracts | agreement	2
Number of firm pipeline transportation contracts	1
Minimum volume commitment	1
Number of reimbursement obligations	2
Number of other commitments	2
Number of Drilling Commitments	1
Number of Wells Due by July 2022	2
Number of Wells Due by July 2023	3
Acreage to be Assigned if Drilling Commitment Not Met | a	13
Drilling Commitment Due 2022 | $	$ 10.2
Drilling Commitment Due 2023 | $	$ 15.3

Commitments and Contingencies_2

Commitments and Contingencies - Gross Future Minimum Transportation Demand and Firm Processing Charges (Detail) $ in Thousands	Jun. 30, 2020USD ($)
Commitments and Contingencies Disclosure [Abstract]
2020	$ 12,732
2021	19,777
2022	13,064
2023	14,600
2024	14,640
Thereafter	4,800
Total	$ 79,613

Commitments and Contingencies C

Commitments and Contingencies Commitments And Contingencies - Gross Future Minimum Volume Charges (Details) $ in Thousands	Jun. 30, 2020USD ($)
Commitments and Contingencies - Gross Future Minimum Volume Charges [Abstract]
2020	$ 1,089
2021	5,268
Thereafter	0
Total	$ 6,357

Commitments and Contingencies_3

Commitments and Contingencies - Other Commitments (Detail) $ in Thousands	Jun. 30, 2020USD ($)
Commitments and Contingencies Disclosure [Abstract]
2020	$ 1,098
2021	1,285
2022	11,485
2023	16,285
Thereafter	0
Total	$ 30,153