10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

þ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2019

OR

o TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission file number 333-222275

HighPoint Resources Corporation

(Exact name of registrant as specified in its charter)

Delaware	82-3620361
(State or other jurisdiction of incorporation or organization)	(IRS Employer Identification No.)

555 17th Street, Suite 3700 Denver, Colorado	80202
(Address of principal executive offices)	(Zip Code)

(303) 293-9100

(Registrant's telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:
Title of each class	Trading Symbol	Name of each exchange on which registered
Common stock, $0.001 par value	HPR	New York Stock Exchange

Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.    þ  Yes    o  No

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).    þ  Yes    o  No

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Large accelerated filer	o	Accelerated filer	þ
Non-accelerated filer	o	Smaller reporting company	o
		Emerging growth company	o

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).    o  Yes    þ  No

There were 213,761,384 shares of $0.001 par value common stock outstanding on April 22, 2019.

INDEX TO FINANCIAL STATEMENTS

PART I. FINANCIAL INFORMATION
Item 1.	Consolidated Financial Statements (Unaudited)	3
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	27
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	36
Item 4.	Controls and Procedures	37
PART II. OTHER INFORMATION
Item 1.	Legal Proceedings	37
Item 1A.	Risk Factors	37
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	38
Item 3.	Defaults Upon Senior Securities	38
Item 4.	Mine Safety Disclosures	38
Item 5.	Other Information	38
Item 6.	Exhibits	38
SIGNATURES		40

2

PART I. FINANCIAL INFORMATION

Item 1. Consolidated Financial Statements.

HIGHPOINT RESOURCES CORPORATION

CONSOLIDATED BALANCE SHEETS

(UNAUDITED)

	March 31, 2019			December 31, 2018
	(in thousands, except share data)
Assets:
Current Assets:
Cash and cash equivalents	$	44,658		$	32,774
Accounts receivable, net of allowance for doubtful accounts	57,473			72,943
Derivative assets	1,419			81,166
Prepayments and other current assets	3,495			2,898
Total current assets	107,045			189,781
Property and equipment - at cost, successful efforts method for oil and gas properties:
Proved oil and gas properties	2,296,671			2,195,310
Unproved oil and gas properties, excluded from amortization	490,868			468,208
Furniture, equipment and other	29,675			20,662
	2,817,214			2,684,180
Accumulated depreciation, depletion, amortization and impairment	(721,054		)	(654,657		)
Total property and equipment, net	2,096,160			2,029,523
Derivative assets	3,939			27,289
Other noncurrent assets	5,392			5,867
Total	$	2,212,536		$	2,252,460
Liabilities and Stockholders' Equity:
Current Liabilities:
Accounts payable and accrued liabilities	$	135,762		$	131,379
Amounts payable to oil and gas property owners	44,886			55,792
Production taxes payable	63,257			59,155
Derivative liabilities	5,850			—
Current portion of long-term debt	—			1,859
Total current liabilities	249,755			248,185
Long-term debt, net of debt issuance costs	687,768			617,387
Asset retirement obligations	27,324			27,330
Deferred income taxes	109,823			139,534
Other noncurrent liabilities	21,391			7,926
Commitments and contingencies (Note 12)
Stockholders' Equity:
Common stock, $0.001 par value; authorized 400,000,000 shares; 213,761,384 and 212,477,101 shares issued and outstanding at March 31, 2019 and December 31, 2018, respectively, with 3,431,780 and 2,912,166 shares subject to restrictions, respectively	210			210
Additional paid-in capital	1,772,336			1,771,730
Retained earnings (accumulated deficit)	(656,071		)	(559,842		)
Treasury stock, at cost: zero shares at March 31, 2019 and December 31, 2018	—			—
Total stockholders' equity	1,116,475			1,212,098
Total	$	2,212,536		$	2,252,460

See notes to Unaudited Consolidated Financial Statements.

3

HIGHPOINT RESOURCES CORPORATION

CONSOLIDATED STATEMENTS OF OPERATIONS

(UNAUDITED)

	Three Months Ended March 31,
	2019			2018
	(in thousands, except share and per share data)
Operating Revenues:
Oil, gas and NGL production	$	101,705		$	80,831
Other operating revenues, net	275			(21		)
Total operating revenues	101,980			80,810
Operating Expenses:
Lease operating expense	11,277			6,251
Gathering, transportation and processing expense	1,723			419
Production tax expense	3,893			5,175
Exploration expense	25			13
Impairment, dry hole costs and abandonment expense	322			317
(Gain) loss on sale of properties	(5		)	408
Depreciation, depletion and amortization	72,610			40,985
Unused commitments	4,469			4,538
General and administrative expense	12,660			10,107
Merger transaction expense	2,414			4,763
Other operating expenses, net	(24		)	39
Total operating expenses	109,364			73,015
Operating Income (Loss)	(7,384		)	7,795
Other Income and Expense:
Interest and other income	314			691
Interest expense	(13,679		)	(13,090		)
Commodity derivative gain (loss)	(105,191		)	(20,333		)
Total other income and expense	(118,556		)	(32,732		)
Income (Loss) before Income Taxes	(125,940		)	(24,937		)
(Provision for) Benefit from Income Taxes	29,711			—
Net Income (Loss)	$	(96,229	)	$	(24,937	)
Net Income (Loss) Per Common Share, Basic	$	(0.46	)	$	(0.20	)
Net Income (Loss) Per Common Share, Diluted	$	(0.46	)	$	(0.20	)
Weighted Average Common Shares Outstanding, Basic	209,931,744			123,595,553
Weighted Average Common Shares Outstanding, Diluted	209,931,744			123,595,553

See notes to Unaudited Consolidated Financial Statements.

4

HIGHPOINT RESOURCES CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS

(UNAUDITED)

	Three Months Ended March 31,
	2019			2018
	(in thousands)
Operating Activities:
Net Income (Loss)	$	(96,229	)	$	(24,937	)
Adjustments to reconcile to net cash provided by operations:
Depreciation, depletion and amortization	72,610			40,985
Deferred income taxes	(29,711		)	—
Impairment, dry hole costs and abandonment expense	322			317
Commodity derivative (gain) loss	105,191			20,333
Settlements of commodity derivatives	4,649			(8,388		)
Stock compensation and other non-cash charges	4,318			835
Amortization of deferred financing costs	640			563
(Gain) loss on sale of properties	(5		)	408
Change in operating assets and liabilities:
Accounts receivable	15,470			9,166
Prepayments and other assets	(72		)	(111		)
Accounts payable, accrued and other liabilities	7,304			822
Amounts payable to oil and gas property owners	(10,906		)	9,609
Production taxes payable	4,102			4,715
Net cash provided by (used in) operating activities	77,683			54,317
Investing Activities:
Additions to oil and gas properties, including acquisitions	(130,862		)	(88,854		)
Additions of furniture, equipment and other	(1,309		)	(122		)
Repayment of debt associated with merger, net of cash acquired	—			(53,357		)
Other investing activities	(273		)	(157		)
Net cash provided by (used in) investing activities	(132,444		)	(142,490		)
Financing Activities:
Proceeds from debt	70,000			—
Principal payments on debt	(1,859		)	(116		)
Other financing activities	(1,496		)	(1,485		)
Net cash provided by (used in) financing activities	66,645			(1,601		)
Increase (Decrease) in Cash and Cash Equivalents	11,884			(89,774		)
Beginning Cash and Cash Equivalents	32,774			314,466
Ending Cash and Cash Equivalents	$	44,658		$	224,692

See notes to Unaudited Consolidated Financial Statements.

5

HIGHPOINT RESOURCES CORPORATION

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY

(UNAUDITED)

(In thousands)

	Common Stock		Additional Paid-In Capital			Retained Earnings (Accumulated Deficit)			Treasury Stock			Total Stockholders' Equity
Balance at December 31, 2017	$	109	$	1,279,507		$	(681,062	)	$	—		$	598,554
Restricted stock activity and shares exchanged for tax withholding	—		—			—			(1,462		)	(1,462		)
Stock-based compensation	—		4,185			—			—			4,185
Retirement of treasury stock	—		(1,462		)	—			1,462			—
Issuance of common stock, merger	100		483,900			—			—			484,000
Net income (loss)	—		—			(24,937		)	—			(24,937		)
Balance at March 31, 2018	$	209	$	1,766,130		$	(705,999	)	$	—		$	1,060,340
Restricted stock activity and shares exchanged for tax withholding	—		—			—			(28		)	(28		)
Stock-based compensation	—		1,797			—			—			1,797
Retirement of treasury stock	—		(28		)	—			28			—
Net income (loss)	—		—			(46,906		)	—			(46,906		)
Balance at June 30, 2018	$	209	$	1,767,899		$	(752,905	)	$	—		$	1,015,203
Restricted stock activity and shares exchanged for tax withholding	1		—			—			(43		)	(42		)
Stock-based compensation	—		1,996			—			—			1,996
Retirement of treasury stock	—		(43		)	—			43			—
Net income (loss)	—		—			(29,360		)	—			(29,360		)
Balance at September 30, 2018	$	210	$	1,769,852		$	(782,265	)	$	—		$	987,797
Restricted stock activity and shares exchanged for tax withholding	—		—			—			(2		)	(2		)
Stock-based compensation	—		1,880			—			—			1,880
Retirement of treasury stock	—		(2		)	—			2			—
Net income (loss)	—		—			222,423			—			222,423
Balance at December 31, 2018	$	210	$	1,771,730		$	(559,842	)	$	—		$	1,212,098
Restricted stock activity and shares exchanged for tax withholding	—		—			—			(1,484		)	(1,484		)
Stock-based compensation	—		2,090			—			—			2,090
Retirement of treasury stock	—		(1,484		)	—			1,484			—
Net income (loss)	—		—			(96,229		)	—			(96,229		)
Balance at March 31, 2019	$	210	$	1,772,336		$	(656,071	)	$	—		$	1,116,475

See notes to Unaudited Consolidated Financial Statements.

6

HIGHPOINT RESOURCES CORPORATION

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

March 31, 2019

1. Organization

HighPoint Resources Corporation, a Delaware corporation, together with its wholly-owned subsidiary (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.

2. 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, 2018 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 possible impairments of oil and gas properties and the amount of future capital costs used in these calculations. Assumptions, judgments and estimates also are required in determining the fair values of assets acquired and liabilities assumed in business combinations, asset retirement obligations, right-of-use assets and lease liabilities, deferred tax assets, 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.

Accounts Receivable. Accounts receivable is comprised of the following:

	As of March 31, 2019			As of December 31, 2018
	(in thousands)
Oil, gas and NGL sales	$	45,626		$	44,860
Due from joint interest owners	10,543			27,435
Other	1,410			754
Allowance for doubtful accounts	(106		)	(106		)
Total accounts receivable	$	57,473		$	72,943

7

Oil and Gas Properties. The Company's oil, gas and NGL exploration and production activities are accounted for using the successful efforts method. Under this method, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether the well has found proved reserves. If an exploratory well does not find proved reserves, the costs of drilling the well are charged to expense and remain within cash flows from investing activities in the Unaudited Consolidated Statements of Cash Flows. If an exploratory well does find proved reserves, the costs remain capitalized and are included within additions to oil and gas properties and remain within cash flows from investing activities in the Unaudited Consolidated Statements of Cash Flows. The costs of development wells are capitalized whether proved reserves are added or not. Oil and gas lease acquisition costs are also capitalized. Upon sale or retirement of depreciable or depletable property, the cost and related accumulated DD&A are eliminated from the accounts and the resulting gain or loss is recognized.

Other exploration costs, including certain geological and geophysical expenses and delay rentals for oil and gas leases, are charged to expense as incurred. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the unit-of-production amortization rate. Maintenance and repairs are charged to expense, and renewals and betterments are capitalized to the appropriate property and equipment accounts.

Unproved oil and gas property costs are transferred to proved oil and gas properties if the properties are subsequently determined to be productive or are assigned proved reserves. Proceeds from sales of partial interests in unproved leases are accounted for as a recovery of cost without recognizing any gain until all costs are recovered. Unproved oil and gas properties are assessed periodically for impairment based on remaining lease terms, drilling results, reservoir performance, commodity price outlooks, future plans to develop acreage, recent sales prices of comparable properties and other relevant matters.

Materials and supplies consist primarily of tubular goods and well equipment to be used in future drilling operations or repair operations and are carried at the lower of cost or market value.

The following table sets forth the net capitalized costs and associated accumulated DD&A and non-cash impairments relating to the Company's oil, natural gas and NGL producing activities:

	As of March 31, 2019			As of December 31, 2018
	(in thousands)
Proved properties	$	667,346		$	663,485
Wells and related equipment and facilities	1,518,824			1,438,092
Support equipment and facilities	88,901			75,392
Materials and supplies	21,600			18,341
Total proved oil and gas properties	$	2,296,671		$	2,195,310
Unproved properties	328,377			328,409
Wells and facilities in progress	162,491			139,799
Total unproved oil and gas properties, excluded from amortization	$	490,868		$	468,208
Accumulated depreciation, depletion, amortization and impairment	(714,237		)	(642,645		)
Total oil and gas properties, net	$	2,073,302		$	2,020,873

The Company reviews oil and natural gas properties for impairment on a quarterly basis or whenever events and circumstances indicate that a decline in the recoverability of their carrying value may have occurred. The Company estimates the expected undiscounted future net cash flows of its oil and gas properties using proved and risked probable and possible reserves based on the Company's development plans and best estimate of future production, commodity pricing, reserve risking, gathering and transportation deductions, production tax rates, lease operating expenses and future development costs. The Company compares such undiscounted future net cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the undiscounted future net cash flows exceed the carrying amount of the oil and gas properties, no impairment is taken. If the carrying amount of a property exceeds the undiscounted future net cash flows, the Company will impair the carrying value to fair value based on an analysis of quantitative and qualitative factors existing as of the balance sheet date. The factors used to determine fair value may include, but are not limited to, recent sales prices of comparable properties, indications from marketing activities, the present value of future revenues, net of estimated operating and development costs using estimates of reserves, future commodity pricing, future production estimates, anticipated capital expenditures and various discount rates commensurate with the risk and current market conditions associated with realizing the projected cash flows.

8

The provision for DD&A of oil and gas properties is calculated on a field-by-field basis using the unit-of-production method. Natural gas and NGLs are converted to an oil equivalent, Boe, at the standard rate of six Mcf to one Boe and forty-two gallons to one Boe, respectively. Estimated future dismantlement, restoration and abandonment costs are taken into consideration by this calculation.

Accounts Payable and Other Accrued Liabilities. Accounts payable and other accrued liabilities are comprised of the following:

	As of March 31, 2019		As of December 31, 2018
	(in thousands)
Accrued drilling, completion and facility costs	$	92,905	$	69,830
Accrued lease operating, gathering, transportation and processing expenses	7,308		6,970
Accrued general and administrative expenses	6,513		8,774
Accrued interest payable	18,930		6,758
Accrued merger transaction expenses	682		550
Prepayments from partners	794		862
Trade payables	1,192		31,057
Operating lease liability	517		—
Other	6,921		6,578
Total accounts payable and other accrued liabilities	$	135,762	$	131,379

Environmental Liabilities. Environmental expenditures that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation are expensed. Environmental liabilities are accrued when environmental assessments and/or clean-ups are probable, and the costs can be reasonably estimated. Recent case law in Wyoming has exposed the Company 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 March 31, 2019, the Company had open contracts with customers with terms of 1 month to 19 years, as well as evergreen contracts that renew on a periodic basis if not canceled by the Company or the customer. The Company's contracts with customers typically require payment within one month of delivery.

Under the Company's contracts with customers, natural gas and its components, including NGLs, are either sold to a midstream entity (which processes the natural gas and subsequently sells the resulting residue gas and NGLs) or are sold to a gas or NGL purchaser after being processed by a third party for a fee. Regardless of the contract structure type, the terms of these contracts compensate the Company for the value of the residue gas and NGLs at current market prices for each product. The Company's oil is sold to multiple oil purchasers at specific delivery points at or near the wellhead. All costs incurred to gather, transport and/or process the Company's oil, gas and NGLs after control has transferred to the customer are considered components of the consideration received from the customer and thus recorded in oil, gas and NGL production revenues in the Unaudited Consolidated Statements of Operations. All costs incurred prior to the transfer of control to the customer are included in gathering, transportation and processing expense in the Unaudited Consolidated Statements of Operations.

Gas imbalances from the sale of natural gas are recorded on the basis of gas actually sold by the Company. If the Company's aggregate sales volumes for a well are greater (or less) than its proportionate share of production from the well, a liability (or receivable) is established to the extent there are insufficient proved reserves available to make-up the overproduced (or underproduced) imbalance. Imbalances have not been significant in the periods presented.

9

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, increases in market prices for hydrocarbons, improvements in operating results, or other factors 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 March 31, 2019.

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. As the Company was in a net loss position, all potentially dilutive securities were anti-dilutive for the three months ended March 31, 2019 and 2018.

The following table sets forth the calculation of basic and diluted income (loss) per share:

	Three Months Ended March 31,
	2019			2018
	(in thousands, except per share amounts)
Net income (loss)	$	(96,229	)	$	(24,937	)
Basic weighted-average common shares outstanding in period	209,932			123,596
Diluted weighted-average common shares outstanding in period	209,932			123,596
Basic net income (loss) per common share	$	(0.46	)	$	(0.20	)
Diluted net income (loss) per common share	$	(0.46	)	$	(0.20	)

New Accounting Pronouncements. In August 2018, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("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 will only impact the Company's disclosures.

In June 2018, the FASB issued ASU 2018-07, Stock Compensation-Improvements to Non-employee Share-Based Payment Accounting. The objective of this update was to simplify several aspects of the accounting for non-employee share-based payment transactions resulting from expanding the scope of Topic 718, Compensation- Stock Compensation, to include share-based payment transactions for acquiring goods and services from non-employees. ASU 2018-07 was effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods. The standard was adopted on January 1, 2019 and did not have a material impact on the Company's disclosures and financial statements.

10

In February 2016, the FASB issued ASU 2016-02, Leases, followed by additional accounting standards updates that provided additional practical expedients and policy election options (collectively, Accounting Standards Codification Topic 842 ("ASC 842")). The objective of ASC 842 was to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclose key information about leasing arrangements. ASC 842 was effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods. The Company adopted ASC 842 effective January 1, 2019 using the modified retrospective method and elected the option to not apply ASC 842 to comparative periods. The Company also elected the following practical expedients:

• not to recognize lease assets or liabilities on the balance sheet when lease terms are less than 12 months,

• carryforward previous conclusions related to current lease classification under the previous lease accounting standard to lease classification for these existing leases under ASC 842,

• exclude from evaluation under ASC 842 land easements that existed or expired before adoption of ASC 842, and

• to combine lease and non-lease components for certain asset classes.

The adoption of ASC 842 resulted in the recognition of right-of-use assets of $8.6 million, and current and noncurrent lease liabilities of $0.3 million and $13.7 million, respectively, on the Unaudited Consolidated Balance Sheet as of January 1, 2019. The difference between the right-of-use assets and the total lease liability was related to lease incentives and deferred rent balances of $5.4 million, which were required to be netted against the right-of-use assets as of the implementation date of January 1, 2019. The Company's leases included office leases and other equipment, all classified as operating leases. The adoption of ASC 842 had no impact on the Company's Unaudited Consolidated Statements of Operations or Cash Flows. See Note 11 for additional information.

3. Supplemental Disclosures of Cash Flow Information

Supplemental cash flow information is as follows:

	Three Months Ended March 31,
	2019			2018
	(in thousands)
Cash paid for interest	$	868		$	395
Cash paid for income taxes	—			—
Cash paid for amounts included in the measurements of lease liabilities:
Operating cash flows from operating leases	229			—
Non-cash operating activities:
Right-of-use assets obtained in exchange for lease obligations
Operating leases (1)	14,667			—
Non-cash investing and financing activities:
Accrued liabilities - oil and gas properties	92,702			67,047
Change in asset retirement obligations, net of disposals	933			7,513
Retirement of treasury stock	(1,484		)	(1,462		)
Issuance of common stock for Merger	—			484,000

(1) Excludes the reclassifications of lease incentives and deferred rent balances.

4. Merger

2018 Merger with Fifth Creek Energy Operating Company, LLC

On March 19, 2018, the Company completed the Merger with Fifth Creek. The Merger was effected through the issuance of 100 million shares of the Company's common stock, with a fair value of $484.0 million on the date of closing, and the repayment of $53.9 million of Fifth Creek debt. In connection with the Merger, the Company incurred costs of $19.2 million of severance, consulting, advisory, legal and other merger-related fees, all of which were expensed and included in merger transaction expense in the Company's Consolidated Statements of Operations.

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Purchase Price Allocation

The transaction was accounted for as a business combination, using the acquisition method, with the Company being the acquirer for accounting purposes. The following table represents the allocation of the total purchase price to the identifiable assets acquired and the liabilities assumed based on the estimated fair values at the acquisition date. The following table sets forth the Company's purchase price allocation:

	March 19, 2018
	(in thousands)
Purchase Price:
Fair value of common stock issued	$	484,000
Plus: Repayment of Fifth Creek debt	53,900
Total purchase price	537,900
Plus Liabilities Assumed:
Accounts payable and accrued liabilities	25,782
Current unfavorable contract	2,651
Other current liabilities	13,797
Asset retirement obligations	7,361
Long-term deferred tax liability	137,707
Long-term unfavorable contract	4,449
Other noncurrent liabilities	2,354
Total purchase price plus liabilities assumed	$	732,001
Fair Value of Assets Acquired:
Cash	543
Accounts receivable	7,831
Oil and Gas Properties:
Proved oil and gas properties	105,702
Unproved oil and gas properties	609,568
Asset retirement obligations	7,361
Furniture, equipment and other	931
Other noncurrent assets	65
Total asset value	$	732,001

The fair value measurements of oil and natural gas properties and asset retirement obligations are based on inputs that are not observable in the market and therefore represent Level 3 inputs. The fair values of proved oil and natural gas properties and asset retirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of oil and natural gas properties included estimates of: (i) recoverable reserves; (ii) production rates; (iii) future operating and development costs; (iv) future commodity prices; and (v) a market-based weighted average cost of capital rate. The fair value of unproved properties was determined using a market approach utilizing recent transactions of a similar nature in the same basin. These inputs required significant judgments and estimates by management at the time of the valuation and are the most sensitive to possible future changes.

The results of operations attributable to the merged companies are included in the Consolidated Statements of Operations beginning on March 19, 2018. The Company generated revenues of approximately $2.1 million and expenses of approximately $1.8 million from the Fifth Creek assets during the period March 19, 2018 to March 31, 2018.

Pro Forma Financial Information

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The following pro forma condensed combined financial information was derived from the historical financial statements of the Company and Fifth Creek and gives effect to the acquisition as if it had occurred on January 1, 2018. The below information reflects pro forma adjustments based on available information and certain assumptions that the Company believes are reasonable, including (i) the repayment of Fifth Creek's debt, (ii) depletion of Fifth Creek's fair-valued proved crude oil and natural gas properties, and (iii) the estimated tax impacts of the pro forma adjustments.

Additionally, pro forma earnings for the three months ended March 31, 2019 and 2018 were adjusted to exclude merger-related costs of $2.4 million and $4.8 million, respectively, incurred by the Company and zero and $4.0 million, respectively, incurred by Fifth Creek. The pro forma results of operations do not include any cost savings or other synergies that may have occurred as a result of the acquisition or any estimated costs that have been incurred by the Company to integrate the Fifth Creek assets. The pro forma condensed combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the acquisition taken place on January 1, 2018; furthermore, the financial information is not intended to be a projection of future results.

	Three Months Ended March 31,
	2019			2018
	(in thousands, except per share data)
Revenues	$	101,980		$	96,742
Net Income (Loss)	(93,815		)	(24,104		)
Net Income (Loss) per Common Share, Basic	(0.45		)	(0.12		)
Net Income (Loss) per Common Share, Diluted	(0.45		)	(0.12		)

5. Long-Term Debt

The Company's outstanding debt is summarized below:

		As of March 31, 2019							As of December 31, 2018
	Maturity Date	Principal		Debt Issuance Costs			Carrying Amount		Principal		Debt Issuance Costs			Carrying Amount
		(in thousands)
Amended Credit Facility (1)	September 14, 2023	$	70,000	$	—		$	70,000	$	—	$	—		$	—
7.0% Senior Notes (2)	October 15, 2022	350,000		(3,000		)	347,000		350,000		(3,210		)	346,790
8.75% Senior Notes (3)	June 15, 2025	275,000		(4,232		)	270,768		275,000		(4,403		)	270,597
Lease Financing Obligation (4)	August 10, 2020	—		—			—		1,859		—			1,859
Total Debt		$	695,000	$	(7,232	)	$	687,768	$	626,859	$	(7,613	)	$	619,246
Less: Current Portion of Long-Term Debt (5)		—		—			—		1,859		—			1,859
Total Long-Term Debt		$	695,000	$	(7,232	)	$	687,768	$	625,000	$	(7,613	)	$	617,387

(1) The recorded value of the Amended Credit Facility approximates its fair value due to its floating rate structure and on financing terms currently available to the Company.

(2) The aggregate estimated fair value of the 7.0% Senior Notes was approximately $332.7 million and $329.7 million as of March 31, 2019 and December 31, 2018, respectively, based on reported market trades of these instruments.

(3) The aggregate estimated fair value of the 8.75% Senior Notes was approximately $263.3 million and $264.7 million as of March 31, 2019 and December 31, 2018, respectively, based on reported market trades of these instruments.

(4) The aggregate estimated fair value of the Lease Financing Obligation was approximately $1.8 million as of December 31, 2018, based on market-based parameters of comparable term secured financing instruments. The Company exercised the early buyout option and purchased the equipment for $1.8 million on February 10, 2019.

(5) As of December 31, 2018, the current portion of long-term debt included the Lease Financing Obligation, which was settled on February 10, 2019.

Amended Credit Facility

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The Company's revolving bank credit facility (the "Amended Credit Facility"), has a maturity date of September 14, 2023, a maximum credit amount of $1.5 billion, an initial elected commitment amount of $500.0 million and an initial borrowing base of $500.0 million. The Company had $70.0 million and zero outstanding under the Amended Credit Facility as of March 31, 2019 and December 31, 2018, respectively. As credit support for future payments under a contractual obligation, a $26.0 million letter of credit has been issued under the Amended Credit Facility, which reduced the available borrowing capacity under the Amended Credit Facility as of March 31, 2019 to $404.0 million.

Interest rates are either adjusted LIBOR plus applicable margins of 1.5% to 2.5% or an alternate base rate plus applicable margins of 0.5% to 1.5%, and the unused commitment fee is between 0.375% and 0.5%. The applicable margin 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 4.0% for the three months ended March 31, 2019.

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). Pursuant to supplemental indentures entered into in connection with the Merger, HighPoint Resources Corporation became a guarantor of the 7.0% Senior Notes and the 8.75% Senior Notes in March 2018. All covenants in the indentures governing the notes limit the activities of HighPoint Operating Corporation, including limitations on the ability to pay dividends, incur additional indebtedness, make restricted payments, create liens, sell assets or make loans to HighPoint Resources Corporation, but in most cases the covenants in the indentures are not applicable to HighPoint Resources Corporation. HighPoint Operating Corporation is currently in compliance with all covenants and has complied with all covenants since issuance.

Nothing in the indentures governing the 7.0% Senior Notes or the 8.75% Senior Notes prohibits the Company from repurchasing any of the notes from time to time at any price in open market purchases, negotiated transactions or by tender offer or otherwise without any notice to or consent of the holders.

Lease Financing Obligation Due 2020

The Company had a lease financing obligation with a balance of $1.9 million as of December 31, 2018 resulting from the Company's sale and subsequent lease back of certain compressors and related facilities owned by the Company (the "Lease Financing Obligation"). The Company elected to exercise the early buyout option and purchased the equipment for $1.8 million on February 10, 2019.

6. Asset Retirement Obligations

A reconciliation of the Company's asset retirement obligations for the three months ended March 31, 2019 is as follows (in thousands):

As of December 31, 2018	$	29,655
Liabilities incurred	864
Liabilities settled	(258		)
Disposition of properties	(73		)
Accretion expense	384
Revisions to estimate	400
As of March 31, 2019	$	30,972
Less: Current asset retirement obligations	3,648
Long-term asset retirement obligations	$	27,324

7. 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).

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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 consolidated balance sheet. The following methods and assumptions were used to estimate the fair values:

Cash equivalents – The highly liquid cash equivalents are recorded at fair value. Carrying value approximates fair value, which represents a Level 1 input.

Deferred compensation plan – The Company maintains a non-qualified deferred compensation plan which allows certain management employees to defer receipt of a portion of their compensation. The Company maintains assets for the deferred compensation plan in a rabbi trust. The assets of the rabbi trust are invested in publicly traded mutual funds and are recorded in other current and other long-term assets in the Unaudited Consolidated Balance Sheets. The deferred compensation plan financial assets are reported at fair value based on active market quotes, which represent Level 1 inputs.

Commodity derivatives – The fair value of crude oil, natural gas and NGL swaps and costless 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. At times, the Company 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.

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	Level 1		Level 2		Level 3		Total
	(in thousands)
As of March 31, 2019
Financial Assets
Cash equivalents	$	37,762	$	—	$	—	$	37,762
Deferred compensation plan	1,679		—		—		1,679
Commodity derivatives	—		15,431		—		15,431
Financial Liabilities
Commodity derivatives	—		16,817		—		16,817
As of December 31, 2018
Financial Assets
Cash equivalents	12,188		—		—		12,188
Deferred compensation plan	1,392		—		—		1,392
Commodity derivatives	—		109,494		—		109,494
Financial Liabilities
Commodity derivatives	—		1,039		—		1,039

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 –Oil and gas property costs are evaluated for impairment and reduced to fair value when there is an indication that the carrying costs may not be recoverable. If an impairment is necessary, the fair value is estimated by using either a market approach based on recent sales prices of comparable properties and/or indications from marketing activities or by using the income valuation technique, which involves calculating the present value of future net revenues. The present value, net of estimated operating and development costs, is calculated using estimates of reserves, future commodity pricing, future production estimates, anticipated capital expenditures and various discount rates commensurate with the risk and current market conditions associated with realizing the projected cash flows, predominantly all of which are designated as Level 3 inputs within the fair value hierarchy. No properties were reduced to fair value during either of the three month periods ended March 31, 2019 and 2018.

Additional Fair Value Disclosures

Long-term Debt – Long-term debt is not presented at fair value on the Unaudited Consolidated Balance Sheets, as it is recorded at carrying value, net of unamortized debt issuance costs. The fair values of the Company's fixed rate 7.0% Senior Notes and 8.75% Senior Notes totaled $596.0 million and $594.4 million as of March 31, 2019 and December 31, 2018, respectively. The fair values of the Company's fixed rate Senior Notes are based on active market quotes, which represent Level 1 inputs.

There is no active, public market for the Amended Credit Facility. The recorded value of the Amended Credit Facility approximates its fair value due to its floating rate structure based on the LIBOR spread, secured interest, and the Company's borrowing base utilization. The Amended Credit Facility had a balance of $70.0 million as of March 31, 2019 and zero as of December 31, 2018. The fair value measurements for the Amended Credit Facility represent Level 2 inputs.

8. Derivative Instruments

The Company uses financial derivative instruments as part of its price risk management program to achieve a more predictable cash flow from its production revenues by reducing its exposure to commodity price fluctuations. The Company has entered into financial commodity swap contracts and costless collars related to the sale of a portion of the Company's production. The Company does not enter into derivative instruments for speculative or trading purposes.

In addition to financial contracts, the Company may at times be party to various physical commodity contracts for the sale of oil, natural gas and NGLs that have varying terms and pricing provisions. These physical commodity contracts qualify for the normal purchase and normal sale exception and, therefore, are not subject to hedge or mark-to-market accounting. The

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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 March 31, 2019
Balance Sheet	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet				Net Amounts of Assets Presented in the Balance Sheet
	(in thousands)
Derivative assets (current)	$	9,815		$	(8,396	)	(1)	$	1,419
Derivative assets (noncurrent)	5,616			(1,677		)	(1)	3,939
Total derivative assets	$	15,431		$	(10,073	)		$	5,358
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet				Net Amounts of Liabilities Presented in the Balance Sheet
	(in thousands)
Derivative liabilities	$	(14,246	)	$	8,396		(1)	$	(5,850	)
Other noncurrent liabilities	(2,571		)	1,677			(1)	(894		)
Total derivative liabilities	$	(16,817	)	$	10,073			$	(6,744	)
	As of December 31, 2018
Balance Sheet	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet				Net Amounts of Assets Presented in the Balance Sheet
	(in thousands)
Derivative assets (current)	$	82,205		$	(1,039	)	(1)	$	81,166
Derivative assets (noncurrent)	27,289			—			(1)	27,289
Total derivative assets	$	109,494		$	(1,039	)		$	108,455
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet				Net Amounts of Liabilities Presented in the Balance Sheet
	(in thousands)
Derivative liabilities	$	(1,039	)	$	1,039		(1)	$	—
Other noncurrent liabilities	—			—			(1)	—
Total derivative liabilities	$	(1,039	)	$	1,039			$	—

(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 March 31, 2019, the Company had swap contracts in place to hedge the following volumes for the periods indicated:

	April – December 2019			For the year 2020
	Derivative Volumes	Weighted Average Price		Derivative Volumes	Weighted Average Price
Oil (Bbls)	4,646,533	$	59.07	4,024,000	$	59.42
Natural Gas (MMbtu)	1,925,000	$	2.11	—	$	—

As of March 31, 2019, the Company had cashless collars (purchased put options and written call options) in place to hedge the following volumes for the periods indicated:

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	April – December 2019
	Derivative Volumes	Weighted Average Floor Price		Weighted Average Ceiling Price
Oil (Bbls)	552,000	$	55.00	$	77.56

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 10 different counterparties as of March 31, 2019. 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.

9. 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 months ended March 31, 2019 and 2018, 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 months ended March 31, 2019 and 2018.

Income tax benefit for the three months ended March 31, 2019 and 2018 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 the effect of deferred tax asset valuation allowances, stock-based compensation, political lobbying expense, political contributions, nondeductible officer compensation and state income taxes. For the three months ended March 31, 2019 the Company recognized $29.7 million of income tax benefit. No income tax expense or benefit was recognized for the three months ended March 31, 2018 as a result of recording a full valuation allowance against the deferred tax asset balance. 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. 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.

10. 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.

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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 March 31,
	2019		2018
	(in thousands)
Nonvested common stock (1)	$	1,796	$	1,330
Nonvested common stock units (1)	294		170
Nonvested performance cash units (2)(3)	632		(73		)
Total	$	2,722	$	1,427

(1) Unrecognized compensation expense as of March 31, 2019 was $11.2 million, which related to grants of nonvested shares of common stock that are expected to be recognized over a weighted-average period of 2.1 years.

(2) The nonvested performance-based cash units are accounted for as liability awards with $1.0 million and $0.3 million in other noncurrent liabilities as of March 31, 2019 and December 31, 2018, 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 months ended March 31, 2019 and 2018 is presented below:

	Three Months Ended March 31, 2019				Three Months Ended March 31, 2018
Nonvested Common Stock Awards	Shares		Weighted Average Grant Date Fair Value		Shares		Weighted Average Grant Date Fair Value
Outstanding at January 1,	2,912,166		$	5.27	1,394,868		$	7.00
Granted	1,835,700		2.64		796,423		5.00
Modified (1)	—		—		1,146,305		4.84
Vested	(1,299,599	)	5.19		(652,208	)	8.35
Forfeited or expired	(16,487	)	4.74		(27,853	)	6.62
Outstanding at March 31,	3,431,780		3.90		2,657,535		5.14

(1) Due to the closing of the Merger, the 2016 and 2017 Performance Cash Programs were converted from nonvested performance-based cash units to nonvested common stock awards, resulting in an increase in nonvested common stock awards for the three months ended March 31, 2018.

A summary of the Company's nonvested common stock unit awards for the three months ended March 31, 2019 and 2018 is presented below:

	Three Months Ended March 31, 2019				Three Months Ended March 31, 2018
Nonvested Common Stock Unit Awards	Units		Weighted Average Grant Date Fair Value		Units		Weighted Average Grant Date Fair Value
Outstanding at January 1,	311,237		$	7.26	272,559		$	6.37
Granted	14,704		2.21		3,198		5.08
Vested	(14,704	)	2.21		(3,198	)	5.08
Outstanding at March 31,	311,237		7.26		272,559		6.37

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A summary of the Company's nonvested performance-based cash unit awards for the three months ended March 31, 2019 and 2018 is presented below:

	Three Months Ended March 31, 2019				Three Months Ended March 31, 2018
Nonvested Performance-Based Cash Unit Awards	Units		Weighted Average Fair Value		Units		Weighted Average Fair Value
Outstanding at January 1,	909,585				1,548,083
Granted	2,026,521				796,423
Performance goal adjustment (1)	—				11,289
Modified (2)	—				(1,211,478	)
Vested	—				(286,652	)
Forfeited or expired	(67,472	)			(61,242	)
Outstanding at March 31,	2,868,634		$	2.21	796,423		$	5.08

(1) The 2015 Program vested at 104.1% in excess of target level and resulted in additional units vesting in March 2018. These units are included in the vested line item for the three months ended March 31, 2018.

(2) Due to the closing of the Merger, the 2016 and 2017 Performance Cash Programs were converted from nonvested performance-based cash units to nonvested common stock awards, resulting in a decrease in nonvested performance-based cash units for the three months ended March 31, 2018. The 2016 Program awards were converted based on performance through March 19, 2018, which resulted in 89% of the units converting to nonvested common stock awards or a reduction of 65,173 units converting to nonvested common stock awards.

Performance Cash Program

2019 Program. In February 2019, the Compensation Committee of the Board of Directors of the Company approved a performance cash program (the "2019 Program") granting performance cash units that will settle in cash and are accounted for as liability awards. The performance-based awards contingently vest in February 2022, depending on the level at which the performance goal is achieved. The performance goal, which will be measured over the three-year period ending December 31, 2021, will be the Company's total shareholder return ("TSR") based on a matrix measurement of (1) the Company's absolute performance and (2) the Company's ranking relative to a defined peer group's individual TSRs ("Relative TSR"). The Company's absolute performance is measured against the December 31, 2018 closing share price of $2.49. If the Company's absolute performance is less than 50%, the payout is zero. If the Company's absolute performance is 50%, the payout is 50%. If the Company's absolute performance is 100%, the payout is 100%, which is the maximum payout for this portion. If the Company's Relative TSR is less than 30%, the payout is zero. If the Company's Relative TSR is 30% or greater, the payout is equal to the Company's percentile rank up to 100% of the original grant. The Company's combined absolute performance and Relative TSR have a maximum vest of up to 200% of the original grant.

11. Leases

The Company adopted ASC 842 effective January 1, 2019 using the modified retrospective method and elected the option to not apply ASC 842 to comparative periods. See Note 2 - New Accounting Pronouncements for the impacts of adopting this new standard.

The Company currently has leases for office space and other equipment, all classified as operating leases. Under ASC 842, 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's leases have remaining terms of up to nine 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.

20

The discount rate used to calculate the present value of the future minimum lease payments is the rate implicit in the lease, when readily determinable. As most of the Company's leases do not provide an implicit rate, the Company utilizes its incremental borrowing rate.

The Company has 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, the Company recognizes the lease payments in the income statement on a straight-line basis over the lease term. The Company has also made the election, for certain classes of underlying assets, to combine lease and non-lease components. However, for the majority of its leases, the Company accounts for lease and non-lease components separately.

For the three months ended March 31, 2019, lease cost was as follows:

	Three Months Ended March 31,
Lease Cost	2019
	(in thousands)
Operating lease cost (1)(3)	$	548
Short-term lease cost (2)(3)	6,219
Total lease cost	$	6,767

(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.

Supplemental balance sheet information related to leases as of March 31, 2019, was as follows:

Operating Leases	As of March 31, 2019
	(in thousands)
Right-of-use assets (1)	$	9,255
Accumulated amortization (2)	(352		)
Total right-of-use assets (5)	$	8,903
Current lease liabilities (3)	(517		)
Noncurrent lease liabilities (4)	(14,117		)
Total lease liabilities (5)	$	(14,634	)
Weighted average remaining lease term
Operating leases (in years)	8.4
Weighted average discount rate
Operating leases	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) Included in accounts payable and accrued liabilities in the Unaudited Consolidated Balance Sheets.

(4) Included in other noncurrent liabilities in the Unaudited Consolidated Balance Sheets.

(5) The difference between the right-of-use assets and total lease liabilities was primarily related to lease incentives and deferred rent balances, which were required to be netted against the right-of-use assets as of the implementation date of January 1, 2019.

Maturities of lease liabilities as of March 31, 2019 were as follows:

21

	As of March 31, 2019
	(in thousands)
2019	$	1,026
2020	1,938
2021	2,230
2022	1,992
2023	2,024
Thereafter	9,654
Total	$	18,864
Less: Interest	(4,230		)
Present value of lease liabilities	$	14,634

Minimum future contractual payments for operating leases under the scope of ASC 840 as of December 31, 2018 were as follows:

	As of December 31, 2018
	(in thousands)
2019	$	2,583
2020	3,032
2021	3,331
2022	3,263
2023	3,036
Thereafter	13,112
Total	$	28,357

12. Commitments and Contingencies

Firm Transportation Agreements. The Company is party to two firm transportation contracts, through July 2021, to provide capacity on natural gas pipeline systems. The contracts require the Company to pay transportation charges regardless of the amount of pipeline capacity utilized by the Company. These monthly transportation payments are included in unused commitments expense in the Unaudited Consolidated Statements of Operations. As a result of previous divestitures in 2013 and 2014, the Company will likely not utilize the firm capacity on the natural gas pipelines.

The amounts in the table below represent the Company's future minimum transportation charges:

	As of March 31, 2019
	(in thousands)
2019	$	13,206
2020	18,400
2021	10,733
Thereafter	—
Total	$	42,339

Gas Gathering and Processing Agreements. The Company is party to one minimum volume commitment and one reimbursement obligation. 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 obligation requires the Company to pay a monthly gathering and processing fee per Mcf of production over a one year period to reimburse a midstream entity for its costs to construct gas gathering and processing facilities. If the costs are not reimbursed by the Company via the monthly gathering and processing fees through August 2019, the Company must pay the difference. The amounts in the table below represent the Company's future minimum charges under both agreements:

22

	As of March 31, 2019
	(in thousands)
2019 (1)	$	8,275
2020	2,167
2021	1,997
Thereafter	—
Total	$	12,439

(1) Includes $6.5 million associated with the reimbursement obligation discussed above.

Other Commitments. The Company is party to one minimum volume commitment for fresh water. The minimum volume commitment requires the Company to purchase a minimum volume of fresh water from a water supplier. The contract requires the Company to pay a fee associated with the contracted volumes regardless of the amount delivered. The Company also has non-cancellable agreements for information technology and geological and geophysical services. Future minimum annual payments under these agreements are as follows:

	As of March 31, 2019
	(in thousands)
2019	$	4,453
2020	1,490
2021	745
2022	745
2023	744
Thereafter	—
Total	$	8,177

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.

13. Parent Guarantor

The condensed consolidating financial information as of and for the periods ended March 31, 2019 and 2018 presents the results of operations, financial position and cash flows of HighPoint Resources Corporation, or parent guarantor, and HighPoint Operating Corporation (f/k/a Bill Barrett), or subsidiary issuer, as well as the consolidating adjustments necessary to present HighPoint Resources Corporation's results on a consolidated basis. The parent guarantor fully and unconditionally guarantees the debt securities of the subsidiary issuer. The indentures governing those securities limit the ability of the subsidiary issuer to pay dividends or otherwise provide funding to the parent guarantor.

For the purpose of the following financial information, investments in subsidiaries are reflected in accordance with the equity method of accounting. The financial information may not necessarily be indicative of results of operations, cash flows, or financial position had the parent and the subsidiary operated as independent entities.

Condensed Consolidating Balance Sheets

23

	As of March 31, 2019
	Parent Guarantor		Subsidiary Issuer		Intercompany Eliminations			Consolidated
	(in thousands)
Assets:
Cash and cash equivalents	$	—	$	44,658	$	—		$	44,658
Accounts receivable, net of allowance for doubtful accounts	—		57,473		—			57,473
Other current assets	—		4,914		—			4,914
Property and equipment, net	—		2,096,160		—			2,096,160
Investment in subsidiaries	1,116,475		—		(1,116,475		)	—
Noncurrent assets	—		9,331		—			9,331
Total assets	$	1,116,475	$	2,212,536	$	(1,116,475	)	$	2,212,536
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	$	—	$	135,762	$	—		$	135,762
Other current liabilities	—		113,993		—			113,993
Long-term debt	—		687,768		—			687,768
Deferred income taxes	—		109,823		—			109,823
Other noncurrent liabilities	—		48,715		—			48,715
Stockholders' equity	1,116,475		1,116,475		(1,116,475		)	1,116,475
Total liabilities and stockholders' equity	$	1,116,475	$	2,212,536	$	(1,116,475	)	$	2,212,536

	As of December 31, 2018
	Parent Guarantor		Subsidiary Issuer		Intercompany Eliminations			Consolidated
	(in thousands)
Assets:
Cash and cash equivalents	$	—	$	32,774	$	—		$	32,774
Accounts receivable, net of allowance for doubtful accounts	—		72,943		—			72,943
Other current assets	—		84,064		—			84,064
Property and equipment, net	—		2,029,523		—			2,029,523
Investment in subsidiaries	1,212,098		—		(1,212,098		)	—
Noncurrent assets	—		33,156		—			33,156
Total assets	$	1,212,098	$	2,252,460	$	(1,212,098	)	$	2,252,460
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	$	—	$	131,379	$	—		$	131,379
Other current liabilities	—		116,806		—			116,806
Long-term debt	—		617,387		—			617,387
Deferred income taxes	—		139,534		—			139,534
Other noncurrent liabilities	—		35,256		—			35,256
Stockholders' equity	1,212,098		1,212,098		(1,212,098		)	1,212,098
Total liabilities and stockholders' equity	$	1,212,098	$	2,252,460	$	(1,212,098	)	$	2,252,460

24

Condensed Consolidating Statements of Operations

	Three Months Ended March 31, 2019
	Parent Guarantor			Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Operating and other revenues	$	—		$	101,980		$	—	$	101,980
Operating expenses	—			(94,290		)	—		(94,290		)
General and administrative	—			(12,660		)	—		(12,660		)
Merger transaction expense	—			(2,414		)	—		(2,414		)
Interest expense	—			(13,679		)	—		(13,679		)
Interest income and other income (expense)	—			(104,877		)	—		(104,877		)
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	—			(125,940		)	—		(125,940		)
(Provision for) benefit from income taxes	—			29,711			—		29,711
Equity in earnings (loss) of subsidiaries	(96,229		)	—			96,229		—
Net income (loss)	$	(96,229	)	$	(96,229	)	$	96,229	$	(96,229	)

	Three Months Ended March 31, 2018
	Parent Guarantor			Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Operating and other revenues	$	—		$	80,810		$	—	$	80,810
Operating expenses	—			(58,145		)	—		(58,145		)
General and administrative	—			(10,107		)	—		(10,107		)
Merger transaction expense	—			(4,763		)	—		(4,763		)
Interest expense	—			(13,090		)	—		(13,090		)
Interest income and other income (expense)	—			(19,642		)	—		(19,642		)
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	—			(24,937		)	—		(24,937		)
(Provision for) benefit from income taxes	—			—			—		—
Equity in earnings (loss) of subsidiaries	(24,937		)	—			24,937		—
Net income (loss)	$	(24,937	)	$	(24,937	)	$	24,937	$	(24,937	)

25

Condensed Consolidating Statements of Cash Flows

	Three Months Ended March 31, 2019
	Parent Guarantor		Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Cash flows from operating activities	$	—	$	77,683		$	—	$	77,683
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	—		(130,862		)	—		(130,862		)
Additions to furniture, fixtures and other	—		(1,309		)	—		(1,309		)
Other investing activities	—		(273		)	—		(273		)
Cash flows from financing activities:
Proceeds from debt	—		70,000			—		70,000
Principal payments on debt	—		(1,859		)	—		(1,859		)
Other financing activities	—		(1,496		)	—		(1,496		)
Change in cash and cash equivalents	—		11,884			—		11,884
Beginning cash and cash equivalents	—		32,774			—		32,774
Ending cash and cash equivalents	$	—	$	44,658		$	—	$	44,658

	Three Months Ended March 31, 2018
	Parent Guarantor		Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Cash flows from operating activities	$	—	$	54,317		$	—	$	54,317
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	—		(88,854		)	—		(88,854		)
Additions to furniture, fixtures and other	—		(122		)	—		(122		)
Payment of acquiree's debt associated with merger, net of cash acquired	—		(53,357		)	—		(53,357		)
Other investing activities	—		(157		)	—		(157		)
Cash flows from financing activities:
Principal payments on debt	—		(116		)	—		(116		)
Other financing activities	—		(1,485		)	—		(1,485		)
Change in cash and cash equivalents	—		(89,774		)	—		(89,774		)
Beginning cash and cash equivalents	—		314,466			—		314,466
Ending cash and cash equivalents	$	—	$	224,692		$	—	$	224,692

26

Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

This Quarterly Report on Form 10-Q contains "forward-looking statements" within the meaning of Section 27A of the Securities Act of 1933, as amended, Section 21E of the Securities Exchange Act of 1934, as amended, and the Private Securities Litigation Reform Act of 1995. Forward-looking statements include statements as to future plans, estimates, beliefs and expected performance of HighPoint Resources Corporation. Forward-looking statements are dependent upon events, risks and uncertainties that may be outside our control. Our actual results could differ materially from those discussed in these forward-looking statements. Factors that could cause or contribute to such differences include, but are not limited to, risks and uncertainties relating to:

• legislative, judicial or regulatory changes including initiatives to impose increased setbacks from occupied structures and other sensitive areas, initiatives to give local governmental authorities the ability to further regulate or to ban oil and gas development activities within their boundaries, and initiatives related to drilling and completion techniques such as hydraulic fracturing;

• potential failure to achieve expected production from existing and future exploration or development projects or acquisitions;

• volatility of market prices received for oil, natural gas and natural gas liquids ("NGLs"), and the risk of a prolonged period of depressed prices;

• declines in the values of our oil and natural gas properties resulting in impairments;

• reduction of proved undeveloped reserves due to failure to develop within the five-year development window defined by the Securities and Exchange Commission;

• derivative and hedging activities;

• the concentration of our properties in the Rocky Mountain region;

• compliance with environmental and other regulations;

• economic and competitive conditions;

• occurrence of property divestitures or acquisitions;

• costs and availability of third party facilities for gathering, processing, refining and transportation;

• future processing volumes and pipeline throughput;

• impact of health and safety issues on operations;

• operational risks, including the risk of industrial accidents and natural disasters;

• reductions in the borrowing base under our amended revolving credit facility (the "Amended Credit Facility");

• debt and equity market conditions and availability of capital;

• ability to receive drilling and other permits, regulatory approvals and required surface access and rights of way;

• higher than expected costs and expenses including production, drilling and well equipment costs;

• changes in estimates of proved reserves;

• the potential for production decline rates from our wells, and/or drilling and related costs, to be greater than we expect;

• ability to replace natural production declines with acquisitions, new drilling or recompletion activities;

• exploration risks such as the risk of drilling unsuccessful wells;

• capital expenditures and contractual obligations;

• liabilities resulting from litigation concerning alleged damages related to environmental issues, pollution, contamination, personal injury, royalties, marketing, title to properties, validity of leases, or other matters that may not be covered by an effective indemnity or insurance;

• midstream capacity issues;

• changes in tax laws and statutory tax rates; and

• other uncertainties, including those factors discussed below and in our Annual Report on Form 10-K for the year ended December 31, 2018 under the headings "Cautionary Note Regarding Forward-Looking Statements" and "Risk Factors" and in Part II, Item 1A, "Risk Factors" of this Quarterly Report on Form 10-Q, all of which are difficult to predict.

In light of these risks, uncertainties and assumptions, the forward-looking events discussed may not occur. Readers should not place undue reliance on these forward-looking statements, which reflect management's views only as of the date hereof. Other than as required under the securities laws, we do not undertake any obligation to update any forward-looking statements whether as a result of changes in internal estimates or expectations, new information, subsequent events or circumstances or otherwise.

Overview

27

We develop oil and natural gas in the Rocky Mountain region of the United States. We seek to build stockholder value by delivering profitable growth in cash flow, reserves and production through the development of oil and natural gas assets. In order to deliver profitable growth, we allocate capital to our highest return assets, concentrate expenditures on exploiting our core assets, maintain capital discipline and optimize operations while upholding high-level standards for health, safety and the environment. Substantially all of our revenues are generated through the sale of oil and natural gas production and NGL recovery at market prices.

Colorado Senate Bill 19-181 was signed into law on April 16, 2019, and it applies to operations occurring on and after that date. It authorizes local governments to approve the siting of and regulate the surface impacts from oil and natural gas development, and it empowers them to adopt requirements and impose conditions more stringent than state regulations. The statute changes the mission of the Colorado Oil and Gas Conservation Commission from fostering responsible and balanced development to regulating development to protect public health and the environment. It creates a new regulatory standard that requires the Commission to protect and minimize adverse impacts to public health and the environment and that omits references to cost effectiveness and technical feasibility. It requires the appointment of an interim nine member Commission with only one member (down from three) with industry experience. No later than July 2020, the Commission will transform into a five member full-time professional commission, including one member with industry expertise. The statute changes spacing and compulsory pooling requirements. It directs the Commission to undertake rulemaking on environmental protection, facility siting, cumulative impacts, flowlines, wells that are inactive, temporarily abandoned, or shut-in, financial assurance, wellbore integrity, and application fees. It also requires the Air Quality Control Commission to review its leak detection and repair rules and to adopt rules to further minimize emissions of hydrocarbons, volatile organic compounds, and nitrogen oxides. These rulemakings may create new approval and operating requirements; such requirements are unlikely to take effect until 2020. Senate Bill 19-181 and related rulemakings may have an adverse effect on our operations in certain respects, particularly in terms of costs and possible delays in the permitting process. However, we believe that the location of our assets in rural areas of Weld County, a jurisdiction generally supportive of oil and gas development, is likely to mitigate these impacts to a significant extent given the emphasis in the statute on increased local control of regulatory matters. 

We are committed to developing and producing oil and natural gas in a responsible and safe manner. Our employees work diligently with regulatory agencies, as well as environmental, wildlife and community organizations, to ensure that exploration and development activities meet stakeholders' expectations and regulatory requirements.

Future acquisitions or dispositions could have a material impact on our financial condition and results of operations by increasing or decreasing our reserves, production and revenues as well as expenses and future capital expenditures. We currently anticipate that we would finance any future acquisitions with available borrowings under our Amended Credit Facility, sales of properties, and/or the issuance of debt, equity or equity-linked securities. Our prior acquisitions and capital expenditures were financed with a combination of cash on hand, funding from the sale of our equity securities, our Amended Credit Facility, other debt financing and cash flows from operations.

As a result of acquisitions and dispositions of properties, our historical results of operations and period-to-period comparisons of these results and certain financial data may not be meaningful. In addition, past results are not necessarily indicative of future results.

Commodity prices are inherently volatile and are influenced by many factors outside of our control. As of April 22, 2019, we have hedged 5,198,533 barrels of oil and 1,925,000 MMbtu of natural gas, or approximately 55% of our expected remaining 2019 production, 4,342,500 barrels of oil for 2020 and 181,000 barrels of oil for 2021 at price levels that provide some economic certainty to our cash flows. We focus our efforts on increasing oil, natural gas and NGLs reserves and production while controlling costs at a level that is appropriate for long-term operations. Our future earnings and cash flows are dependent on our ability to manage our revenues and overall cost structure to a level that allows for profitable production.

We operate in one industry segment, which is the development and production of crude oil, natural gas and NGLs, and all of our operations are conducted in the Rocky Mountain region of the United States. Consequently, we currently report a single reportable segment.

For the three months ended March 31, 2019, as a result of the closing of the Merger on March 19, 2018, Fifth Creek's revenues and expenses are included in the Unaudited Consolidated Statement of Operations beginning on March 19, 2018.

28

Three Months Ended March 31, 2019 Compared with Three Months Ended March 31, 2018

	Three Months Ended March 31,						Increase (Decrease)
	2019			2018			Amount			Percent
	($ in thousands, except per unit data)
Operating Results:
Operating Revenues
Oil, gas and NGL production	$	101,705		$	80,831		$	20,874		26	%
Other operating revenues	275			(21		)	296			*nm
Total operating revenues	101,980			80,810			21,170			26	%
Operating Expenses
Lease operating expense	11,277			6,251			5,026			80	%
Gathering, transportation and processing expense	1,723			419			1,304			311	%
Production tax expense	3,893			5,175			(1,282		)	(25	)%
Exploration expense	25			13			12			92	%
Impairment, dry hole costs and abandonment expense	322			317			5			2	%
(Gain) loss on sale of properties	(5		)	408			(413		)	*nm
Depreciation, depletion and amortization	72,610			40,985			31,625			77	%
Unused commitments	4,469			4,538			(69		)	(2	)%
General and administrative expense (1)	12,660			10,107			2,553			25	%
Merger transaction expense	2,414			4,763			(2,349		)	(49	)%
Other operating expenses, net	(24		)	39			(63		)	*nm
Total operating expenses	$	109,364		$	73,015		$	36,349		50	%
Production Data:
Oil (MBbls)	1,720			1,137			583			51	%
Natural gas (MMcf)	3,756			2,562			1,194			47	%
NGLs (MBbls)	452			350			102			29	%
Combined volumes (MBoe)	2,798			1,914			884			46	%
Daily combined volumes (Boe/d)	31,089			21,267			9,822			46	%
Average Realized Prices Before Hedging:
Oil (per Bbl)	$	50.82		$	60.45		$	(9.63	)	(16	)%
Natural gas (per Mcf)	2.21			1.95			0.26			13	%
NGLs (per Bbl)	13.29			20.31			(7.02		)	(35	)%
Combined (per Boe)	36.35			42.24			(5.89		)	(14	)%
Average Realized Prices with Hedging:
Oil (per Bbl)	$	54.01		$	53.00		$	1.01		2	%
Natural gas (per Mcf)	1.98			1.98			—			—	%
NGLs (per Bbl)	13.29			20.31			(7.02		)	(35	)%
Combined (per Boe)	38.01			37.86			0.15			—	%
Average Costs (per Boe):
Lease operating expense	$	4.03		$	3.27		$	0.76		23	%
Gathering, transportation and processing expense	0.62			0.22			0.40			182	%
Production tax expense	1.39			2.70			(1.31		)	(49	)%
Depreciation, depletion and amortization	25.95			21.41			4.54			21	%
General and administrative expense (1)	4.52			5.28			(0.76		)	(14	)%

* Not meaningful.

(1) Included in general and administrative expense is long-term cash and equity incentive compensation of $2.7 million (or $0.97 per Boe) and $1.4 million (or $0.75 per Boe) for the three months ended March 31, 2019 and 2018, respectively.

29

Production Revenues and Volumes. Production revenues increased to $101.7 million for the three months ended March 31, 2019 from $80.8 million for the three months ended March 31, 2018. The increase in production revenues was due to a 46%increase in production volumes, offset by a 14% decrease in average realized prices before hedging. The increase in production volumes increased production revenues by approximately $32.1 million, while average realized prices before hedging decreased production revenues by approximately $11.2 million.

Lease Operating Expense. LOE increased to $4.03 per Boe for the three months ended March 31, 2019 from $3.27 per Boe for the three months ended March 31, 2018. The increase per Boe for the three months ended March 31, 2019 compared with the three months ended March 31, 2018 is primarily related to adverse weather impacting field operations in both Northeast Wattenberg and Hereford, along with compressor maintenance. In addition, first quarter LOE is typically higher compared to the remainder of the year due to increased seasonal operating costs.

Gathering, Transportation and Processing Expense. GTP expense increased to $0.62 per Boe for the three months ended March 31, 2019 from $0.22 per Boe for the three months ended March 31, 2018.

Costs incurred to gather, transport and/or process our oil, gas and NGLs prior to the transfer of control to the customer are included in GTP expense. Costs incurred to gather, transport and/or process our oil, gas and NGLs after control has transferred to the customer are considered components of the consideration received from the customer and thus recorded in oil, gas and NGL production revenues. In general, based on specific contract arrangements, costs incurred in the Hereford Field in the DJ Basin, which was acquired in the Merger, are included in GTP expense and costs incurred in the Northeast Wattenberg Field in the DJ Basin are included in production revenues. See the "Revenue Recognition" section in Note 2 for additional information.

GTP expense for the three months ended March 31, 2019 of $0.62 per Boe is primarily associated with increased production volume from the Hereford Field. We expect GTP expense per Boe to increase in the future as we further develop and increase our production mix from the Hereford Field under the existing contractual arrangements.

Production Tax Expense. Total production taxes decreased to $3.9 million for the three months ended March 31, 2019 from $5.2 million for the three months ended March 31, 2018. Production tax expense for both periods included an annual true-up of Colorado ad valorem tax based on actual assessments and a true-up of the Colorado severance tax. Production taxes are primarily based on the wellhead values of production, which exclude gains and losses associated with hedging activities. Excluding the ad valorem and severance tax adjustments, production taxes as a percentage of oil, natural gas and NGL sales were 8.5% and 8.9% for the three months ended March 31, 2019 and 2018, respectively.

Depreciation, Depletion and Amortization. DD&A increased to $72.6 million for the three months ended March 31, 2019 compared with $41.0 million for the three months ended March 31, 2018. The increase of $31.6 million was a result of a 46%increase in production and a 21%increase in the DD&A rate for the three months ended March 31, 2019 compared with the three months ended March 31, 2018. The increase in production accounted for a $18.9 million increase in DD&A expense while the increase in the DD&A rate accounted for a $12.7 million increase in DD&A expense.

Under successful efforts accounting, depletion expense is calculated on a field-by-field basis based on geologic and reservoir delineation using the unit-of-production method. The capital expenditures for proved properties for each field compared to the proved reserves corresponding to each producing field determine a depletion rate for current production. For the three months ended March 31, 2019, the relationship of capital expenditures, proved reserves and production from certain producing fields yielded a depletion rate of $25.95 per Boe compared with $21.41 per Boe for the three months ended March 31, 2018. The increase in the depletion rate of 21% is the result of year end 2018 reserve adjustments.

Unused Commitments. Unused commitments expense for each of the three months ended March 31, 2019 and 2018 consisted of $4.5 million related to gas transportation contracts. During March 2010, we entered into two firm natural gas pipeline transportation contracts to provide a guaranteed outlet for production from the West Tavaputs area of the Uinta Basin and the Gibson Gulch area of the Piceance Basin. These transportation contracts were not included in the sales of these assets in December 2013 and September 2014, respectively. Both firm transportation contracts require the pipeline to provide transportation capacity and require us to pay monthly transportation charges regardless of the amount of pipeline capacity utilized. The agreements expire July 31, 2021.

General and Administrative Expense. General and administrative expense increased to $12.7 million for the three months ended March 31, 2019 from $10.1 million for the three months ended March 31, 2018, primarily due to an increase in employee compensation and benefits associated with an increase in headcount. General and administrative expense on a Boe basis decreased from $5.28 for the three months ended March 31, 2018 to $4.52 for the three months ended March 31, 2019.

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Included in general and administrative expense is long-term cash and equity incentive compensation of $2.7 million and $1.4 million for the three months ended March 31, 2019 and 2018, respectively. The components of long-term cash and equity incentive compensation for the three months ended March 31, 2019 and 2018 are shown in the following table:

	Three Months Ended March 31,
	2019		2018
	(in thousands)
Nonvested common stock	$	1,797	$	1,330
Nonvested common stock units	293		170
Nonvested performance cash units (1)	632		(73		)
Total	$	2,722	$	1,427

(1) The nonvested performance cash units are accounted for as liability awards and will be settled in cash for the performance metrics that are met. The expense for the period will increase or decrease based on updated fair values of these awards at each reporting date.

Merger Transaction Expense. Merger transaction expense was $2.4 million and $4.8 million for the three months ended March 31, 2019 and March 31, 2018, respectively. Transaction expenses included severance, consulting, advisory, legal and other merger-related fees that were not capitalized as part of the Merger.

Commodity Derivative Gain (Loss).Commodity derivative gain (loss) was a loss of $105.2 million for the three months ended March 31, 2019 compared with a loss of $20.3 million for the three months ended March 31, 2018. The loss for the three months ended March 31, 2019 compared to the loss for the three months ended March 31, 2018 was related to fluctuations of oil and natural gas future pricing compared to actual pricing of commodity hedges in place as of March 31, 2019 and 2018.

The fair value of our open, but not yet settled derivative contracts is based on an income approach using various assumptions, such as quoted forward prices for commodities, risk-free discount rates, volatility factors and time value factors. The mark-to-market fair value of the open commodity derivative contracts will generally be inversely related to the price movement of the underlying commodity. If commodity price trends reverse from period to period, prior unrealized gains may become unrealized losses and vice versa. Higher underlying commodity price volatility will generally lead to higher volatility in our unrealized gains and losses and, by association, the fair value of our commodity derivative contracts. These unrealized gains and losses will impact our net income in the period reported. The mark-to-market fair value can create non-cash volatility in our reported earnings during periods of commodity price volatility. We have experienced such volatility in the past and are likely to experience it in the future. Gains on our derivatives generally indicate lower wellhead revenues in the future while losses indicate higher future wellhead revenues.

The table below summarizes our commodity derivative gains and losses that were recognized in the periods presented:

	Three Months Ended March 31,
	2019			2018
	(in thousands)
Realized gain (loss) on derivatives (1)	$	4,649		$	(8,388	)
Prior year unrealized (gain) loss transferred to realized (gain) loss (1)	(19,759		)	6,094
Unrealized gain (loss) on derivatives (1)	(90,081		)	(18,039		)
Total commodity derivative gain (loss)	$	(105,191	)	$	(20,333	)

(1) Realized and unrealized gains and losses on commodity derivatives are presented in the table as separate line items but are combined for a total commodity derivative gain (loss) in the Unaudited Consolidated Statements of Operations. This separate presentation is a non-GAAP measure. Management believes the separate presentation of the realized and unrealized commodity derivative gains and losses is useful because the realized cash settlement portion provides a better understanding of our hedge position. We also believe that this disclosure allows for a more accurate comparison to our peers.

During the three months ended March 31, 2019, approximately 89% of our oil volumes and 34% of our natural gas volumes were subject to financial hedges, which resulted in increased oil income of $5.5 million and decreased natural gas

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income of $0.9 million after settlements. During the three months ended March 31, 2018, approximately 75% of our oil volumes and 17% of our natural gas volumes were subject to financial hedges, which resulted in decreased oil income of $8.5 million and increased natural gas income of $0.1 million after settlements.

Income Tax (Expense) Benefit. For the three months ended March 31, 2019, an income tax benefit was recognized in the amount of $29.7 million. For the year ended December 31, 2018, we determined that it was more likely than not that we would be able to realize a portion of our deferred tax assets. This determination was made by considering all available evidence in assessing the need for a valuation allowance. Such evidence included the scheduled reversal of deferred tax liabilities, assets acquired in connection with the Merger and their classification as proved or unproved, current and projected future taxable income and tax planning strategies. In making this assessment, judgment is required in considering the relative weight of negative and positive evidence. As a result of the analysis conducted, we reversed a majority of the valuation allowance on certain deferred tax assets. We continue to consider all available evidence in assessing the need for a valuation allowance on our deferred tax assets. No income tax expense or benefit was recognized as of March 31, 2018 as a result of a full valuation allowance against our deferred tax assets.

Capital Resources and Liquidity

Our primary sources of liquidity since our formation have been net cash provided by operating activities, sales and other issuances of equity and debt securities, bank credit facilities, proceeds from sale-leasebacks, joint exploration agreements and sales of interests in properties. Our primary use of capital has been for the development, exploration and acquisition of oil and natural gas properties. As we pursue profitable reserves and production growth, we continually monitor the capital resources available to us to meet our future financial obligations, fund planned capital expenditure activities and ensure adequate liquidity. Our future success in growing proved reserves and production will be highly dependent on capital resources being available to us. We believe that we have sufficient liquidity available to us from cash on hand, cash flows from operations and under our Amended Credit Facility for our planned uses of capital for the remainder of 2019 and for 2020.

On September 14, 2018, we entered into the Amended Credit Facility to incorporate the proved reserves and assets acquired in the Merger. The Amended Credit Facility provides for a maximum credit amount of $1.5 billion, an initial elected commitment amount of $500.0 million, and an initial borrowing base of $500.0 million, with interest rates and commitment fees unchanged. At December 31, 2018, we had cash and cash equivalents of $32.8 million and no amounts outstanding under the Amended Credit Facility. At March 31, 2019, we had cash and cash equivalents of $44.7 million and $70.0 million outstanding under the Amended Credit Facility. Our effective borrowing capacity as of March 31, 2019 was reduced by $26.0 million to $404.0 million due to an outstanding irrevocable letter of credit related to a firm transportation agreement.

Cash Flow from Operating Activities

Net cash provided by operating activities for the three months ended March 31, 2019 and 2018 was $77.7 million and $54.3 million, respectively. The increase in net cash provided by operating activities was primarily due to an increase in production revenues.

Commodity Hedging Activities

Our operating cash flow is sensitive to many variables, the most significant of which are the prices we receive for the oil, natural gas and NGLs we produce. Prices for these commodities are determined primarily by prevailing market conditions. National and worldwide economic activity and political stability, weather, infrastructure capacity to reach markets, supply levels and other variable factors influence market conditions for these products. These factors are beyond our control and are difficult to predict.

To mitigate some of the potential negative impact on cash flow caused by changes in oil, natural gas and NGL prices, we have entered into financial commodity swap contracts and cashless collars to receive fixed prices for a portion of our production. At March 31, 2019, we had in place crude oil swaps covering portions of our 2019 and 2020 production, natural gas swaps covering portions of our 2019 production and crude oil cashless collars covering portions of our 2019 production.

The following table includes all hedges entered into through April 22, 2019.

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Contract	Total Hedged Volumes	Quantity Type	Weighted Average Fixed Price		Weighted Average Floor Price		Weighted Average Ceiling Price		Index Price (1)
Swap Contracts:
2019
Oil	4,646,533	Bbls	$	59.07					WTI
Natural gas	1,925,000	MMBtu	$	2.11					NWPL
2020
Oil	4,342,500	Bbls	$	59.54					WTI
2021
Oil	181,000	Bbls	$	57.13					WTI
Cashless Collars:
2019
Oil	552,000	Bbls			$	55.00	$	77.56	WTI
Total

(1) WTI refers to West Texas Intermediate price as quoted on the New York Mercantile Exchange. NWPL refers to the Northwest Pipeline Corporation price as quoted in Platt's Inside FERC on the first business day of each month.

By removing the price volatility from a portion of our oil and natural gas revenue, we have mitigated, but not eliminated, the potential effects of changing prices on our operating cash flow for the relevant period. While mitigating negative effects of falling commodity prices, these derivative contracts also limit the benefits we would receive from increases in commodity prices.

It is our 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. Our 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. We are not required to provide any credit support to our counterparties other than cross collateralization with the properties securing the Amended Credit Facility. We have set-off provisions in our derivative contracts with lenders under our Amended Credit Facility which, in the event of a counterparty default, allow us to set-off amounts owed to the defaulting counterparty under the Amended Credit Facility or other obligations against monies owed to us under the derivative contracts. Where the counterparty is not a lender under the Amended Credit Facility, we may not be able to set-off amounts owed by us under the Amended Credit Facility, even if such counterparty is an affiliate of a lender under such facility.

Capital Expenditures

Our capital expenditures are summarized in the following tables for the periods indicated:

	Three Months Ended March 31,
Basin/Area	2019		2018
	(in millions)
DJ Basin	$	123.5	$	112.0
Other	2.6		0.1
Total	$	126.1	$	112.1

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	Three Months Ended March 31,
	2019		2018
	(in millions)
Acquisitions of proved and unproved properties and other real estate	$	0.3	$	0.5
Drilling, development, exploration and exploitation of oil and natural gas properties	111.9		98.1
Gathering and compression facilities	8.4		13.4
Geologic and geophysical costs	2.9		—
Furniture, fixtures and equipment	2.6		0.1
Total	$	126.1	$	112.1

Our current estimated capital expenditure budget for 2019 is $350.0 million to $380.0 million. The budget includes facilities costs and excludes acquisitions. We may adjust capital expenditures as business conditions and operating results warrant. The amount, timing and allocation of capital expenditures is generally discretionary and within our control. If oil, natural gas and NGL prices decline to below acceptable levels or costs increase above acceptable levels, we could choose to defer a portion of our budgeted capital expenditures until later periods to achieve the desired balance between sources and uses of liquidity. We would generally do this by prioritizing capital projects to first focus on those that we believe will have the highest expected risk-adjusted financial returns and ability to generate near-term cash flow.

We believe that we have sufficient available liquidity with available cash on hand, cash under the Amended Credit Facility and cash flow from operations to fund our 2019 and 2020 capital expenditures. Future cash flows are subject to a number of variables, including our level of oil and natural gas production, commodity prices and operating costs. There can be no assurance that operations and other capital resources will provide sufficient amounts of cash flow to maintain planned levels of capital expenditures.

Financing Activities

Amended Credit Facility. We had $70.0 million and zero outstanding under the Amended Credit Facility as of March 31, 2019 and December 31, 2018, respectively. On September 14, 2018, we entered into the Amended Credit Facility to incorporate the proved reserves and assets acquired in the Merger. The Amended Credit Facility provides for a maximum credit amount of $1.5 billion, an initial elected commitment amount of $500.0 million, and an initial borrowing base of $500.0 million, with interest rates and commitment fees unchanged. The Amended Credit Facility extended the maturity date of the facility to September 14, 2023. Borrowing bases are computed based on proved oil, natural gas and NGL reserves, hedge positions and estimated future cash flows from those reserves calculated using future commodity pricing provided by our lenders, as well as any other outstanding debt. Lower commodity prices will generally result in a lower borrowing base.

We are currently in compliance with all financial covenants and have complied with all financial covenants since issuance. We expect to be in compliance with all financial covenants based on the 2019 budget at current commodity prices.

Our outstanding debt is summarized below:

		As of March 31, 2019							As of December 31, 2018
	Maturity Date	Principal		Unamortized Discount			Carrying Amount		Principal		Unamortized Discount			Carrying Amount
		(in thousands)
Amended Credit Facility	September 14, 2023	$	70,000	$	—		$	70,000	$	—	$	—		$	—
7.0% Senior Notes	October 15, 2022	350,000		(3,000		)	347,000		350,000		(3,210		)	346,790
8.75% Senior Notes	June 15, 2025	275,000		(4,232		)	270,768		275,000		(4,403		)	270,597
Lease Financing Obligation	August 10, 2020	—		—			—		1,859		—			1,859
Total Debt		$	695,000	$	(7,232	)	$	687,768	$	626,859	$	(7,613	)	$	619,246
Less: Current Portion of Long-Term Debt		—		—			—		1,859		—			1,859
Total Long-Term Debt (1)		$	695,000	$	(7,232	)	$	687,768	$	625,000	$	(7,613	)	$	617,387

(1) See Note 5 for additional information.

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Credit Ratings. Our credit risk is evaluated by two independent rating agencies based on publicly available information and information obtained during our ongoing discussions with the rating agencies. Moody's Investor Services and Standard & Poor's Rating Services currently rate our 7.0% Senior Notes and 8.75% Senior Notes and have assigned a credit rating. We do not have any credit rating triggers that would accelerate the maturity of amounts due under our Amended Credit Facility, 7.0% Senior Notes or 8.75% Senior Notes. However, our ability to raise funds and the costs of any financing activities could be affected by our credit rating at the time any such financing activities are conducted.

Contractual Obligations. A summary of our contractual obligations as of March 31, 2019 is provided in the following table:

	Payments Due by Year
	Year 1		Year 2		Year 3		Year 4		Year 5		Thereafter		Total
	Twelve Months Ended March 31, 2020		Twelve Months Ended March 31, 2021		Twelve Months Ended March 31, 2022		Twelve Months Ended March 31, 2023		Twelve Months Ended March 31, 2024		After March 31, 2024
	(in thousands)
Notes payable (1)	$	460	$	—	$	—	$	70,000	$	—	$	—	$	70,460
7.0% Senior Notes (2)	24,500		24,500		24,500		374,500		—		—		448,000
8.75% Senior Notes (3)	24,063		24,063		24,063		24,063		24,063		311,091		431,406
Firm transportation agreements (4)	17,806		18,400		6,133		—		—		—		42,339
Gas gathering and processing agreements (5)(6)	8,819		2,124		1,496		—		—		—		12,439
Asset retirement obligations (7)	3,648		1,023		1,131		1,042		1,325		22,803		30,972
Derivative liability (8)	5,850		894		—		—		—		—		6,744
Operating Leases (9)	1,305		2,224		2,171		1,983		2,037		9,144		18,864
Other (10)	4,825		1,303		745		745		559		—		8,177
Total	$	91,276	$	74,531	$	60,239	$	472,333	$	27,984	$	343,038	$	1,069,401

(1) Included in notes payable is the outstanding principal amount under our Amended Credit Facility due September 14, 2023. This table does not include future commitment fees, interest expense or other fees on our Amended Credit Facility because the Amended Credit Facility is a floating rate instrument, and we cannot determine with accuracy the timing of future loan advances, repayments or future interest rates to be charged. Also included in notes payable includes interest on a $26.0 million letter of credit that accrues interest at 2.0% and 0.125% per annum for participation fees and fronting fees, respectively. The expected term of the letter of credit is January 31, 2020.

(2) On March 25, 2012, we issued $400.0 million aggregate principal amount of 7.0% Senior Notes. We are obligated to make semi-annual interest payments through maturity on October 15, 2022 equal to $12.3 million.

(3) On April 28, 2017, we issued $275.0 million aggregate principal amount of 8.75% Senior Notes. We are obligated to make semi-annual interest payments through maturity on June 15, 2025 equal to $12.0 million.

(4) We have entered into contracts that provide firm transportation capacity on pipeline systems. The contracts require us to pay transportation demand charges regardless of the amount of gas we deliver to the processing facility or pipeline.

(5) Includes a gas gathering and processing contract which requires us to deliver a minimum volume of natural gas to a midstream entity for gathering and processing on a monthly basis. The contract requires us to pay a fee associated with the contracted volumes regardless of the amount delivered.

(6) Includes a reimbursement obligation of $6.5 million. The reimbursement obligation requires us to pay a monthly gathering and processing fee per Mcf of production over a one year period to reimburse a midstream entity for its costs to construct gas gathering and processing facilities. If the costs are not reimbursed by us via the monthly gathering and processing fees through August 2019, we must pay the difference.

(7) Neither the ultimate settlement amounts nor the timing of our asset retirement obligations can be precisely determined in advance. See "Critical Accounting Policies and Estimates" in Part II, Item 7 of HighPoint Resources' Annual Report on Form 10-K for the year ended December 31, 2018 for a more detailed discussion of the nature of the accounting estimates involved in estimating asset retirement obligations.

(8) Derivative liability represents the net fair value for oil, gas and NGL commodity derivatives presented as liabilities in our Unaudited Consolidated Balance Sheets as of March 31, 2019. The ultimate settlement amounts of our derivative liabilities are unknown because they are subject to continuing market fluctuations. See "Critical Accounting Policies and Estimates" in Part II, Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2018 and in "Commodity Hedging Activities" above in this Quarterly Report on Form 10-Q for a more detailed discussion of the nature of the accounting estimates involved in valuing derivative instruments.

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(9) Operating leases primarily includes office leases. Also included are leases of operations equipment which are shown as gross amounts that we are financially committed to pay. However, we will record in our financial statements our proportionate share based on our working interest, which will vary from property to property.

(10) Primarily includes a fresh water commitment contract which requires us to purchase a minimum volume of fresh water from a supplier. The contract requires us to pay a fee associated with the contracted volumes regardless of the amount delivered.

Off-Balance Sheet Arrangements

We do not have any off-balance sheet arrangements as of March 31, 2019.

Trends and Uncertainties

We refer you to the corresponding section in Part II, Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2018 for a discussion of trends and uncertainties that may affect our financial condition or liquidity. Also see "Risk Factors" in Part II of this report.

Critical Accounting Policies and Estimates

We refer you to the corresponding section in Part II, Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2018 and the notes to the Unaudited Consolidated Financial Statements included in Item 1 of this Quarterly Report on Form 10-Q for a description of critical accounting policies and estimates.

Item 3. Quantitative and Qualitative Disclosures about Market Risk.

The primary objective of the following information is to provide forward-looking quantitative and qualitative information about our potential exposure to market risks. The term "market risk" refers to the risk of loss arising from adverse changes in oil, natural gas and NGL prices and interest rates. The disclosures are not meant to be precise indicators of expected future losses, but rather indicators of reasonably possible losses. This forward-looking information provides indicators of how we view and manage our ongoing market risk exposures. All of our market risk sensitive instruments were entered into for purposes other than speculative trading.

Commodity Price Risk

Our primary market risk exposure is to the prices we receive for our production. Commodity pricing is primarily driven by the prevailing worldwide price for crude oil and spot regional market prices applicable to our U.S. oil and natural gas production. Pricing for oil, natural gas and NGLs has been volatile and unpredictable for several years, and we expect this volatility to continue in the future. The prices we receive for future production depend on many factors outside of our control, including volatility in the differences between product prices at sales points and the applicable index price. Based on our average daily production and our derivative contracts in place for the three months ended March 31, 2019, our income before income taxes would have decreased by approximately $0.2 million for each $5.00 per barrel decrease in crude oil prices, approximately $0.2 million for each $0.10 decrease per MMBtu in natural gas prices and approximately $0.4 million for each $1.00 per barrel decrease in NGL prices.

We routinely enter into commodity hedges relating to a portion of our projected production revenue through various financial transactions that hedge future prices received. These transactions may include financial price swaps whereby we will receive a fixed price and pay a variable market price to the contract counterparty. These commodity hedging activities are intended to support oil, natural gas and NGL prices at targeted levels that provide an acceptable rate of return and to manage our exposure to oil, natural gas and NGL price fluctuations. We do not enter into any market risk sensitive instruments for trading purposes.

As of April 22, 2019, we have swap contracts related to oil and natural gas volumes in place for the following periods indicated:

	April – December 2019			For the year 2020			For the year 2021
	Derivative Volumes	Weighted Average Price		Derivative Volumes	Weighted Average Price		Derivative Volumes	Weighted Average Price
Oil (Bbls)	4,646,533	$	59.07	4,342,500	$	59.54	181,000	$	57.13
Natural Gas (MMbtu)	1,925,000	$	2.11				—	$	—

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As of April 22, 2019, we have cashless collars related to oil volumes in place for the following periods indicated:

	April – December 2019
	Derivative Volumes	Weighted Average Floor Price		Weighted Average Ceiling Price
Oil (Bbls)	552,000	$	55.00	$	77.56

Further detail of these hedges is summarized in the table presented under "Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations— Capital Resources and Liquidity— Commodity Hedging Activities."

Interest Rate Risk

At March 31, 2019, we had $70.0 million outstanding under our Amended Credit Facility, which bears interest at floating rates. The weighted average annual interest rate incurred on this debt for the three months ended March 31, 2019 was 4.0%. A 1.0% increase in each of the average LIBOR rate and federal funds rate for the three months ended March 31, 2019 would have resulted in an estimated $0.1 million increase in interest expense assuming a similar average debt level to the three months ended March 31, 2019. There were no borrowings under the Amended Credit Facility during 2018. We also had $350.0 million principal amount of 7.0% Senior Notes and $275.0 million principal amount of 8.75% Senior Notes outstanding at March 31, 2019.

Item 4. Controls and Procedures.

Evaluation of Disclosure Controls and Procedures. As of March 31, 2019, we carried out an evaluation, under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rules 13a-15 and 15d-15 of the Securities Exchange Act of 1934. Based upon that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures are effective as of March 31, 2019.

Changes in Internal Controls. There was no change in our internal control over financial reporting during the first fiscal quarter of 2019 that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

PART II. OTHER INFORMATION

Item 1. Legal Proceedings.

We are involved in various legal or governmental proceedings in the ordinary course of business. These proceeding are subject to the uncertainties inherent in any litigation. We review the status of these proceedings on an ongoing basis and, from time to time, may settle or otherwise resolve these matters on terms and conditions that management believes are in our best interests. While the ultimate outcome and impact of any proceeding cannot be predicted with certainty, our management does not believe that the resolution of any currently pending proceeding will have a material adverse effect on our financial condition or results of operations.

As previously disclosed, in the Annual Report on Form10-K, we received initial and supplemental EPA "Section 114" mandatory information directives, as well as parallel "compliance advisories" from the Colorado Department of Public Health and Environment ("CDPHE"). These directives led to settlement negotiations with EPA and CDPHE. In April 2019, we entered into a consent decree with the EPA and the CDPHE to resolve these matters. Upon final approval by the Court, we will pay a fine of $275,000 to the United States and $55,000 to the State of Colorado, conduct a supplemental environmental project estimated to cost up to $220,000 and undertake certain operational enhancements.

Item 1A. Risk Factors.

There have been no material changes or updates to the risk factors previously disclosed in the "Risk Factors" section of our Annual Report on Form 10-K for the year ended December 31, 2018. An investment in our securities involves various risks. When considering an investment in our Company, you should carefully consider all of the risk factors described in our Annual Report on Form 10-K for the year ended December 31, 2018 and subsequent reports filed with the SEC. These risks and

37

uncertainties are not the only ones facing us, and there may be additional matters that we are unaware of or that we currently consider immaterial. All of these could adversely affect our business, financial condition, results of operations and cash flows and, thus, the value of an investment in our Company.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

Unregistered Sales of Securities

There were no sales of unregistered equity securities during the period covered by this report.

Issuer Purchases of Equity Securities

The following table contains information about our acquisitions of equity securities during the three months ended March 31, 2019:

Period	Total Number of Shares (1)	Weighted Average Price Paid Per Share		Total Number of  Shares (or Units) Purchased as Part of Publicly Announced Plans or Programs	Maximum Number  (or Approximate  Dollar Value) of Shares (or Units) that May Yet Be Purchased Under the Plans or Programs
January 1 – 31, 2019	—	$	—	—	—
February 1 – 28, 2019	549,634	2.70		—	—
March 1 – 31, 2019	—	—		—	—
Total	549,634	2.70		—	—

(1) Represents shares delivered by employees to satisfy tax withholding obligations resulting from the vesting of restricted shares of common stock issued pursuant to our employee incentive plans.

Item 3. Defaults upon Senior Securities.

Not applicable.

Item 4. Mine Safety Disclosures.

Not applicable.

Item 5. Other Information.

Not applicable.

Item 6. Exhibits.

Exhibit Number	Description of Exhibits
31.1	Rule 13a-14(a)/15d-14(a) Certification of Chief Executive Officer.
31.2	Rule 13a-14(a)/15d-14(a) Certification of Chief Financial Officer.
32.1	Section 1350 Certification of Chief Executive Officer.
32.2	Section 1350 Certification of Chief Financial Officer.
101.INS	XBRL Instance Document

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Exhibit Number	Description of Exhibits
101.SCH	XBRL Taxonomy Extension Schema Document
101.CAL	XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF	XBRL Taxonomy Extension Definition Linkbase Document
101.LAB	XBRL Taxonomy Extension Label Linkbase Document
101.PRE	XBRL Taxonomy Extension Presentation Linkbase Document

39

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

		HIGHPOINT RESOURCES CORPORATION
Date:	May 6, 2019	By:	/s/ R. Scot Woodall
			R. Scot Woodall
			Chief Executive Officer and President
			(Principal Executive Officer)
Date:	May 6, 2019	By:	/s/ David R. Macosko
			David R. Macosko
			Senior Vice President-Accounting
			(Principal Accounting Officer)

40

EX-31.1

Exhibit 31.1

CERTIFICATION

I, R. Scot Woodall, certify that:

1. I have reviewed this quarterly report on Form 10-Q of HighPoint Resources Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 6, 2019

/s/ R. Scot Woodall

R. Scot Woodall

Chief Executive Officer, President and Director

(Principal Executive Officer)

EX-31.2

Exhibit 31.2

CERTIFICATION

I, William M. Crawford, certify that:

1. I have reviewed this quarterly report on Form 10-Q of HighPoint Resources Corporation;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

c. Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

d. Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: May 6, 2019

/s/ William M. Crawford

William M. Crawford

Chief Financial Officer

(Principal Financial Officer)

EX-32.1

Exhibit 32.1

HIGHPOINT RESOURCES CORPORATION

SARBANES-OXLEY ACT SECTION 906 CERTIFICATION

In connection with this quarterly report on Form 10-Q of HighPoint Resources Corporation for the fiscal quarter ended March 31, 2019, I, R. Scot Woodall, Chief Executive Officer and President of HighPoint Resources Corporation, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1. This Form 10-Q for the fiscal quarter ended March 31, 2019 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2. The information contained in this Form 10-Q for the fiscal quarter ended March 31, 2019 fairly presents, in all material respects, the financial condition and results of operations of HighPoint Resources Corporation for the periods presented therein.

Date: May 6, 2019

/s/ R. Scot Woodall

R. Scot Woodall

Chief Executive Officer and President

(Principal Executive Officer)

EX-32.2

Exhibit 32.2

HIGHPOINT RESOURCES CORPORATION

SARBANES-OXLEY ACT SECTION 906 CERTIFICATION

In connection with this quarterly report on Form 10-Q of HighPoint Resources Corporation for the fiscal quarter ended March 31, 2019, I, William M. Crawford, Chief Financial Officer of HighPoint Resources Corporation, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that:

1. This Form 10-Q for the fiscal quarter ended March 31, 2019 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

2. The information contained in this Form 10-Q for the fiscal quarter ended March 31, 2019 fairly presents, in all material respects, the financial condition and results of operations of HighPoint Resources Corporation for the periods presented therein.

Date: May 6, 2019

/s/ William M. Crawford

William M. Crawford

Chief Financial Officer

(Principal Financial Officer)

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2019	Apr. 22, 2019
Document Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Entity Emerging Growth Company	false
Entity Small Business	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Trading Symbol	HPR
Entity Registrant Name	HighPoint Resources Corp
Entity Central Index Key	0001725526
Current Fiscal Year End Date	--12-31
Entity Filer Category	Accelerated Filer
Entity Common Stock, Shares Outstanding		213,761,384

XML

CONSOLIDATED BALANCE SHEETS (UNAUDITED) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Current Assets:
Cash and cash equivalents	$ 44,658	$ 32,774
Accounts receivable, net of allowance for doubtful accounts	57,473	72,943
Derivative assets	1,419	81,166
Prepayments and other current assets	3,495	2,898
Total current assets	107,045	189,781
Property and equipment - at cost, successful efforts method for oil and gas properties:
Proved oil and gas properties	2,296,671	2,195,310
Unproved oil and gas properties, excluded from amortization	490,868	468,208
Furniture, equipment and other	29,675	20,662
Property, plant and equipment, gross	2,817,214	2,684,180
Accumulated depreciation, depletion, amortization and impairment	721,054	654,657
Total property and equipment, net	2,096,160	2,029,523
Derivative assets	3,939	27,289
Other noncurrent assets	5,392	5,867
Total	2,212,536	2,252,460
Current Liabilities:
Accounts payable and accrued liabilities	135,762	131,379
Amounts payable to oil and gas property owners	44,886	55,792
Production taxes payable	63,257	59,155
Derivative liabilities	5,850	0
Current portion of long-term debt	0	1,859
Total current liabilities	249,755	248,185
Long-term debt, net of debt issuance costs	687,768	617,387
Asset retirement obligations	27,324	27,330
Deferred income taxes	109,823	139,534
Other noncurrent liabilities	21,391	7,926
Commitments and contingencies (Note 12)
Stockholders' Equity:
Common stock, $0.001 par value; authorized 400,000,000 shares; 213,761,384 and 212,477,101 shares issued and outstanding at March 31, 2019 and December 31, 2018, respectively, with 3,431,780 and 2,912,166 shares subject to restrictions, respectively	210	210
Additional paid-in capital	1,772,336	1,771,730
Retained earnings (accumulated deficit)	(656,071)	(559,842)
Treasury stock, at cost: zero shares at March 31, 2019 and December 31, 2018	0	0
Total stockholders' equity	1,116,475	1,212,098
Total liabilities and stockholders' equity	$ 2,212,536	$ 2,252,460

XML

CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical) - $ / shares	Mar. 31, 2019	Dec. 31, 2018
Statement of Financial Position [Abstract]
Common Stock, Par or Stated Value Per Share (in dollars per share)	$ 0.001	$ 0.001
Common Stock, Shares Authorized	400,000,000	400,000,000
Common Stock, Shares, Issued	213,761,384	212,477,101
Common stock, shares outstanding (in shares)	213,761,384	212,477,101
Common stock, shares subject to restrictions (in shares)	3,431,780	2,912,166
Treasury stock, shares (in shares)	0	0

XML

CONSOLIDATED STATEMENTS OF OPERATIONS (UNAUDITED) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Operating Revenues:
Total operating revenues	$ 101,980	$ 80,810
Operating Expenses:
Production tax expense	3,893	5,175
Exploration expense	25	13
Impairment, dry hole costs and abandonment expense	322	317
(Gain) loss on sale of properties	(5)	408
Depreciation, depletion and amortization	72,610	40,985
Unused commitments	4,469	4,538
General and administrative expense	12,660	10,107
Merger transaction expense	2,414	4,763
Other operating expenses, net	(24)	39
Total operating expenses	109,364	73,015
Operating Income (Loss)	(7,384)	7,795
Other Income and Expense:
Interest and other income	314	691
Interest expense	(13,679)	(13,090)
Commodity derivative gain (loss)	(105,191)	(20,333)
Total other income and expense	(118,556)	(32,732)
Income (Loss) before Income Taxes	(125,940)	(24,937)
(Provision for) Benefit from Income Taxes	29,711	0
Net Income (Loss)	$ (96,229)	$ (24,937)
Net Income (Loss) Per Common Share, Basic (in dollars per share)	$ (0.46)	$ (0.20)
Net Income (Loss) Per Common Share, Diluted (in dollars per share)	$ (0.46)	$ (0.20)
Weighted Average Common Shares Outstanding, Basic	209,931,744	123,595,553
Weighted Average Common Shares Outstanding, Diluted	209,931,744	123,595,553
Oil, gas and NGL production
Operating Revenues:
Production and other revenues	$ 101,705	$ 80,831
Other operating revenues, net
Operating Revenues:
Production and other revenues	275	(21)
Lease operating expense
Operating Expenses:
Cost of goods and services	11,277	6,251
Gathering, transportation and processing expense
Operating Expenses:
Cost of goods and services	$ 1,723	$ 419

XML

CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Operating Activities:
Net Income (Loss)	$ (96,229)	$ (24,937)
Adjustments to reconcile to net cash provided by operations:
Depreciation, depletion and amortization	72,610	40,985
Deferred income taxes	(29,711)	0
Impairment, dry hole costs and abandonment expense	322	317
Commodity derivative (gain) loss	105,191	20,333
Settlements of commodity derivatives	4,649	(8,388)
Stock compensation and other non-cash charges	4,318	835
Amortization of deferred financing costs	640	563
(Gain) loss on sale of properties	(5)	408
Change in operating assets and liabilities:
Accounts receivable	15,470	9,166
Prepayments and other assets	(72)	(111)
Accounts payable, accrued and other liabilities	7,304	822
Amounts payable to oil and gas property owners	(10,906)	9,609
Production taxes payable	4,102	4,715
Net cash provided by (used in) operating activities	77,683	54,317
Investing Activities:
Additions to oil and gas properties, including acquisitions	(130,862)	(88,854)
Additions of furniture, equipment and other	(1,309)	(122)
Repayment of debt associated with merger, net of cash acquired	0	(53,357)
Other investing activities	(273)	(157)
Net cash provided by (used in) investing activities	(132,444)	(142,490)
Financing Activities:
Proceeds from debt	70,000	0
Principal payments on debt	(1,859)	(116)
Other financing activities	(1,496)	(1,485)
Net cash provided by (used in) financing activities	66,645	(1,601)
Increase (Decrease) in Cash and Cash Equivalents	11,884	(89,774)
Beginning Cash and Cash Equivalents	32,774	314,466
Ending Cash and Cash Equivalents	$ 44,658	$ 224,692

XML

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, 2017	$ 598,554	$ 109	$ 1,279,507	$ (681,062)	$ 0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Restricted stock activity and shares exchanged for tax withholding	(1,462)				(1,462)
Stock-based compensation	4,185		4,185
Retirement of treasury stock	0		(1,462)		1,462
Issuance of common stock, merger	484,000	100	483,900
Net income (loss)	(24,937)			(24,937)
Balance at Mar. 31, 2018	1,060,340	209	1,766,130	(705,999)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Restricted stock activity and shares exchanged for tax withholding	(28)				(28)
Stock-based compensation	1,797		1,797
Retirement of treasury stock	0		(28)		28
Net income (loss)	(46,906)			(46,906)
Balance at Jun. 30, 2018	1,015,203	209	1,767,899	(752,905)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Restricted stock activity and shares exchanged for tax withholding	(42)	1			(43)
Stock-based compensation	1,996		1,996
Retirement of treasury stock	0		(43)		43
Net income (loss)	(29,360)			(29,360)
Balance at Sep. 30, 2018	987,797	210	1,769,852	(782,265)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Restricted stock activity and shares exchanged for tax withholding	(2)				(2)
Stock-based compensation	1,880		1,880
Retirement of treasury stock	0		(2)		2
Net income (loss)	222,423			222,423
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	(1,484)				(1,484)
Stock-based compensation	2,090		2,090
Retirement of treasury stock	0		(1,484)		1,484
Net income (loss)	(96,229)			(96,229)
Balance at Mar. 31, 2019	$ 1,116,475	$ 210	$ 1,772,336	$ (656,071)	$ 0

XML

Organization

3 Months Ended

Mar. 31, 2019

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Organization

Organization

HighPoint Resources Corporation, a Delaware corporation, together with its wholly-owned subsidiary (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.

XML

Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 2019

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, 2018 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 possible impairments of oil and gas properties and the amount of future capital costs used in these calculations. Assumptions, judgments and estimates also are required in determining the fair values of assets acquired and liabilities assumed in business combinations, asset retirement obligations, right-of-use assets and lease liabilities, deferred tax assets, 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.

Accounts Receivable. Accounts receivable is comprised of the following:

	As of March 31, 2019			As of December 31, 2018
	(in thousands)
Oil, gas and NGL sales	$	45,626		$	44,860
Due from joint interest owners	10,543			27,435
Other	1,410			754
Allowance for doubtful accounts	(106		)	(106		)
Total accounts receivable	$	57,473		$	72,943

Oil and Gas Properties. The Company's oil, gas and NGL exploration and production activities are accounted for using the successful efforts method. Under this method, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether the well has found proved reserves. If an exploratory well does not find proved reserves, the costs of drilling the well are charged to expense and remain within cash flows from investing activities in the Unaudited Consolidated Statements of Cash Flows. If an exploratory well does find proved reserves, the costs remain capitalized and are included within additions to oil and gas properties and remain within cash flows from investing activities in the Unaudited Consolidated Statements of Cash Flows. The costs of development wells are capitalized whether proved reserves are added or not. Oil and gas lease acquisition costs are also capitalized. Upon sale or retirement of depreciable or depletable property, the cost and related accumulated DD&A are eliminated from the accounts and the resulting gain or loss is recognized.

Other exploration costs, including certain geological and geophysical expenses and delay rentals for oil and gas leases, are charged to expense as incurred. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the unit-of-production amortization rate. Maintenance and repairs are charged to expense, and renewals and betterments are capitalized to the appropriate property and equipment accounts.

Unproved oil and gas property costs are transferred to proved oil and gas properties if the properties are subsequently determined to be productive or are assigned proved reserves. Proceeds from sales of partial interests in unproved leases are accounted for as a recovery of cost without recognizing any gain until all costs are recovered. Unproved oil and gas properties are assessed periodically for impairment based on remaining lease terms, drilling results, reservoir performance, commodity price outlooks, future plans to develop acreage, recent sales prices of comparable properties and other relevant matters.

Materials and supplies consist primarily of tubular goods and well equipment to be used in future drilling operations or repair operations and are carried at the lower of cost or market value.

The following table sets forth the net capitalized costs and associated accumulated DD&A and non-cash impairments relating to the Company's oil, natural gas and NGL producing activities:

	As of March 31, 2019			As of December 31, 2018
	(in thousands)
Proved properties	$	667,346		$	663,485
Wells and related equipment and facilities	1,518,824			1,438,092
Support equipment and facilities	88,901			75,392
Materials and supplies	21,600			18,341
Total proved oil and gas properties	$	2,296,671		$	2,195,310
Unproved properties	328,377			328,409
Wells and facilities in progress	162,491			139,799
Total unproved oil and gas properties, excluded from amortization	$	490,868		$	468,208
Accumulated depreciation, depletion, amortization and impairment	(714,237		)	(642,645		)
Total oil and gas properties, net	$	2,073,302		$	2,020,873

The Company reviews oil and natural gas properties for impairment on a quarterly basis or whenever events and circumstances indicate that a decline in the recoverability of their carrying value may have occurred. The Company estimates the expected undiscounted future net cash flows of its oil and gas properties using proved and risked probable and possible reserves based on the Company's development plans and best estimate of future production, commodity pricing, reserve risking, gathering and transportation deductions, production tax rates, lease operating expenses and future development costs. The Company compares such undiscounted future net cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the undiscounted future net cash flows exceed the carrying amount of the oil and gas properties, no impairment is taken. If the carrying amount of a property exceeds the undiscounted future net cash flows, the Company will impair the carrying value to fair value based on an analysis of quantitative and qualitative factors existing as of the balance sheet date. The factors used to determine fair value may include, but are not limited to, recent sales prices of comparable properties, indications from marketing activities, the present value of future revenues, net of estimated operating and development costs using estimates of reserves, future commodity pricing, future production estimates, anticipated capital expenditures and various discount rates commensurate with the risk and current market conditions associated with realizing the projected cash flows.

The provision for DD&A of oil and gas properties is calculated on a field-by-field basis using the unit-of-production method. Natural gas and NGLs are converted to an oil equivalent, Boe, at the standard rate of six Mcf to one Boe and forty-two gallons to one Boe, respectively. Estimated future dismantlement, restoration and abandonment costs are taken into consideration by this calculation.

Accounts Payable and Other Accrued Liabilities. Accounts payable and other accrued liabilities are comprised of the following:

	As of March 31, 2019		As of December 31, 2018
	(in thousands)
Accrued drilling, completion and facility costs	$	92,905	$	69,830
Accrued lease operating, gathering, transportation and processing expenses	7,308		6,970
Accrued general and administrative expenses	6,513		8,774
Accrued interest payable	18,930		6,758
Accrued merger transaction expenses	682		550
Prepayments from partners	794		862
Trade payables	1,192		31,057
Operating lease liability	517		—
Other	6,921		6,578
Total accounts payable and other accrued liabilities	$	135,762	$	131,379

Environmental Liabilities. Environmental expenditures that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation are expensed. Environmental liabilities are accrued when environmental assessments and/or clean-ups are probable, and the costs can be reasonably estimated. Recent case law in Wyoming has exposed the Company 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 March 31, 2019, the Company had open contracts with customers with terms of 1 month to 19 years, as well as evergreen contracts that renew on a periodic basis if not canceled by the Company or the customer. The Company's contracts with customers typically require payment within one month of delivery.

Under the Company's contracts with customers, natural gas and its components, including NGLs, are either sold to a midstream entity (which processes the natural gas and subsequently sells the resulting residue gas and NGLs) or are sold to a gas or NGL purchaser after being processed by a third party for a fee. Regardless of the contract structure type, the terms of these contracts compensate the Company for the value of the residue gas and NGLs at current market prices for each product. The Company's oil is sold to multiple oil purchasers at specific delivery points at or near the wellhead. All costs incurred to gather, transport and/or process the Company's oil, gas and NGLs after control has transferred to the customer are considered components of the consideration received from the customer and thus recorded in oil, gas and NGL production revenues in the Unaudited Consolidated Statements of Operations. All costs incurred prior to the transfer of control to the customer are included in gathering, transportation and processing expense in the Unaudited Consolidated Statements of Operations.

Gas imbalances from the sale of natural gas are recorded on the basis of gas actually sold by the Company. If the Company's aggregate sales volumes for a well are greater (or less) than its proportionate share of production from the well, a liability (or receivable) is established to the extent there are insufficient proved reserves available to make-up the overproduced (or underproduced) imbalance. Imbalances have not been significant in the periods presented.

Derivative Instruments and Hedging Activities. The Company periodically uses derivative financial instruments to achieve a more predictable cash flow from its oil, natural gas and NGL sales by reducing its exposure to price fluctuations. Derivative instruments are recorded at fair market value and are included in the Unaudited Consolidated Balance Sheets as assets or liabilities.

Income Taxes. Income taxes are provided for the tax effects of transactions reported in the financial statements and consist of taxes currently payable plus deferred income taxes related to certain income and expenses recognized in different periods for financial and income tax reporting purposes. Deferred income tax assets and liabilities represent the future tax return consequences of those differences, which will either be taxable or deductible when assets are recovered or liabilities are settled. Deferred income taxes also include tax credits and net operating losses that are available to offset future income taxes. Deferred income taxes are measured by applying currently enacted tax rates. 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, increases in market prices for hydrocarbons, improvements in operating results, or other factors 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 March 31, 2019.

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. As the Company was in a net loss position, all potentially dilutive securities were anti-dilutive for the three months ended March 31, 2019 and 2018.

The following table sets forth the calculation of basic and diluted income (loss) per share:

	Three Months Ended March 31,
	2019			2018
	(in thousands, except per share amounts)
Net income (loss)	$	(96,229	)	$	(24,937	)
Basic weighted-average common shares outstanding in period	209,932			123,596
Diluted weighted-average common shares outstanding in period	209,932			123,596
Basic net income (loss) per common share	$	(0.46	)	$	(0.20	)
Diluted net income (loss) per common share	$	(0.46	)	$	(0.20	)

New Accounting Pronouncements. In August 2018, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("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 will only impact the Company's disclosures.

In June 2018, the FASB issued ASU 2018-07, Stock Compensation-Improvements to Non-employee Share-Based Payment Accounting. The objective of this update was to simplify several aspects of the accounting for non-employee share-based payment transactions resulting from expanding the scope of Topic 718, Compensation- Stock Compensation, to include share-based payment transactions for acquiring goods and services from non-employees. ASU 2018-07 was effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods. The standard was adopted on January 1, 2019 and did not have a material impact on the Company's disclosures and financial statements.

In February 2016, the FASB issued ASU 2016-02, Leases, followed by additional accounting standards updates that provided additional practical expedients and policy election options (collectively, Accounting Standards Codification Topic 842 ("ASC 842")). The objective of ASC 842 was to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclose key information about leasing arrangements. ASC 842 was effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods. The Company adopted ASC 842 effective January 1, 2019 using the modified retrospective method and elected the option to not apply ASC 842 to comparative periods. The Company also elected the following practical expedients:

• not to recognize lease assets or liabilities on the balance sheet when lease terms are less than 12 months,

• carryforward previous conclusions related to current lease classification under the previous lease accounting standard to lease classification for these existing leases under ASC 842,

• exclude from evaluation under ASC 842 land easements that existed or expired before adoption of ASC 842, and

• to combine lease and non-lease components for certain asset classes.

The adoption of ASC 842 resulted in the recognition of right-of-use assets of $8.6 million, and current and noncurrent lease liabilities of $0.3 million and $13.7 million, respectively, on the Unaudited Consolidated Balance Sheet as of January 1, 2019. The difference between the right-of-use assets and the total lease liability was related to lease incentives and deferred rent balances of $5.4 million, which were required to be netted against the right-of-use assets as of the implementation date of January 1, 2019. The Company's leases included office leases and other equipment, all classified as operating leases. The adoption of ASC 842 had no impact on the Company's Unaudited Consolidated Statements of Operations or Cash Flows. See Note 11 for additional information.

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Supplemental Disclosures of Cash Flow Information

3 Months Ended

Mar. 31, 2019

Supplemental Cash Flow Elements [Abstract]

Supplemental Disclosures of Cash Flow Information

Supplemental Disclosures of Cash Flow Information

Supplemental cash flow information is as follows:

	Three Months Ended March 31,
	2019			2018
	(in thousands)
Cash paid for interest	$	868		$	395
Cash paid for income taxes	—			—
Cash paid for amounts included in the measurements of lease liabilities:
Operating cash flows from operating leases	229			—
Non-cash operating activities:
Right-of-use assets obtained in exchange for lease obligations
Operating leases (1)	14,667			—
Non-cash investing and financing activities:
Accrued liabilities - oil and gas properties	92,702			67,047
Change in asset retirement obligations, net of disposals	933			7,513
Retirement of treasury stock	(1,484		)	(1,462		)
Issuance of common stock for Merger	—			484,000

(1) Excludes the reclassifications of lease incentives and deferred rent balances.

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Merger Merger

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

Merger

Merger

2018 Merger with Fifth Creek Energy Operating Company, LLC

On March 19, 2018, the Company completed the Merger with Fifth Creek. The Merger was effected through the issuance of 100 million shares of the Company's common stock, with a fair value of $484.0 million on the date of closing, and the repayment of $53.9 million of Fifth Creek debt. In connection with the Merger, the Company incurred costs of $19.2 million of severance, consulting, advisory, legal and other merger-related fees, all of which were expensed and included in merger transaction expense in the Company's Consolidated Statements of Operations.

Purchase Price Allocation

The transaction was accounted for as a business combination, using the acquisition method, with the Company being the acquirer for accounting purposes. The following table represents the allocation of the total purchase price to the identifiable assets acquired and the liabilities assumed based on the estimated fair values at the acquisition date. The following table sets forth the Company's purchase price allocation:

	March 19, 2018
	(in thousands)
Purchase Price:
Fair value of common stock issued	$	484,000
Plus: Repayment of Fifth Creek debt	53,900
Total purchase price	537,900
Plus Liabilities Assumed:
Accounts payable and accrued liabilities	25,782
Current unfavorable contract	2,651
Other current liabilities	13,797
Asset retirement obligations	7,361
Long-term deferred tax liability	137,707
Long-term unfavorable contract	4,449
Other noncurrent liabilities	2,354
Total purchase price plus liabilities assumed	$	732,001
Fair Value of Assets Acquired:
Cash	543
Accounts receivable	7,831
Oil and Gas Properties:
Proved oil and gas properties	105,702
Unproved oil and gas properties	609,568
Asset retirement obligations	7,361
Furniture, equipment and other	931
Other noncurrent assets	65
Total asset value	$	732,001

The fair value measurements of oil and natural gas properties and asset retirement obligations are based on inputs that are not observable in the market and therefore represent Level 3 inputs. The fair values of proved oil and natural gas properties and asset retirement obligations were measured using valuation techniques that convert future cash flows to a single discounted amount. Significant inputs to the valuation of oil and natural gas properties included estimates of: (i) recoverable reserves; (ii) production rates; (iii) future operating and development costs; (iv) future commodity prices; and (v) a market-based weighted average cost of capital rate. The fair value of unproved properties was determined using a market approach utilizing recent transactions of a similar nature in the same basin. These inputs required significant judgments and estimates by management at the time of the valuation and are the most sensitive to possible future changes.

The results of operations attributable to the merged companies are included in the Consolidated Statements of Operations beginning on March 19, 2018. The Company generated revenues of approximately $2.1 million and expenses of approximately $1.8 million from the Fifth Creek assets during the period March 19, 2018 to March 31, 2018.

Pro Forma Financial Information

The following pro forma condensed combined financial information was derived from the historical financial statements of the Company and Fifth Creek and gives effect to the acquisition as if it had occurred on January 1, 2018. The below information reflects pro forma adjustments based on available information and certain assumptions that the Company believes are reasonable, including (i) the repayment of Fifth Creek's debt, (ii) depletion of Fifth Creek's fair-valued proved crude oil and natural gas properties, and (iii) the estimated tax impacts of the pro forma adjustments.

Additionally, pro forma earnings for the three months ended March 31, 2019 and 2018 were adjusted to exclude merger-related costs of $2.4 million and $4.8 million, respectively, incurred by the Company and zero and $4.0 million, respectively, incurred by Fifth Creek. The pro forma results of operations do not include any cost savings or other synergies that may have occurred as a result of the acquisition or any estimated costs that have been incurred by the Company to integrate the Fifth Creek assets. The pro forma condensed combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the acquisition taken place on January 1, 2018; furthermore, the financial information is not intended to be a projection of future results.

	Three Months Ended March 31,
	2019			2018
	(in thousands, except per share data)
Revenues	$	101,980		$	96,742
Net Income (Loss)	(93,815		)	(24,104		)
Net Income (Loss) per Common Share, Basic	(0.45		)	(0.12		)
Net Income (Loss) per Common Share, Diluted	(0.45		)	(0.12		)

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Long-Term Debt

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Long-Term Debt

Long-Term Debt

The Company's outstanding debt is summarized below:

		As of March 31, 2019							As of December 31, 2018
	Maturity Date	Principal		Debt Issuance Costs			Carrying Amount		Principal		Debt Issuance Costs			Carrying Amount
		(in thousands)
Amended Credit Facility (1)	September 14, 2023	$	70,000	$	—		$	70,000	$	—	$	—		$	—
7.0% Senior Notes (2)	October 15, 2022	350,000		(3,000		)	347,000		350,000		(3,210		)	346,790
8.75% Senior Notes (3)	June 15, 2025	275,000		(4,232		)	270,768		275,000		(4,403		)	270,597
Lease Financing Obligation (4)	August 10, 2020	—		—			—		1,859		—			1,859
Total Debt		$	695,000	$	(7,232	)	$	687,768	$	626,859	$	(7,613	)	$	619,246
Less: Current Portion of Long-Term Debt (5)		—		—			—		1,859		—			1,859
Total Long-Term Debt		$	695,000	$	(7,232	)	$	687,768	$	625,000	$	(7,613	)	$	617,387

(1) The recorded value of the Amended Credit Facility approximates its fair value due to its floating rate structure and on financing terms currently available to the Company.

(2) The aggregate estimated fair value of the 7.0% Senior Notes was approximately $332.7 million and $329.7 million as of March 31, 2019 and December 31, 2018, respectively, based on reported market trades of these instruments.

(3) The aggregate estimated fair value of the 8.75% Senior Notes was approximately $263.3 million and $264.7 million as of March 31, 2019 and December 31, 2018, respectively, based on reported market trades of these instruments.

(4) The aggregate estimated fair value of the Lease Financing Obligation was approximately $1.8 million as of December 31, 2018, based on market-based parameters of comparable term secured financing instruments. The Company exercised the early buyout option and purchased the equipment for $1.8 million on February 10, 2019.

(5) As of December 31, 2018, the current portion of long-term debt included the Lease Financing Obligation, which was settled on February 10, 2019.

Amended Credit Facility

The Company's revolving bank credit facility (the "Amended Credit Facility"), has a maturity date of September 14, 2023, a maximum credit amount of $1.5 billion, an initial elected commitment amount of $500.0 million and an initial borrowing base of $500.0 million. The Company had $70.0 million and zero outstanding under the Amended Credit Facility as of March 31, 2019 and December 31, 2018, respectively. As credit support for future payments under a contractual obligation, a $26.0 million letter of credit has been issued under the Amended Credit Facility, which reduced the available borrowing capacity under the Amended Credit Facility as of March 31, 2019 to $404.0 million.

Interest rates are either adjusted LIBOR plus applicable margins of 1.5% to 2.5% or an alternate base rate plus applicable margins of 0.5% to 1.5%, and the unused commitment fee is between 0.375% and 0.5%. The applicable margin 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 4.0% for the three months ended March 31, 2019.

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). Pursuant to supplemental indentures entered into in connection with the Merger, HighPoint Resources Corporation became a guarantor of the 7.0% Senior Notes and the 8.75% Senior Notes in March 2018. All covenants in the indentures governing the notes limit the activities of HighPoint Operating Corporation, including limitations on the ability to pay dividends, incur additional indebtedness, make restricted payments, create liens, sell assets or make loans to HighPoint Resources Corporation, but in most cases the covenants in the indentures are not applicable to HighPoint Resources Corporation. HighPoint Operating Corporation is currently in compliance with all covenants and has complied with all covenants since issuance.

Nothing in the indentures governing the 7.0% Senior Notes or the 8.75% Senior Notes prohibits the Company from repurchasing any of the notes from time to time at any price in open market purchases, negotiated transactions or by tender offer or otherwise without any notice to or consent of the holders.

Lease Financing Obligation Due 2020

The Company had a lease financing obligation with a balance of $1.9 million as of December 31, 2018 resulting from the Company's sale and subsequent lease back of certain compressors and related facilities owned by the Company (the "Lease Financing Obligation"). The Company elected to exercise the early buyout option and purchased the equipment for $1.8 million on February 10, 2019.

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Asset Retirement Obligations

3 Months Ended

Mar. 31, 2019

Asset Retirement Obligation Disclosure [Abstract]

Asset Retirement Obligations

Asset Retirement Obligations

A reconciliation of the Company's asset retirement obligations for the three months ended March 31, 2019 is as follows (in thousands):

As of December 31, 2018	$	29,655
Liabilities incurred	864
Liabilities settled	(258		)
Disposition of properties	(73		)
Accretion expense	384
Revisions to estimate	400
As of March 31, 2019	$	30,972
Less: Current asset retirement obligations	3,648
Long-term asset retirement obligations	$	27,324

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Fair Value Measurements

3 Months Ended

Mar. 31, 2019

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 consolidated balance sheet. The following methods and assumptions were used to estimate the fair values:

Cash equivalents – The highly liquid cash equivalents are recorded at fair value. Carrying value approximates fair value, which represents a Level 1 input.

Deferred compensation plan – The Company maintains a non-qualified deferred compensation plan which allows certain management employees to defer receipt of a portion of their compensation. The Company maintains assets for the deferred compensation plan in a rabbi trust. The assets of the rabbi trust are invested in publicly traded mutual funds and are recorded in other current and other long-term assets in the Unaudited Consolidated Balance Sheets. The deferred compensation plan financial assets are reported at fair value based on active market quotes, which represent Level 1 inputs.

Commodity derivatives – The fair value of crude oil, natural gas and NGL swaps and costless 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. At times, the Company 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 March 31, 2019
Financial Assets
Cash equivalents	$	37,762	$	—	$	—	$	37,762
Deferred compensation plan	1,679		—		—		1,679
Commodity derivatives	—		15,431		—		15,431
Financial Liabilities
Commodity derivatives	—		16,817		—		16,817
As of December 31, 2018
Financial Assets
Cash equivalents	12,188		—		—		12,188
Deferred compensation plan	1,392		—		—		1,392
Commodity derivatives	—		109,494		—		109,494
Financial Liabilities
Commodity derivatives	—		1,039		—		1,039

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 –Oil and gas property costs are evaluated for impairment and reduced to fair value when there is an indication that the carrying costs may not be recoverable. If an impairment is necessary, the fair value is estimated by using either a market approach based on recent sales prices of comparable properties and/or indications from marketing activities or by using the income valuation technique, which involves calculating the present value of future net revenues. The present value, net of estimated operating and development costs, is calculated using estimates of reserves, future commodity pricing, future production estimates, anticipated capital expenditures and various discount rates commensurate with the risk and current market conditions associated with realizing the projected cash flows, predominantly all of which are designated as Level 3 inputs within the fair value hierarchy. No properties were reduced to fair value during either of the three month periods ended March 31, 2019 and 2018.

Additional Fair Value Disclosures

Long-term Debt – Long-term debt is not presented at fair value on the Unaudited Consolidated Balance Sheets, as it is recorded at carrying value, net of unamortized debt issuance costs. The fair values of the Company's fixed rate 7.0% Senior Notes and 8.75% Senior Notes totaled $596.0 million and $594.4 million as of March 31, 2019 and December 31, 2018, respectively. The fair values of the Company's fixed rate Senior Notes are based on active market quotes, which represent Level 1 inputs.

There is no active, public market for the Amended Credit Facility. The recorded value of the Amended Credit Facility approximates its fair value due to its floating rate structure based on the LIBOR spread, secured interest, and the Company's borrowing base utilization. The Amended Credit Facility had a balance of $70.0 million as of March 31, 2019 and zero as of December 31, 2018. The fair value measurements for the Amended Credit Facility represent Level 2 inputs.

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Derivative Instruments

3 Months Ended

Mar. 31, 2019

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments

Derivative Instruments

The Company uses financial derivative instruments as part of its price risk management program to achieve a more predictable cash flow from its production revenues by reducing its exposure to commodity price fluctuations. The Company has entered into financial commodity swap contracts and costless collars related to the sale of a portion of the Company's production. The Company does not enter into derivative instruments for speculative or trading purposes.

In addition to financial contracts, the Company may at times be party to various physical commodity contracts for the sale of oil, natural gas and NGLs that have varying terms and pricing provisions. These physical commodity contracts qualify for the normal purchase and normal sale exception and, therefore, are not subject to hedge or mark-to-market accounting. The financial impact of physical commodity contracts is included in oil, natural gas and NGL production revenues at the time of settlement.

All derivative instruments, other than those that meet the normal purchase and normal sale exception, as mentioned above, are recorded at fair value and included on the Unaudited Consolidated Balance Sheets as assets or liabilities. The following table summarizes the location, as well as the gross and net fair value amounts, of all derivative instruments presented on the Unaudited Consolidated Balance Sheets as of the dates indicated.

	As of March 31, 2019
Balance Sheet	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet				Net Amounts of Assets Presented in the Balance Sheet
	(in thousands)
Derivative assets (current)	$	9,815		$	(8,396	)	(1)	$	1,419
Derivative assets (noncurrent)	5,616			(1,677		)	(1)	3,939
Total derivative assets	$	15,431		$	(10,073	)		$	5,358
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet				Net Amounts of Liabilities Presented in the Balance Sheet
	(in thousands)
Derivative liabilities	$	(14,246	)	$	8,396		(1)	$	(5,850	)
Other noncurrent liabilities	(2,571		)	1,677			(1)	(894		)
Total derivative liabilities	$	(16,817	)	$	10,073			$	(6,744	)
	As of December 31, 2018
Balance Sheet	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet				Net Amounts of Assets Presented in the Balance Sheet
	(in thousands)
Derivative assets (current)	$	82,205		$	(1,039	)	(1)	$	81,166
Derivative assets (noncurrent)	27,289			—			(1)	27,289
Total derivative assets	$	109,494		$	(1,039	)		$	108,455
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet				Net Amounts of Liabilities Presented in the Balance Sheet
	(in thousands)
Derivative liabilities	$	(1,039	)	$	1,039		(1)	$	—
Other noncurrent liabilities	—			—			(1)	—
Total derivative liabilities	$	(1,039	)	$	1,039			$	—

(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 March 31, 2019, the Company had swap contracts in place to hedge the following volumes for the periods indicated:

	April – December 2019			For the year 2020
	Derivative Volumes	Weighted Average Price		Derivative Volumes	Weighted Average Price
Oil (Bbls)	4,646,533	$	59.07	4,024,000	$	59.42
Natural Gas (MMbtu)	1,925,000	$	2.11	—	$	—

As of March 31, 2019, the Company had cashless collars (purchased put options and written call options) in place to hedge the following volumes for the periods indicated:

	April – December 2019
	Derivative Volumes	Weighted Average Floor Price		Weighted Average Ceiling Price
Oil (Bbls)	552,000	$	55.00	$	77.56

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 10 different counterparties as of March 31, 2019. 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.

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Income Taxes

3 Months Ended

Mar. 31, 2019

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 months ended March 31, 2019 and 2018, 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 months ended March 31, 2019 and 2018.

Income tax benefit for the three months ended March 31, 2019 and 2018 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 the effect of deferred tax asset valuation allowances, stock-based compensation, political lobbying expense, political contributions, nondeductible officer compensation and state income taxes. For the three months ended March 31, 2019 the Company recognized $29.7 million of income tax benefit. No income tax expense or benefit was recognized for the three months ended March 31, 2018 as a result of recording a full valuation allowance against the deferred tax asset balance. 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. 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.

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Equity Incentive Compensation Plans and Other Long-term Incentive Programs

3 Months Ended

Mar. 31, 2019

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Equity Incentive Compensation Plans and Other Long-term Incentive Programs

Equity Incentive Compensation Plans and Other Long-term Incentive Programs

The Company maintains various stock-based compensation plans and other employee benefits as discussed below. Stock-based compensation is measured at the grant date based on the value of the awards, and the fair value is recognized on a straight-line basis over the requisite service period (usually the vesting period). Nonvested shares of common stock generally vest ratably over a three year service period, and nonvested shares of common stock units vest over a one year service period. Cash-based compensation is measured at fair value at each reporting date and is recognized on a straight-line basis over the requisite service period (usually the vesting period). Cash-based awards generally have a cliff vest of three years.

The following table presents the long-term equity and cash incentive compensation related to awards for the periods indicated:

	Three Months Ended March 31,
	2019		2018
	(in thousands)
Nonvested common stock (1)	$	1,796	$	1,330
Nonvested common stock units (1)	294		170
Nonvested performance cash units (2)(3)	632		(73		)
Total	$	2,722	$	1,427

(1) Unrecognized compensation expense as of March 31, 2019 was $11.2 million, which related to grants of nonvested shares of common stock that are expected to be recognized over a weighted-average period of 2.1 years.

(2) The nonvested performance-based cash units are accounted for as liability awards with $1.0 million and $0.3 million in other noncurrent liabilities as of March 31, 2019 and December 31, 2018, 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 months ended March 31, 2019 and 2018 is presented below:

	Three Months Ended March 31, 2019				Three Months Ended March 31, 2018
Nonvested Common Stock Awards	Shares		Weighted Average Grant Date Fair Value		Shares		Weighted Average Grant Date Fair Value
Outstanding at January 1,	2,912,166		$	5.27	1,394,868		$	7.00
Granted	1,835,700		2.64		796,423		5.00
Modified (1)	—		—		1,146,305		4.84
Vested	(1,299,599	)	5.19		(652,208	)	8.35
Forfeited or expired	(16,487	)	4.74		(27,853	)	6.62
Outstanding at March 31,	3,431,780		3.90		2,657,535		5.14

(1) Due to the closing of the Merger, the 2016 and 2017 Performance Cash Programs were converted from nonvested performance-based cash units to nonvested common stock awards, resulting in an increase in nonvested common stock awards for the three months ended March 31, 2018.

A summary of the Company's nonvested common stock unit awards for the three months ended March 31, 2019 and 2018 is presented below:

	Three Months Ended March 31, 2019				Three Months Ended March 31, 2018
Nonvested Common Stock Unit Awards	Units		Weighted Average Grant Date Fair Value		Units		Weighted Average Grant Date Fair Value
Outstanding at January 1,	311,237		$	7.26	272,559		$	6.37
Granted	14,704		2.21		3,198		5.08
Vested	(14,704	)	2.21		(3,198	)	5.08
Outstanding at March 31,	311,237		7.26		272,559		6.37

A summary of the Company's nonvested performance-based cash unit awards for the three months ended March 31, 2019 and 2018 is presented below:

	Three Months Ended March 31, 2019				Three Months Ended March 31, 2018
Nonvested Performance-Based Cash Unit Awards	Units		Weighted Average Fair Value		Units		Weighted Average Fair Value
Outstanding at January 1,	909,585				1,548,083
Granted	2,026,521				796,423
Performance goal adjustment (1)	—				11,289
Modified (2)	—				(1,211,478	)
Vested	—				(286,652	)
Forfeited or expired	(67,472	)			(61,242	)
Outstanding at March 31,	2,868,634		$	2.21	796,423		$	5.08

(1) The 2015 Program vested at 104.1% in excess of target level and resulted in additional units vesting in March 2018. These units are included in the vested line item for the three months ended March 31, 2018.

(2) Due to the closing of the Merger, the 2016 and 2017 Performance Cash Programs were converted from nonvested performance-based cash units to nonvested common stock awards, resulting in a decrease in nonvested performance-based cash units for the three months ended March 31, 2018. The 2016 Program awards were converted based on performance through March 19, 2018, which resulted in 89% of the units converting to nonvested common stock awards or a reduction of 65,173 units converting to nonvested common stock awards.

Performance Cash Program

2019 Program. In February 2019, the Compensation Committee of the Board of Directors of the Company approved a performance cash program (the "2019 Program") granting performance cash units that will settle in cash and are accounted for as liability awards. The performance-based awards contingently vest in February 2022, depending on the level at which the performance goal is achieved. The performance goal, which will be measured over the three-year period ending December 31, 2021, will be the Company's total shareholder return ("TSR") based on a matrix measurement of (1) the Company's absolute performance and (2) the Company's ranking relative to a defined peer group's individual TSRs ("Relative TSR"). The Company's absolute performance is measured against the December 31, 2018 closing share price of $2.49. If the Company's absolute performance is less than 50%, the payout is zero. If the Company's absolute performance is 50%, the payout is 50%. If the Company's absolute performance is 100%, the payout is 100%, which is the maximum payout for this portion. If the Company's Relative TSR is less than 30%, the payout is zero. If the Company's Relative TSR is 30% or greater, the payout is equal to the Company's percentile rank up to 100% of the original grant. The Company's combined absolute performance and Relative TSR have a maximum vest of up to 200% of the original grant.

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Leases

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

Leases

Leases

The Company adopted ASC 842 effective January 1, 2019 using the modified retrospective method and elected the option to not apply ASC 842 to comparative periods. See Note 2 - New Accounting Pronouncements for the impacts of adopting this new standard.

The Company currently has leases for office space and other equipment, all classified as operating leases. Under ASC 842, 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's leases have remaining terms of up to nine 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 rate implicit in the lease, when readily determinable. As most of the Company's leases do not provide an implicit rate, the Company utilizes its incremental borrowing rate.

The Company has 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, the Company recognizes the lease payments in the income statement on a straight-line basis over the lease term. The Company has also made the election, for certain classes of underlying assets, to combine lease and non-lease components. However, for the majority of its leases, the Company accounts for lease and non-lease components separately.

For the three months ended March 31, 2019, lease cost was as follows:

	Three Months Ended March 31,
Lease Cost	2019
	(in thousands)
Operating lease cost (1)(3)	$	548
Short-term lease cost (2)(3)	6,219
Total lease cost	$	6,767

(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.

Supplemental balance sheet information related to leases as of March 31, 2019, was as follows:

Operating Leases	As of March 31, 2019
	(in thousands)
Right-of-use assets (1)	$	9,255
Accumulated amortization (2)	(352		)
Total right-of-use assets (5)	$	8,903
Current lease liabilities (3)	(517		)
Noncurrent lease liabilities (4)	(14,117		)
Total lease liabilities (5)	$	(14,634	)
Weighted average remaining lease term
Operating leases (in years)	8.4
Weighted average discount rate
Operating leases	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) Included in accounts payable and accrued liabilities in the Unaudited Consolidated Balance Sheets.

(4) Included in other noncurrent liabilities in the Unaudited Consolidated Balance Sheets.

(5) The difference between the right-of-use assets and total lease liabilities was primarily related to lease incentives and deferred rent balances, which were required to be netted against the right-of-use assets as of the implementation date of January 1, 2019.

Maturities of lease liabilities as of March 31, 2019 were as follows:

	As of March 31, 2019
	(in thousands)
2019	$	1,026
2020	1,938
2021	2,230
2022	1,992
2023	2,024
Thereafter	9,654
Total	$	18,864
Less: Interest	(4,230		)
Present value of lease liabilities	$	14,634

Minimum future contractual payments for operating leases under the scope of ASC 840 as of December 31, 2018 were as follows:

	As of December 31, 2018
	(in thousands)
2019	$	2,583
2020	3,032
2021	3,331
2022	3,263
2023	3,036
Thereafter	13,112
Total	$	28,357

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2019

Commitments and Contingencies Disclosure [Abstract]

Commitments and Contingencies

Commitments and Contingencies

Firm Transportation Agreements. The Company is party to two firm transportation contracts, through July 2021, to provide capacity on natural gas pipeline systems. The contracts require the Company to pay transportation charges regardless of the amount of pipeline capacity utilized by the Company. These monthly transportation payments are included in unused commitments expense in the Unaudited Consolidated Statements of Operations. As a result of previous divestitures in 2013 and 2014, the Company will likely not utilize the firm capacity on the natural gas pipelines.

The amounts in the table below represent the Company's future minimum transportation charges:

	As of March 31, 2019
	(in thousands)
2019	$	13,206
2020	18,400
2021	10,733
Thereafter	—
Total	$	42,339

Gas Gathering and Processing Agreements. The Company is party to one minimum volume commitment and one reimbursement obligation. 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 obligation requires the Company to pay a monthly gathering and processing fee per Mcf of production over a one year period to reimburse a midstream entity for its costs to construct gas gathering and processing facilities. If the costs are not reimbursed by the Company via the monthly gathering and processing fees through August 2019, the Company must pay the difference. The amounts in the table below represent the Company's future minimum charges under both agreements:

	As of March 31, 2019
	(in thousands)
2019 (1)	$	8,275
2020	2,167
2021	1,997
Thereafter	—
Total	$	12,439

(1) Includes $6.5 million associated with the reimbursement obligation discussed above.

Other Commitments. The Company is party to one minimum volume commitment for fresh water. The minimum volume commitment requires the Company to purchase a minimum volume of fresh water from a water supplier. The contract requires the Company to pay a fee associated with the contracted volumes regardless of the amount delivered. The Company also has non-cancellable agreements for information technology and geological and geophysical services. Future minimum annual payments under these agreements are as follows:

	As of March 31, 2019
	(in thousands)
2019	$	4,453
2020	1,490
2021	745
2022	745
2023	744
Thereafter	—
Total	$	8,177

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.

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Parent Guarantor

3 Months Ended

Mar. 31, 2019

Condensed Financial Information Disclosure [Abstract]

Parent Guarantor

Parent Guarantor

The condensed consolidating financial information as of and for the periods ended March 31, 2019 and 2018 presents the results of operations, financial position and cash flows of HighPoint Resources Corporation, or parent guarantor, and HighPoint Operating Corporation (f/k/a Bill Barrett), or subsidiary issuer, as well as the consolidating adjustments necessary to present HighPoint Resources Corporation's results on a consolidated basis. The parent guarantor fully and unconditionally guarantees the debt securities of the subsidiary issuer. The indentures governing those securities limit the ability of the subsidiary issuer to pay dividends or otherwise provide funding to the parent guarantor.

For the purpose of the following financial information, investments in subsidiaries are reflected in accordance with the equity method of accounting. The financial information may not necessarily be indicative of results of operations, cash flows, or financial position had the parent and the subsidiary operated as independent entities.

Condensed Consolidating Balance Sheets

	As of March 31, 2019
	Parent Guarantor		Subsidiary Issuer		Intercompany Eliminations			Consolidated
	(in thousands)
Assets:
Cash and cash equivalents	$	—	$	44,658	$	—		$	44,658
Accounts receivable, net of allowance for doubtful accounts	—		57,473		—			57,473
Other current assets	—		4,914		—			4,914
Property and equipment, net	—		2,096,160		—			2,096,160
Investment in subsidiaries	1,116,475		—		(1,116,475		)	—
Noncurrent assets	—		9,331		—			9,331
Total assets	$	1,116,475	$	2,212,536	$	(1,116,475	)	$	2,212,536
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	$	—	$	135,762	$	—		$	135,762
Other current liabilities	—		113,993		—			113,993
Long-term debt	—		687,768		—			687,768
Deferred income taxes	—		109,823		—			109,823
Other noncurrent liabilities	—		48,715		—			48,715
Stockholders' equity	1,116,475		1,116,475		(1,116,475		)	1,116,475
Total liabilities and stockholders' equity	$	1,116,475	$	2,212,536	$	(1,116,475	)	$	2,212,536

	As of December 31, 2018
	Parent Guarantor		Subsidiary Issuer		Intercompany Eliminations			Consolidated
	(in thousands)
Assets:
Cash and cash equivalents	$	—	$	32,774	$	—		$	32,774
Accounts receivable, net of allowance for doubtful accounts	—		72,943		—			72,943
Other current assets	—		84,064		—			84,064
Property and equipment, net	—		2,029,523		—			2,029,523
Investment in subsidiaries	1,212,098		—		(1,212,098		)	—
Noncurrent assets	—		33,156		—			33,156
Total assets	$	1,212,098	$	2,252,460	$	(1,212,098	)	$	2,252,460
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	$	—	$	131,379	$	—		$	131,379
Other current liabilities	—		116,806		—			116,806
Long-term debt	—		617,387		—			617,387
Deferred income taxes	—		139,534		—			139,534
Other noncurrent liabilities	—		35,256		—			35,256
Stockholders' equity	1,212,098		1,212,098		(1,212,098		)	1,212,098
Total liabilities and stockholders' equity	$	1,212,098	$	2,252,460	$	(1,212,098	)	$	2,252,460

Condensed Consolidating Statements of Operations

	Three Months Ended March 31, 2019
	Parent Guarantor			Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Operating and other revenues	$	—		$	101,980		$	—	$	101,980
Operating expenses	—			(94,290		)	—		(94,290		)
General and administrative	—			(12,660		)	—		(12,660		)
Merger transaction expense	—			(2,414		)	—		(2,414		)
Interest expense	—			(13,679		)	—		(13,679		)
Interest income and other income (expense)	—			(104,877		)	—		(104,877		)
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	—			(125,940		)	—		(125,940		)
(Provision for) benefit from income taxes	—			29,711			—		29,711
Equity in earnings (loss) of subsidiaries	(96,229		)	—			96,229		—
Net income (loss)	$	(96,229	)	$	(96,229	)	$	96,229	$	(96,229	)

	Three Months Ended March 31, 2018
	Parent Guarantor			Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Operating and other revenues	$	—		$	80,810		$	—	$	80,810
Operating expenses	—			(58,145		)	—		(58,145		)
General and administrative	—			(10,107		)	—		(10,107		)
Merger transaction expense	—			(4,763		)	—		(4,763		)
Interest expense	—			(13,090		)	—		(13,090		)
Interest income and other income (expense)	—			(19,642		)	—		(19,642		)
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	—			(24,937		)	—		(24,937		)
(Provision for) benefit from income taxes	—			—			—		—
Equity in earnings (loss) of subsidiaries	(24,937		)	—			24,937		—
Net income (loss)	$	(24,937	)	$	(24,937	)	$	24,937	$	(24,937	)

Condensed Consolidating Statements of Cash Flows

	Three Months Ended March 31, 2019
	Parent Guarantor		Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Cash flows from operating activities	$	—	$	77,683		$	—	$	77,683
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	—		(130,862		)	—		(130,862		)
Additions to furniture, fixtures and other	—		(1,309		)	—		(1,309		)
Other investing activities	—		(273		)	—		(273		)
Cash flows from financing activities:
Proceeds from debt	—		70,000			—		70,000
Principal payments on debt	—		(1,859		)	—		(1,859		)
Other financing activities	—		(1,496		)	—		(1,496		)
Change in cash and cash equivalents	—		11,884			—		11,884
Beginning cash and cash equivalents	—		32,774			—		32,774
Ending cash and cash equivalents	$	—	$	44,658		$	—	$	44,658

	Three Months Ended March 31, 2018
	Parent Guarantor		Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Cash flows from operating activities	$	—	$	54,317		$	—	$	54,317
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	—		(88,854		)	—		(88,854		)
Additions to furniture, fixtures and other	—		(122		)	—		(122		)
Payment of acquiree's debt associated with merger, net of cash acquired	—		(53,357		)	—		(53,357		)
Other investing activities	—		(157		)	—		(157		)
Cash flows from financing activities:
Principal payments on debt	—		(116		)	—		(116		)
Other financing activities	—		(1,485		)	—		(1,485		)
Change in cash and cash equivalents	—		(89,774		)	—		(89,774		)
Beginning cash and cash equivalents	—		314,466			—		314,466
Ending cash and cash equivalents	$	—	$	224,692		$	—	$	224,692

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Summary of Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2019

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, 2018 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 possible impairments of oil and gas properties and the amount of future capital costs used in these calculations. Assumptions, judgments and estimates also are required in determining the fair values of assets acquired and liabilities assumed in business combinations, asset retirement obligations, right-of-use assets and lease liabilities, deferred tax assets, 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.

Oil and Gas Properties

Oil and Gas Properties. The Company's oil, gas and NGL exploration and production activities are accounted for using the successful efforts method. Under this method, all property acquisition costs and costs of exploratory and development wells are capitalized when incurred, pending determination of whether the well has found proved reserves. If an exploratory well does not find proved reserves, the costs of drilling the well are charged to expense and remain within cash flows from investing activities in the Unaudited Consolidated Statements of Cash Flows. If an exploratory well does find proved reserves, the costs remain capitalized and are included within additions to oil and gas properties and remain within cash flows from investing activities in the Unaudited Consolidated Statements of Cash Flows. The costs of development wells are capitalized whether proved reserves are added or not. Oil and gas lease acquisition costs are also capitalized. Upon sale or retirement of depreciable or depletable property, the cost and related accumulated DD&A are eliminated from the accounts and the resulting gain or loss is recognized.

Other exploration costs, including certain geological and geophysical expenses and delay rentals for oil and gas leases, are charged to expense as incurred. The sale of a partial interest in a proved property is accounted for as a cost recovery and no gain or loss is recognized as long as this treatment does not significantly affect the unit-of-production amortization rate. Maintenance and repairs are charged to expense, and renewals and betterments are capitalized to the appropriate property and equipment accounts.

Unproved oil and gas property costs are transferred to proved oil and gas properties if the properties are subsequently determined to be productive or are assigned proved reserves. Proceeds from sales of partial interests in unproved leases are accounted for as a recovery of cost without recognizing any gain until all costs are recovered. Unproved oil and gas properties are assessed periodically for impairment based on remaining lease terms, drilling results, reservoir performance, commodity price outlooks, future plans to develop acreage, recent sales prices of comparable properties and other relevant matters.

Materials and supplies consist primarily of tubular goods and well equipment to be used in future drilling operations or repair operations and are carried at the lower of cost or market value.

The following table sets forth the net capitalized costs and associated accumulated DD&A and non-cash impairments relating to the Company's oil, natural gas and NGL producing activities:

	As of March 31, 2019			As of December 31, 2018
	(in thousands)
Proved properties	$	667,346		$	663,485
Wells and related equipment and facilities	1,518,824			1,438,092
Support equipment and facilities	88,901			75,392
Materials and supplies	21,600			18,341
Total proved oil and gas properties	$	2,296,671		$	2,195,310
Unproved properties	328,377			328,409
Wells and facilities in progress	162,491			139,799
Total unproved oil and gas properties, excluded from amortization	$	490,868		$	468,208
Accumulated depreciation, depletion, amortization and impairment	(714,237		)	(642,645		)
Total oil and gas properties, net	$	2,073,302		$	2,020,873

The Company reviews oil and natural gas properties for impairment on a quarterly basis or whenever events and circumstances indicate that a decline in the recoverability of their carrying value may have occurred. The Company estimates the expected undiscounted future net cash flows of its oil and gas properties using proved and risked probable and possible reserves based on the Company's development plans and best estimate of future production, commodity pricing, reserve risking, gathering and transportation deductions, production tax rates, lease operating expenses and future development costs. The Company compares such undiscounted future net cash flows to the carrying amount of the oil and gas properties to determine if the carrying amount is recoverable. If the undiscounted future net cash flows exceed the carrying amount of the oil and gas properties, no impairment is taken. If the carrying amount of a property exceeds the undiscounted future net cash flows, the Company will impair the carrying value to fair value based on an analysis of quantitative and qualitative factors existing as of the balance sheet date. The factors used to determine fair value may include, but are not limited to, recent sales prices of comparable properties, indications from marketing activities, the present value of future revenues, net of estimated operating and development costs using estimates of reserves, future commodity pricing, future production estimates, anticipated capital expenditures and various discount rates commensurate with the risk and current market conditions associated with realizing the projected cash flows.

The provision for DD&A of oil and gas properties is calculated on a field-by-field basis using the unit-of-production method. Natural gas and NGLs are converted to an oil equivalent, Boe, at the standard rate of six Mcf to one Boe and forty-two gallons to one Boe, respectively. Estimated future dismantlement, restoration and abandonment costs are taken into consideration by this calculation.

Accounts Payable and Accrued Liabilities

Accounts Payable and Other Accrued Liabilities. Accounts payable and other accrued liabilities are comprised of the following:

	As of March 31, 2019		As of December 31, 2018
	(in thousands)
Accrued drilling, completion and facility costs	$	92,905	$	69,830
Accrued lease operating, gathering, transportation and processing expenses	7,308		6,970
Accrued general and administrative expenses	6,513		8,774
Accrued interest payable	18,930		6,758
Accrued merger transaction expenses	682		550
Prepayments from partners	794		862
Trade payables	1,192		31,057
Operating lease liability	517		—
Other	6,921		6,578
Total accounts payable and other accrued liabilities	$	135,762	$	131,379

Environmental Liabilities

Environmental Liabilities. Environmental expenditures that relate to an existing condition caused by past operations and that do not contribute to current or future revenue generation are expensed. Environmental liabilities are accrued when environmental assessments and/or clean-ups are probable, and the costs can be reasonably estimated. Recent case law in Wyoming has exposed the Company 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 March 31, 2019, the Company had open contracts with customers with terms of 1 month to 19 years, as well as evergreen contracts that renew on a periodic basis if not canceled by the Company or the customer. The Company's contracts with customers typically require payment within one month of delivery.

Under the Company's contracts with customers, natural gas and its components, including NGLs, are either sold to a midstream entity (which processes the natural gas and subsequently sells the resulting residue gas and NGLs) or are sold to a gas or NGL purchaser after being processed by a third party for a fee. Regardless of the contract structure type, the terms of these contracts compensate the Company for the value of the residue gas and NGLs at current market prices for each product. The Company's oil is sold to multiple oil purchasers at specific delivery points at or near the wellhead. All costs incurred to gather, transport and/or process the Company's oil, gas and NGLs after control has transferred to the customer are considered components of the consideration received from the customer and thus recorded in oil, gas and NGL production revenues in the Unaudited Consolidated Statements of Operations. All costs incurred prior to the transfer of control to the customer are included in gathering, transportation and processing expense in the Unaudited Consolidated Statements of Operations.

Gas imbalances from the sale of natural gas are recorded on the basis of gas actually sold by the Company. If the Company's aggregate sales volumes for a well are greater (or less) than its proportionate share of production from the well, a liability (or receivable) is established to the extent there are insufficient proved reserves available to make-up the overproduced (or underproduced) imbalance. Imbalances have not been significant in the periods presented.

Derivative Instruments and Hedging Activities

Derivative Instruments and Hedging Activities. The Company periodically uses derivative financial instruments to achieve a more predictable cash flow from its oil, natural gas and NGL sales by reducing its exposure to price fluctuations. Derivative instruments are recorded at fair market value and are included in the Unaudited Consolidated Balance Sheets as assets or liabilities.

Income Taxes

Income Taxes. Income taxes are provided for the tax effects of transactions reported in the financial statements and consist of taxes currently payable plus deferred income taxes related to certain income and expenses recognized in different periods for financial and income tax reporting purposes. Deferred income tax assets and liabilities represent the future tax return consequences of those differences, which will either be taxable or deductible when assets are recovered or liabilities are settled. Deferred income taxes also include tax credits and net operating losses that are available to offset future income taxes. Deferred income taxes are measured by applying currently enacted tax rates. 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, increases in market prices for hydrocarbons, improvements in operating results, or other factors 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 March 31, 2019.

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. As the Company was in a net loss position, all potentially dilutive securities were anti-dilutive for the three months ended March 31, 2019 and 2018.

The following table sets forth the calculation of basic and diluted income (loss) per share:

	Three Months Ended March 31,
	2019			2018
	(in thousands, except per share amounts)
Net income (loss)	$	(96,229	)	$	(24,937	)
Basic weighted-average common shares outstanding in period	209,932			123,596
Diluted weighted-average common shares outstanding in period	209,932			123,596
Basic net income (loss) per common share	$	(0.46	)	$	(0.20	)
Diluted net income (loss) per common share	$	(0.46	)	$	(0.20	)

New Accounting Pronouncements

New Accounting Pronouncements. In August 2018, the Financial Accounting Standards Board ("FASB") issued Accounting Standards Update ("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 will only impact the Company's disclosures.

In June 2018, the FASB issued ASU 2018-07, Stock Compensation-Improvements to Non-employee Share-Based Payment Accounting. The objective of this update was to simplify several aspects of the accounting for non-employee share-based payment transactions resulting from expanding the scope of Topic 718, Compensation- Stock Compensation, to include share-based payment transactions for acquiring goods and services from non-employees. ASU 2018-07 was effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods. The standard was adopted on January 1, 2019 and did not have a material impact on the Company's disclosures and financial statements.

In February 2016, the FASB issued ASU 2016-02, Leases, followed by additional accounting standards updates that provided additional practical expedients and policy election options (collectively, Accounting Standards Codification Topic 842 ("ASC 842")). The objective of ASC 842 was to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclose key information about leasing arrangements. ASC 842 was effective for annual periods beginning after December 15, 2018, and interim periods within those annual periods. The Company adopted ASC 842 effective January 1, 2019 using the modified retrospective method and elected the option to not apply ASC 842 to comparative periods. The Company also elected the following practical expedients:

• not to recognize lease assets or liabilities on the balance sheet when lease terms are less than 12 months,

• carryforward previous conclusions related to current lease classification under the previous lease accounting standard to lease classification for these existing leases under ASC 842,

• exclude from evaluation under ASC 842 land easements that existed or expired before adoption of ASC 842, and

• to combine lease and non-lease components for certain asset classes.

The adoption of ASC 842 resulted in the recognition of right-of-use assets of $8.6 million, and current and noncurrent lease liabilities of $0.3 million and $13.7 million, respectively, on the Unaudited Consolidated Balance Sheet as of January 1, 2019. The difference between the right-of-use assets and the total lease liability was related to lease incentives and deferred rent balances of $5.4 million, which were required to be netted against the right-of-use assets as of the implementation date of January 1, 2019. The Company's leases included office leases and other equipment, all classified as operating leases. The adoption of ASC 842 had no impact on the Company's Unaudited Consolidated Statements of Operations or Cash Flows. See Note 11 for additional information.

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Leases (Policies)

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

Leases

The Company currently has leases for office space and other equipment, all classified as operating leases. Under ASC 842, 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.

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Summary of Significant Accounting Policies (Tables)

3 Months Ended

Mar. 31, 2019

Accounting Policies [Abstract]

Summary of Accounts Receivable

Accounts receivable is comprised of the following:

	As of March 31, 2019			As of December 31, 2018
	(in thousands)
Oil, gas and NGL sales	$	45,626		$	44,860
Due from joint interest owners	10,543			27,435
Other	1,410			754
Allowance for doubtful accounts	(106		)	(106		)
Total accounts receivable	$	57,473		$	72,943

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 March 31, 2019			As of December 31, 2018
	(in thousands)
Proved properties	$	667,346		$	663,485
Wells and related equipment and facilities	1,518,824			1,438,092
Support equipment and facilities	88,901			75,392
Materials and supplies	21,600			18,341
Total proved oil and gas properties	$	2,296,671		$	2,195,310
Unproved properties	328,377			328,409
Wells and facilities in progress	162,491			139,799
Total unproved oil and gas properties, excluded from amortization	$	490,868		$	468,208
Accumulated depreciation, depletion, amortization and impairment	(714,237		)	(642,645		)
Total oil and gas properties, net	$	2,073,302		$	2,020,873

Accounts Payable and Accrued Liabilities

Accounts payable and other accrued liabilities are comprised of the following:

	As of March 31, 2019		As of December 31, 2018
	(in thousands)
Accrued drilling, completion and facility costs	$	92,905	$	69,830
Accrued lease operating, gathering, transportation and processing expenses	7,308		6,970
Accrued general and administrative expenses	6,513		8,774
Accrued interest payable	18,930		6,758
Accrued merger transaction expenses	682		550
Prepayments from partners	794		862
Trade payables	1,192		31,057
Operating lease liability	517		—
Other	6,921		6,578
Total accounts payable and other accrued liabilities	$	135,762	$	131,379

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 March 31,
	2019			2018
	(in thousands, except per share amounts)
Net income (loss)	$	(96,229	)	$	(24,937	)
Basic weighted-average common shares outstanding in period	209,932			123,596
Diluted weighted-average common shares outstanding in period	209,932			123,596
Basic net income (loss) per common share	$	(0.46	)	$	(0.20	)
Diluted net income (loss) per common share	$	(0.46	)	$	(0.20	)

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Supplemental Disclosures of Cash Flow Information (Tables)

3 Months Ended

Mar. 31, 2019

Supplemental Cash Flow Elements [Abstract]

Supplemental Cash Flow Information

Supplemental cash flow information is as follows:

	Three Months Ended March 31,
	2019			2018
	(in thousands)
Cash paid for interest	$	868		$	395
Cash paid for income taxes	—			—
Cash paid for amounts included in the measurements of lease liabilities:
Operating cash flows from operating leases	229			—
Non-cash operating activities:
Right-of-use assets obtained in exchange for lease obligations
Operating leases (1)	14,667			—
Non-cash investing and financing activities:
Accrued liabilities - oil and gas properties	92,702			67,047
Change in asset retirement obligations, net of disposals	933			7,513
Retirement of treasury stock	(1,484		)	(1,462		)
Issuance of common stock for Merger	—			484,000

(1) Excludes the reclassifications of lease incentives and deferred rent balances.

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Merger (Tables)

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

Schedule of Recognized Identified Assets Acquired and Liabilities Assumed

The following table sets forth the Company's purchase price allocation:

	March 19, 2018
	(in thousands)
Purchase Price:
Fair value of common stock issued	$	484,000
Plus: Repayment of Fifth Creek debt	53,900
Total purchase price	537,900
Plus Liabilities Assumed:
Accounts payable and accrued liabilities	25,782
Current unfavorable contract	2,651
Other current liabilities	13,797
Asset retirement obligations	7,361
Long-term deferred tax liability	137,707
Long-term unfavorable contract	4,449
Other noncurrent liabilities	2,354
Total purchase price plus liabilities assumed	$	732,001
Fair Value of Assets Acquired:
Cash	543
Accounts receivable	7,831
Oil and Gas Properties:
Proved oil and gas properties	105,702
Unproved oil and gas properties	609,568
Asset retirement obligations	7,361
Furniture, equipment and other	931
Other noncurrent assets	65
Total asset value	$	732,001

Business Acquisition, Pro Forma Information

The pro forma condensed combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the acquisition taken place on January 1, 2018; furthermore, the financial information is not intended to be a projection of future results.

	Three Months Ended March 31,
	2019			2018
	(in thousands, except per share data)
Revenues	$	101,980		$	96,742
Net Income (Loss)	(93,815		)	(24,104		)
Net Income (Loss) per Common Share, Basic	(0.45		)	(0.12		)
Net Income (Loss) per Common Share, Diluted	(0.45		)	(0.12		)

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Long-Term Debt (Tables)

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Outstanding Debt

The Company's outstanding debt is summarized below:

		As of March 31, 2019							As of December 31, 2018
	Maturity Date	Principal		Debt Issuance Costs			Carrying Amount		Principal		Debt Issuance Costs			Carrying Amount
		(in thousands)
Amended Credit Facility (1)	September 14, 2023	$	70,000	$	—		$	70,000	$	—	$	—		$	—
7.0% Senior Notes (2)	October 15, 2022	350,000		(3,000		)	347,000		350,000		(3,210		)	346,790
8.75% Senior Notes (3)	June 15, 2025	275,000		(4,232		)	270,768		275,000		(4,403		)	270,597
Lease Financing Obligation (4)	August 10, 2020	—		—			—		1,859		—			1,859
Total Debt		$	695,000	$	(7,232	)	$	687,768	$	626,859	$	(7,613	)	$	619,246
Less: Current Portion of Long-Term Debt (5)		—		—			—		1,859		—			1,859
Total Long-Term Debt		$	695,000	$	(7,232	)	$	687,768	$	625,000	$	(7,613	)	$	617,387

(1) The recorded value of the Amended Credit Facility approximates its fair value due to its floating rate structure and on financing terms currently available to the Company.

(2) The aggregate estimated fair value of the 7.0% Senior Notes was approximately $332.7 million and $329.7 million as of March 31, 2019 and December 31, 2018, respectively, based on reported market trades of these instruments.

(3) The aggregate estimated fair value of the 8.75% Senior Notes was approximately $263.3 million and $264.7 million as of March 31, 2019 and December 31, 2018, respectively, based on reported market trades of these instruments.

(4) The aggregate estimated fair value of the Lease Financing Obligation was approximately $1.8 million as of December 31, 2018, based on market-based parameters of comparable term secured financing instruments. The Company exercised the early buyout option and purchased the equipment for $1.8 million on February 10, 2019.

(5) As of December 31, 2018, the current portion of long-term debt included the Lease Financing Obligation, which was settled on February 10, 2019.

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Asset Retirement Obligations (Tables)

3 Months Ended

Mar. 31, 2019

Asset Retirement Obligation Disclosure [Abstract]

Schedule of Asset Retirement Obligations

A reconciliation of the Company's asset retirement obligations for the three months ended March 31, 2019 is as follows (in thousands):

As of December 31, 2018	$	29,655
Liabilities incurred	864
Liabilities settled	(258		)
Disposition of properties	(73		)
Accretion expense	384
Revisions to estimate	400
As of March 31, 2019	$	30,972
Less: Current asset retirement obligations	3,648
Long-term asset retirement obligations	$	27,324

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2019

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

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 March 31, 2019
Financial Assets
Cash equivalents	$	37,762	$	—	$	—	$	37,762
Deferred compensation plan	1,679		—		—		1,679
Commodity derivatives	—		15,431		—		15,431
Financial Liabilities
Commodity derivatives	—		16,817		—		16,817
As of December 31, 2018
Financial Assets
Cash equivalents	12,188		—		—		12,188
Deferred compensation plan	1,392		—		—		1,392
Commodity derivatives	—		109,494		—		109,494
Financial Liabilities
Commodity derivatives	—		1,039		—		1,039

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Derivative Instruments (Tables)

3 Months Ended

Mar. 31, 2019

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 March 31, 2019
Balance Sheet	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet				Net Amounts of Assets Presented in the Balance Sheet
	(in thousands)
Derivative assets (current)	$	9,815		$	(8,396	)	(1)	$	1,419
Derivative assets (noncurrent)	5,616			(1,677		)	(1)	3,939
Total derivative assets	$	15,431		$	(10,073	)		$	5,358
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet				Net Amounts of Liabilities Presented in the Balance Sheet
	(in thousands)
Derivative liabilities	$	(14,246	)	$	8,396		(1)	$	(5,850	)
Other noncurrent liabilities	(2,571		)	1,677			(1)	(894		)
Total derivative liabilities	$	(16,817	)	$	10,073			$	(6,744	)
	As of December 31, 2018
Balance Sheet	Gross Amounts of Recognized Assets			Gross Amounts Offset in the Balance Sheet				Net Amounts of Assets Presented in the Balance Sheet
	(in thousands)
Derivative assets (current)	$	82,205		$	(1,039	)	(1)	$	81,166
Derivative assets (noncurrent)	27,289			—			(1)	27,289
Total derivative assets	$	109,494		$	(1,039	)		$	108,455
	Gross Amounts of Recognized Liabilities			Gross Amounts Offset in the Balance Sheet				Net Amounts of Liabilities Presented in the Balance Sheet
	(in thousands)
Derivative liabilities	$	(1,039	)	$	1,039		(1)	$	—
Other noncurrent liabilities	—			—			(1)	—
Total derivative liabilities	$	(1,039	)	$	1,039			$	—

(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 March 31, 2019, the Company had swap contracts in place to hedge the following volumes for the periods indicated:

	April – December 2019			For the year 2020
	Derivative Volumes	Weighted Average Price		Derivative Volumes	Weighted Average Price
Oil (Bbls)	4,646,533	$	59.07	4,024,000	$	59.42
Natural Gas (MMbtu)	1,925,000	$	2.11	—	$	—

Cashless Collars

Derivative Instruments and Hedging Activities Disclosures [Line Items]

Financial Instruments for Hedging Volumes

As of March 31, 2019, the Company had cashless collars (purchased put options and written call options) in place to hedge the following volumes for the periods indicated:

	April – December 2019
	Derivative Volumes	Weighted Average Floor Price		Weighted Average Ceiling Price
Oil (Bbls)	552,000	$	55.00	$	77.56

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Equity Incentive Compensation Plans and Other Long-term Incentive Programs (Tables)

3 Months Ended

Mar. 31, 2019

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 March 31,
	2019		2018
	(in thousands)
Nonvested common stock (1)	$	1,796	$	1,330
Nonvested common stock units (1)	294		170
Nonvested performance cash units (2)(3)	632		(73		)
Total	$	2,722	$	1,427

(1) Unrecognized compensation expense as of March 31, 2019 was $11.2 million, which related to grants of nonvested shares of common stock that are expected to be recognized over a weighted-average period of 2.1 years.

(2) The nonvested performance-based cash units are accounted for as liability awards with $1.0 million and $0.3 million in other noncurrent liabilities as of March 31, 2019 and December 31, 2018, 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 Shares [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Nonvested Share Activity

A summary of the Company's nonvested common stock awards for the three months ended March 31, 2019 and 2018 is presented below:

	Three Months Ended March 31, 2019				Three Months Ended March 31, 2018
Nonvested Common Stock Awards	Shares		Weighted Average Grant Date Fair Value		Shares		Weighted Average Grant Date Fair Value
Outstanding at January 1,	2,912,166		$	5.27	1,394,868		$	7.00
Granted	1,835,700		2.64		796,423		5.00
Modified (1)	—		—		1,146,305		4.84
Vested	(1,299,599	)	5.19		(652,208	)	8.35
Forfeited or expired	(16,487	)	4.74		(27,853	)	6.62
Outstanding at March 31,	3,431,780		3.90		2,657,535		5.14

(1) Due to the closing of the Merger, the 2016 and 2017 Performance Cash Programs were converted from nonvested performance-based cash units to nonvested common stock awards, resulting in an increase in nonvested common stock awards for the three months ended March 31, 2018.

Nonvested Performance Cash Units

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Nonvested Performance-based Units Activity

A summary of the Company's nonvested performance-based cash unit awards for the three months ended March 31, 2019 and 2018 is presented below:

	Three Months Ended March 31, 2019				Three Months Ended March 31, 2018
Nonvested Performance-Based Cash Unit Awards	Units		Weighted Average Fair Value		Units		Weighted Average Fair Value
Outstanding at January 1,	909,585				1,548,083
Granted	2,026,521				796,423
Performance goal adjustment (1)	—				11,289
Modified (2)	—				(1,211,478	)
Vested	—				(286,652	)
Forfeited or expired	(67,472	)			(61,242	)
Outstanding at March 31,	2,868,634		$	2.21	796,423		$	5.08

(1) The 2015 Program vested at 104.1% in excess of target level and resulted in additional units vesting in March 2018. These units are included in the vested line item for the three months ended March 31, 2018.

(2) Due to the closing of the Merger, the 2016 and 2017 Performance Cash Programs were converted from nonvested performance-based cash units to nonvested common stock awards, resulting in a decrease in nonvested performance-based cash units for the three months ended March 31, 2018. The 2016 Program awards were converted based on performance through March 19, 2018, which resulted in 89% of the units converting to nonvested common stock awards or a reduction of 65,173 units converting to nonvested common stock awards.

Director [Member]

Share-based Compensation Arrangement by Share-based Payment Award [Line Items]

Schedule of Nonvested Share Activity

A summary of the Company's nonvested common stock unit awards for the three months ended March 31, 2019 and 2018 is presented below:

	Three Months Ended March 31, 2019				Three Months Ended March 31, 2018
Nonvested Common Stock Unit Awards	Units		Weighted Average Grant Date Fair Value		Units		Weighted Average Grant Date Fair Value
Outstanding at January 1,	311,237		$	7.26	272,559		$	6.37
Granted	14,704		2.21		3,198		5.08
Vested	(14,704	)	2.21		(3,198	)	5.08
Outstanding at March 31,	311,237		7.26		272,559		6.37

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Leases (Tables)

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

Lease, Cost

For the three months ended March 31, 2019, lease cost was as follows:

	Three Months Ended March 31,
Lease Cost	2019
	(in thousands)
Operating lease cost (1)(3)	$	548
Short-term lease cost (2)(3)	6,219
Total lease cost	$	6,767

(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.

Supplemental Balance Sheet Information, Leases

Supplemental balance sheet information related to leases as of March 31, 2019, was as follows:

Operating Leases	As of March 31, 2019
	(in thousands)
Right-of-use assets (1)	$	9,255
Accumulated amortization (2)	(352		)
Total right-of-use assets (5)	$	8,903
Current lease liabilities (3)	(517		)
Noncurrent lease liabilities (4)	(14,117		)
Total lease liabilities (5)	$	(14,634	)
Weighted average remaining lease term
Operating leases (in years)	8.4
Weighted average discount rate
Operating leases	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) Included in accounts payable and accrued liabilities in the Unaudited Consolidated Balance Sheets.

(4) Included in other noncurrent liabilities in the Unaudited Consolidated Balance Sheets.

(5) The difference between the right-of-use assets and total lease liabilities was primarily related to lease incentives and deferred rent balances, which were required to be netted against the right-of-use assets as of the implementation date of January 1, 2019.

Lessee, Operating Lease, Liability, Maturity

Maturities of lease liabilities as of March 31, 2019 were as follows:

	As of March 31, 2019
	(in thousands)
2019	$	1,026
2020	1,938
2021	2,230
2022	1,992
2023	2,024
Thereafter	9,654
Total	$	18,864
Less: Interest	(4,230		)
Present value of lease liabilities	$	14,634

Schedule of Future Minimum Rental Payments for Operating Leases [Table Text Block]

Minimum future contractual payments for operating leases under the scope of ASC 840 as of December 31, 2018 were as follows:

	As of December 31, 2018
	(in thousands)
2019	$	2,583
2020	3,032
2021	3,331
2022	3,263
2023	3,036
Thereafter	13,112
Total	$	28,357

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Commitments and Contingencies (Tables)

3 Months Ended

Mar. 31, 2019

Commitments and Contingencies Disclosure [Abstract]

Schedule Of Gross Future Minimum Volume Charges [Table Text Block]

The amounts in the table below represent the Company's future minimum charges under both agreements:

	As of March 31, 2019
	(in thousands)
2019 (1)	$	8,275
2020	2,167
2021	1,997
Thereafter	—
Total	$	12,439

(1) Includes $6.5 million associated with the reimbursement obligation discussed above.

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 March 31, 2019
	(in thousands)
2019	$	13,206
2020	18,400
2021	10,733
Thereafter	—
Total	$	42,339

Other Commitments

Future minimum annual payments under these agreements are as follows:

	As of March 31, 2019
	(in thousands)
2019	$	4,453
2020	1,490
2021	745
2022	745
2023	744
Thereafter	—
Total	$	8,177

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Parent Guarantor (Tables)

3 Months Ended

Mar. 31, 2019

Condensed Financial Information Disclosure [Abstract]

Schedule of Condensed Consolidating Balance Sheets

Condensed Consolidating Balance Sheets

	As of March 31, 2019
	Parent Guarantor		Subsidiary Issuer		Intercompany Eliminations			Consolidated
	(in thousands)
Assets:
Cash and cash equivalents	$	—	$	44,658	$	—		$	44,658
Accounts receivable, net of allowance for doubtful accounts	—		57,473		—			57,473
Other current assets	—		4,914		—			4,914
Property and equipment, net	—		2,096,160		—			2,096,160
Investment in subsidiaries	1,116,475		—		(1,116,475		)	—
Noncurrent assets	—		9,331		—			9,331
Total assets	$	1,116,475	$	2,212,536	$	(1,116,475	)	$	2,212,536
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	$	—	$	135,762	$	—		$	135,762
Other current liabilities	—		113,993		—			113,993
Long-term debt	—		687,768		—			687,768
Deferred income taxes	—		109,823		—			109,823
Other noncurrent liabilities	—		48,715		—			48,715
Stockholders' equity	1,116,475		1,116,475		(1,116,475		)	1,116,475
Total liabilities and stockholders' equity	$	1,116,475	$	2,212,536	$	(1,116,475	)	$	2,212,536

	As of December 31, 2018
	Parent Guarantor		Subsidiary Issuer		Intercompany Eliminations			Consolidated
	(in thousands)
Assets:
Cash and cash equivalents	$	—	$	32,774	$	—		$	32,774
Accounts receivable, net of allowance for doubtful accounts	—		72,943		—			72,943
Other current assets	—		84,064		—			84,064
Property and equipment, net	—		2,029,523		—			2,029,523
Investment in subsidiaries	1,212,098		—		(1,212,098		)	—
Noncurrent assets	—		33,156		—			33,156
Total assets	$	1,212,098	$	2,252,460	$	(1,212,098	)	$	2,252,460
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	$	—	$	131,379	$	—		$	131,379
Other current liabilities	—		116,806		—			116,806
Long-term debt	—		617,387		—			617,387
Deferred income taxes	—		139,534		—			139,534
Other noncurrent liabilities	—		35,256		—			35,256
Stockholders' equity	1,212,098		1,212,098		(1,212,098		)	1,212,098
Total liabilities and stockholders' equity	$	1,212,098	$	2,252,460	$	(1,212,098	)	$	2,252,460

Schedule of Condensed Consolidating Statements of Operations

Condensed Consolidating Statements of Operations

	Three Months Ended March 31, 2019
	Parent Guarantor			Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Operating and other revenues	$	—		$	101,980		$	—	$	101,980
Operating expenses	—			(94,290		)	—		(94,290		)
General and administrative	—			(12,660		)	—		(12,660		)
Merger transaction expense	—			(2,414		)	—		(2,414		)
Interest expense	—			(13,679		)	—		(13,679		)
Interest income and other income (expense)	—			(104,877		)	—		(104,877		)
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	—			(125,940		)	—		(125,940		)
(Provision for) benefit from income taxes	—			29,711			—		29,711
Equity in earnings (loss) of subsidiaries	(96,229		)	—			96,229		—
Net income (loss)	$	(96,229	)	$	(96,229	)	$	96,229	$	(96,229	)

	Three Months Ended March 31, 2018
	Parent Guarantor			Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Operating and other revenues	$	—		$	80,810		$	—	$	80,810
Operating expenses	—			(58,145		)	—		(58,145		)
General and administrative	—			(10,107		)	—		(10,107		)
Merger transaction expense	—			(4,763		)	—		(4,763		)
Interest expense	—			(13,090		)	—		(13,090		)
Interest income and other income (expense)	—			(19,642		)	—		(19,642		)
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	—			(24,937		)	—		(24,937		)
(Provision for) benefit from income taxes	—			—			—		—
Equity in earnings (loss) of subsidiaries	(24,937		)	—			24,937		—
Net income (loss)	$	(24,937	)	$	(24,937	)	$	24,937	$	(24,937	)

Schedule of Condensed Consolidating Statements of Cash Flows

Condensed Consolidating Statements of Cash Flows

	Three Months Ended March 31, 2019
	Parent Guarantor		Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Cash flows from operating activities	$	—	$	77,683		$	—	$	77,683
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	—		(130,862		)	—		(130,862		)
Additions to furniture, fixtures and other	—		(1,309		)	—		(1,309		)
Other investing activities	—		(273		)	—		(273		)
Cash flows from financing activities:
Proceeds from debt	—		70,000			—		70,000
Principal payments on debt	—		(1,859		)	—		(1,859		)
Other financing activities	—		(1,496		)	—		(1,496		)
Change in cash and cash equivalents	—		11,884			—		11,884
Beginning cash and cash equivalents	—		32,774			—		32,774
Ending cash and cash equivalents	$	—	$	44,658		$	—	$	44,658

	Three Months Ended March 31, 2018
	Parent Guarantor		Subsidiary Issuer			Intercompany Eliminations		Consolidated
	(in thousands)
Cash flows from operating activities	$	—	$	54,317		$	—	$	54,317
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	—		(88,854		)	—		(88,854		)
Additions to furniture, fixtures and other	—		(122		)	—		(122		)
Payment of acquiree's debt associated with merger, net of cash acquired	—		(53,357		)	—		(53,357		)
Other investing activities	—		(157		)	—		(157		)
Cash flows from financing activities:
Principal payments on debt	—		(116		)	—		(116		)
Other financing activities	—		(1,485		)	—		(1,485		)
Change in cash and cash equivalents	—		(89,774		)	—		(89,774		)
Beginning cash and cash equivalents	—		314,466			—		314,466
Ending cash and cash equivalents	$	—	$	224,692		$	—	$	224,692

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Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Jan. 01, 2019	Dec. 31, 2018
Property, Plant and Equipment [Line Items]
Right-of-use assets (1)	$ 8,903	$ 8,600
Current lease liabilities	517	300	$ 0
Noncurrent lease liabilities (4)	$ 14,117	13,700
Lease Incentives And Deferred Rent Reduction Of ROU Asset Beginning Balance		$ 5,400

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Summary of Significant Accounting Policies - Summary of Accounts Receivable (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Accounts, Notes, Loans and Financing Receivable [Line Items]
Allowance for doubtful accounts	$ (106)	$ (106)
Accounts receivable	57,473	72,943
Accrued Oil, Gas, and NGL Sales
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable gross	45,626	44,860
Due from Joint Interest Owners
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable gross	10,543	27,435
Other
Accounts, Notes, Loans and Financing Receivable [Line Items]
Accounts receivable gross	$ 1,410	$ 754

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Summary of Significant Accounting Policies - Net Capitalized Costs and Associated Accumulated Depreciation, Depletion & Amortization and Non Cash Impairments (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Accounting Policies [Abstract]
Proved properties	$ 667,346	$ 663,485
Wells and related equipment and facilities	1,518,824	1,438,092
Support equipment and facilities	88,901	75,392
Materials and supplies	21,600	18,341
Total proved oil and gas properties	2,296,671	2,195,310
Unproved properties	328,377	328,409
Wells and facilities in progress	162,491	139,799
Total unproved oil and gas properties, excluded from amortization	490,868	468,208
Accumulated depreciation, depletion, amortization and impairment	(714,237)	(642,645)
Total oil and gas properties, net	$ 2,073,302	$ 2,020,873

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Summary of Significant Accounting Policies - Accounts Payable and Accrued Liabilities (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Jan. 01, 2019	Dec. 31, 2018
Accounting Policies [Abstract]
Accrued drilling, completion and facility costs	$ 92,905		$ 69,830
Accrued lease operating, gathering, transportation and processing expenses	7,308		6,970
Accrued general and administrative expenses	6,513		8,774
Accrued interest payable	18,930		6,758
Accrued merger transaction expenses	682		550
Prepayments from partners	794		862
Trade payables	1,192		31,057
Operating lease liability	517	$ 300	0
Other	6,921		6,578
Total accounts payable and other accrued liabilities	$ 135,762		$ 131,379

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Summary of Significant Accounting Policies - Revenue Recognition (Details)	3 Months Ended
	Mar. 31, 2019
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	19 years

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Summary of Significant Accounting Policies - Calculation of Basic and Diluted Earnings (Loss) Per Share (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018
Accounting Policies [Abstract]
Net Income (Loss)	$ (96,229)	$ 222,423	$ (29,360)	$ (46,906)	$ (24,937)
Basic weighted-average common shares outstanding in period (in shares)	209,931,744				123,595,553
Diluted weighted-average common shares outstanding in period (in shares)	209,931,744				123,595,553
Net Income (Loss) Per Common Share, Basic (in dollars per share)	$ (0.46)				$ (0.20)
Net Income (Loss) Per Common Share, Diluted (in dollars per share)	$ (0.46)				$ (0.20)

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Supplemental Disclosures of Cash Flow Information - Supplemental Cash Flow Information (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Supplemental Cash Flow Information [Abstract]
Cash paid for interest	$ 868	$ 395
Cash paid for income taxes	0	0
Operating cash flows from operating leases	229	0
Operating leases (1)	14,667	0
Non-cash investing and financing activities:
Accrued liabilities - oil and gas properties	92,702	67,047
Change in asset retirement obligations, net of disposals	933	7,513
Retirement of treasury stock	(1,484)	(1,462)
Issuance of common stock for Merger	$ 0	$ 484,000

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Merger Narrative (Details) - USD ($)			3 Months Ended		12 Months Ended
	Mar. 31, 2018	Mar. 19, 2018	Mar. 31, 2019	Mar. 31, 2018	Mar. 31, 2019
Business Acquisition [Line Items]
Merger transaction expense			$ 2,414,000	$ 4,763,000
Fifth Creek
Business Acquisition [Line Items]
Business combination, pro forma information, revenue of acquiree since acquisition date, actual	$ 2,100,000
Business combination, pro forma information, expenses of acquiree since acquisition date, actual	$ 1,800,000
Business acquisition, equity interest issued or issuable, number of shares				100,000,000
Fair value of common stock issued		$ 484,000,000
Plus: Repayment of Fifth Creek debt		$ 53,900,000
Merger transaction expense					$ 19,200,000
Fifth Creek | Acquisition-related Costs
Business Acquisition [Line Items]
Merger transaction expense			$ 0	$ 4,000,000

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Merger Purchase Price Allocation (Details) - Fifth Creek $ in Thousands	Mar. 19, 2018 USD ($)
Purchase Price:
Fair value of common stock issued	$ 484,000
Plus: Repayment of Fifth Creek debt	53,900
Total purchase price	537,900
Plus Liabilities Assumed:
Accounts payable and accrued liabilities	25,782
Current unfavorable contract	2,651
Other current liabilities	13,797
Asset retirement obligations	7,361
Long-term deferred tax liability	137,707
Long-term unfavorable contract	4,449
Other noncurrent liabilities	2,354
Total purchase price plus liabilities assumed	732,001
Fair Value of Assets Acquired:
Cash	543
Accounts receivable	7,831
Oil and Gas Properties:
Proved oil and gas properties	105,702
Unproved oil and gas properties	609,568
Asset retirement obligations	7,361
Furniture, equipment and other	931
Other noncurrent assets	65
Total asset value	$ 732,001

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Merger Pro Forma (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Business Combinations [Abstract]
Revenues	$ 101,980	$ 96,742
Net Income (Loss)	$ (93,815)	$ (24,104)
Net Income (Loss) per Common Share, Basic (in usd per share)	$ (0.45)	$ (0.12)
Net Income (Loss) per Common Share, Diluted (in usd per share)	$ (0.45)	$ (0.12)

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Long-Term Debt - Outstanding Debt (Detail) - USD ($)	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 695,000,000	$ 625,000,000
Unamortized Debt Issuance Expense	(7,232,000)	(7,613,000)
Carrying Amount	687,768,000	617,387,000
Debt, fair value	$ 596,000,000	594,400,000
Amended Credit Facility
Debt Instrument [Line Items]
Maturity Date	Sep. 14, 2023
Debt Instrument, Face Amount	$ 70,000,000	0
Unamortized Debt Issuance Expense	0	0
Carrying Amount	70,000,000	0
7.0% Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Face Amount	350,000,000	350,000,000
Unamortized Debt Issuance Expense	(3,000,000)	(3,210,000)
Carrying Amount	$ 347,000,000	346,790,000
Debt, stated interest rate	7.00%
Debt, fair value	$ 332,700,000	329,700,000
8.75% Senior Notes
Debt Instrument [Line Items]
Debt Instrument, Face Amount	275,000,000	275,000,000
Unamortized Debt Issuance Expense	(4,232,000)	(4,403,000)
Carrying Amount	$ 270,768,000	270,597,000
Debt, stated interest rate	8.75%
Debt, fair value	$ 263,300,000	264,700,000
Lease Financing Obligation
Debt Instrument [Line Items]
Debt Instrument, Face Amount	0	1,859,000
Unamortized Debt Issuance Expense	0	0
Carrying Amount	0	1,859,000
Debt, fair value		1,800,000
Long-term Debt
Debt Instrument [Line Items]
Debt Instrument, Face Amount	695,000,000	626,859,000
Unamortized Debt Issuance Expense	(7,232,000)	(7,613,000)
Carrying Amount	687,768,000	619,246,000
Current Portion of Long-Term Debt
Debt Instrument [Line Items]
Debt Instrument, Face Amount	0	1,859,000
Unamortized Debt Issuance Expense	0	0
Carrying Amount	$ 0	$ 1,859,000

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Long-Term Debt - Additional Information (Detail) - USD ($)	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Principal amount	$ 695,000,000	$ 625,000,000
Debt, fair value	596,000,000	594,400,000
Purchase of equipment	1,800,000
Maximum Credit Amount, Maximum Commitments That Could Be Elected By Lenders	$ 1,500,000,000
Minimum
Debt Instrument [Line Items]
Revolving credit facility interest rate percent above LIBOR alternate interest rate	0.50%
Commitment fee percentage	0.375%
Revolving Credit Facility Interest Rate Percent Above Libor	1.50%
Maximum
Debt Instrument [Line Items]
Revolving credit facility interest rate percent above LIBOR alternate interest rate	1.50%
Commitment fee percentage	0.50%
Revolving Credit Facility Interest Rate Percent Above Libor	2.50%
Amended Credit Facility
Debt Instrument [Line Items]
Debt instrument, maturity date	Sep. 14, 2023
Line of credit facility, maximum borrowing capacity	$ 500,000,000
Debt, Weighted Average Interest Rate	4.00%
Letters of credit issued amount	$ 26,000,000
Line of credit facility, remaining borrowing capacity	404,000,000
Principal amount	70,000,000	0
7.0% Senior Notes
Debt Instrument [Line Items]
Principal amount	$ 350,000,000	350,000,000
Debt, stated interest rate	7.00%
Debt, fair value	$ 332,700,000	329,700,000
8.75% Senior Notes
Debt Instrument [Line Items]
Principal amount	$ 275,000,000	275,000,000
Debt, stated interest rate	8.75%
Debt, fair value	$ 263,300,000	264,700,000
Lease Financing Obligation
Debt Instrument [Line Items]
Principal amount	$ 0	1,859,000
Debt, fair value		$ 1,800,000

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Asset Retirement Obligations - Schedule of Asset Retirement Obligations (Detail) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
As of December 31, 2018	$ 29,655
Liabilities incurred	864
Liabilities settled	(258)
Disposition of properties	(73)
Accretion expense	384
Revisions to estimate	400
As of March 31, 2019	30,972
Less: Current asset retirement obligations	3,648
Long-term asset retirement obligations	$ 27,324

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Fair Value Measurements - Fair Value, Balance Sheet Grouping (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018	Mar. 31, 2018	Dec. 31, 2017
Financial Assets
Cash equivalents	$ 44,658	$ 32,774	$ 224,692	$ 314,466
Commodity derivatives	5,358	108,455
Financial Liabilities
Commodity derivatives	6,744	0
Total
Financial Assets
Cash equivalents	37,762	12,188
Deferred compensation plan	1,679	1,392
Commodity derivatives	15,431	109,494
Financial Liabilities
Commodity derivatives	16,817	1,039
Level 1
Financial Assets
Cash equivalents	37,762	12,188
Deferred compensation plan	1,679	1,392
Commodity derivatives	0	0
Financial Liabilities
Commodity derivatives	0	0
Level 2
Financial Assets
Cash equivalents	0	0
Deferred compensation plan	0	0
Commodity derivatives	15,431	109,494
Financial Liabilities
Commodity derivatives	16,817	1,039
Level 3
Financial Assets
Cash equivalents	0	0
Deferred compensation plan	0	0
Commodity derivatives	0	0
Financial Liabilities
Commodity derivatives	$ 0	$ 0

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Fair Value Measurements - Additional Information (Detail) - USD ($)	Mar. 31, 2019	Dec. 31, 2018
Fair Value Measurements [Line Items]
Unproved Oil and Gas Property, Successful Effort Method	$ 490,868,000	$ 468,208,000
Debt, fair value	596,000,000	594,400,000
Debt Instrument, Face Amount	$ 695,000,000	625,000,000
7.0% Senior Notes
Fair Value Measurements [Line Items]
Debt, stated interest rate	7.00%
Debt, fair value	$ 332,700,000	329,700,000
Debt Instrument, Face Amount	$ 350,000,000	350,000,000
8.75% Senior Notes
Fair Value Measurements [Line Items]
Debt, stated interest rate	8.75%
Debt, fair value	$ 263,300,000	264,700,000
Debt Instrument, Face Amount	275,000,000	275,000,000
Amended Credit Facility
Fair Value Measurements [Line Items]
Debt Instrument, Face Amount	70,000,000	0
Lease Financing Obligation
Fair Value Measurements [Line Items]
Debt, fair value		1,800,000
Debt Instrument, Face Amount	$ 0	$ 1,859,000

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Derivative Instruments - Fair Value Amounts of Derivative Instruments (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets	$ 15,431	$ 109,494
Gross Amounts Offset in the Balance Sheet	(10,073)	(1,039)
Net Amounts of Assets Presented in the Balance Sheet	5,358	108,455
Gross Amounts of Recognized Liabilities	(16,817)	(1,039)
Gross Amounts Offset in the Balance Sheet	10,073	1,039
Net Amounts of Liabilities Presented in the Balance Sheet	(6,744)	0
Derivative assets (current)
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets	9,815	82,205
Gross Amounts Offset in the Balance Sheet	(8,396)	(1,039)
Net Amounts of Assets Presented in the Balance Sheet	1,419	81,166
Derivative assets (noncurrent)
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Assets	5,616	27,289
Gross Amounts Offset in the Balance Sheet	(1,677)	0
Net Amounts of Assets Presented in the Balance Sheet	3,939	27,289
Derivative liabilities
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Liabilities	(14,246)	(1,039)
Gross Amounts Offset in the Balance Sheet	8,396	1,039
Net Amounts of Liabilities Presented in the Balance Sheet	(5,850)	0
Other noncurrent liabilities
Derivatives, Fair Value [Line Items]
Gross Amounts of Recognized Liabilities	(2,571)	0
Gross Amounts Offset in the Balance Sheet	1,677	0
Net Amounts of Liabilities Presented in the Balance Sheet	$ (894)	$ 0

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Derivative Instruments - Financial Instruments for Hedging Volume (Detail)	Mar. 31, 2019 MMBTU $ / unit bbl
April – December 2019 | Swap contracts | Oil (Bbls)
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	4,646,533
Weighted Average Price (usd per unit)	59.07
April – December 2019 | Swap contracts | Natural Gas (MMbtu)
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed natural gas volume | MMBTU	1,925,000
Weighted Average Price (usd per unit)	2.11
April – December 2019 | Cashless Collars | Oil (Bbls)
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	552,000
Weighted Average Floor Price (usd per unit)	55.00
Weighted Average Ceiling Price (usd per unit)	77.56
For the year 2020 | Swap contracts | Oil (Bbls)
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed oil volume | bbl	4,024,000
Weighted Average Price (usd per unit)	59.42
For the year 2020 | Swap contracts | Natural Gas (MMbtu)
Derivative Instruments, Gain (Loss) [Line Items]
Hedge backed natural gas volume | MMBTU	0
Weighted Average Price (usd per unit)	0.00

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Derivative Instruments - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019 counterparty
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Number of counterparties for hedges at period end	10

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Income Taxes - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Operating Loss Carryforwards [Line Items]
Income Tax Expense (Benefit)	$ (29,711)	$ 0

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Equity Incentive Compensation Plans and Other Long-term Incentive Programs - Additional Information (Detail) $ / shares in Units, $ in Millions	3 Months Ended		12 Months Ended
	Mar. 31, 2019 USD ($) $ / shares shares	Mar. 31, 2018 shares	Dec. 31, 2018 USD ($) integer $ / shares
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Common Stock, Par or Stated Value Per Share (in dollars per share) | $ / shares	$ 0.001		$ 0.001
Unrecognized compensation cost | $	$ 11.2
Weighted-average period (years)	2 years 1 month 6 days
Nonvested Equity Shares
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Award vesting period	3 years
Total shares granted (in shares)	1,835,700	796,423
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares)	1,299,599	652,208
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
Nonvested Performance Cash Units
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Deferred Compensation Cash-based Arrangements, Liability, Classified, Noncurrent | $	$ 1.0		$ 0.3
Total shares granted (in shares)	2,026,521	796,423
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares)	0	286,652
Two Thousand And Fifteen Performance Program [Member]
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Percent of Performance Based Shares Vested			104.10%
Two Thousand And Sixteen Performance Program [Member]
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Percentage Of Original Award Converted To Nonvested Common Stock Award			89.00%
Number Of Units Not Converted To Nonvested Common Stock | integer			65,173
Two Thousand Eighteen Performance Program [Domain]
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Performance Goal Measurement Period	3 years
Closing Share Price, December 31, 2018 | $ / shares	$ 2.49
Absolute Performance Is Less Than 50%	50.00%
Payout Is Zero If Absolute Performance Is Less Than 50%	0.00%
Absolute Performance Is 50%	50.00%
Payout Is 50% If Absolute Performance Is 50%	50.00%
Absolute Performance Is 100%	100.00%
Payout Is 100% If Absolute Performance Is 100%	100.00%
Relative TSR Is Less Than 30%	30.00%
Payout Is Zero If Relative TSR Is Less Than 30%	0.00%
Relative TSR Is 30% Or Greater	30.00%
Payout Is Equal To Percentile Rank, Up To 100%, If Relative TSR Is Greater Than 30%	100.00%
Two Thousand Eighteen Performance Program [Domain] | Absolute Performance and Relative TSR | Maximum
Deferred Compensation Arrangement with Individual, Excluding Share-based Payments and Postretirement Benefits [Line Items]
Award vesting rights, percentage	200.00%

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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
	Mar. 31, 2019	Mar. 31, 2018
Stock Based Compensation [Line Items]
Non-cash stock-based compensation equity awards	$ 2,722	$ 1,427
Nonvested Equity Shares [Member]
Stock Based Compensation [Line Items]
Non-cash stock-based compensation equity awards	1,796	1,330
Nonvested Equity Common Stock Units
Stock Based Compensation [Line Items]
Non-cash stock-based compensation equity awards	294	170
Nonvested Performance Cash Units
Stock Based Compensation [Line Items]
Cash Unit Based Compensation Awards	$ 632	$ (73)

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Equity Incentive Compensation Plans and Other Long-term Incentive Programs - Stock Options and Nonvested Equity Shares, Equity Awards Granted (Detail) - $ / shares	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018	Dec. 31, 2017
Nonvested Equity Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number (in shares)	3,431,780	2,657,535	2,912,166	1,394,868
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares)	(1,299,599)	(652,208)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value (in dollars per share)	$ 5.19	$ 8.35
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period (in shares)	(16,487)	(27,853)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeitures, Weighted Average Grant Date Fair Value (in dollars per share)	$ 4.74	$ 6.62
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value (in dollars per share)	$ 3.90	$ 5.14	$ 5.27	$ 7.00
Total shares granted (in shares)	1,835,700	796,423
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value (in dollars per share)	$ 2.64	$ 5.00
Share-based Compensation Arrangement by Share-based Payment Award, Shares Modified in Period	0	1,146,305
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Modified Shares in Period, Weighted Average Grant Date Fair Value	$ 0.00	$ 4.84
Nonvested Performance Cash Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number (in shares)	2,868,634	796,423	909,585	1,548,083
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares)	0	(286,652)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Forfeited in Period (in shares)	(67,472)	(61,242)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value (in dollars per share)	$ 2.21	$ 5.08
Total shares granted (in shares)	2,026,521	796,423
Share-Based Compensation, Performance Goal Adjustment (in shares)	0	11,289
Share Based Compensation, Modification (in shares)	0	1,211,478
Director [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Number (in shares)	311,237	272,559	311,237	272,559
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period (in shares)	(14,704)	(3,198)
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value (in dollars per share)	$ 2.21	$ 5.08
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value (in dollars per share)	$ 7.26	$ 6.37	$ 7.26	$ 6.37
Total shares granted (in shares)	14,704	3,198
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Grants in Period, Weighted Average Grant Date Fair Value (in dollars per share)	$ 2.21	$ 5.08

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Leases Additional Details (Details)	Mar. 31, 2019
Leases [Abstract]
Term of contract	9 years

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Leases Lease Cost (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Leases [Abstract]
Operating lease cost	$ 548
Short-term lease cost	6,219
Total lease cost	$ 6,767

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Leases Supplemental Balance Sheet (Details) - USD ($) $ in Thousands	Mar. 31, 2019	Jan. 01, 2019	Dec. 31, 2018
Leases [Abstract]
Right-of-use assets	$ 9,255
Accumulated amortization	(352)
Total right-of-use assets	8,903	$ 8,600
Current lease liabilities	517	300	$ 0
Noncurrent lease liabilities	14,117	$ 13,700
Total lease liabilities	$ 14,634
Weighted average remaining lease term
Operating leases (in years)	8 years 4 months 25 days
Weighted average discount rate
Operating leases	5.60%

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Leases Maturity (Details) $ in Thousands	Mar. 31, 2019 USD ($)
Leases [Abstract]
2019	$ 1,026
2020	1,938
2021	2,230
2022	1,992
2023	2,024
Thereafter	9,654
Total	18,864
Less: Interest	4,230
Present value of lease liabilities	$ 14,634

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Leases ASC 840 Future Operating Lease Payments (Details) $ in Thousands	Dec. 31, 2018 USD ($)
Leases [Abstract]
2019	$ 2,583
2020	3,032
2021	3,331
2022	3,263
2023	3,036
Thereafter	13,112
Total	$ 28,357

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Commitments and Contingencies - Additional Information (Detail) $ in Millions	3 Months Ended
	Mar. 31, 2019 USD ($) agreement integer
Contingencies And Commitments [Line Items]
Reimbursement Obligation To Construct Gas Gathering And Processing Facilities | $	$ 6.5
Minimum Volume Commitment	1
Sale Leaseback Transaction Early Buyout Option To Purchase Equipment | $	$ 1.8
Number of Firm Transportation Contracts | agreement	2
Number Of GTP Reimbursement Obligations	1
Number Of Other Commitments	1
Reimbursement Obligation, Reimbursement Period	1 year

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Commitments and Contingencies - Gross Future Minimum Transportation Demand and Firm Processing Charges (Detail) $ in Thousands	Mar. 31, 2019 USD ($)
Commitments and Contingencies Disclosure [Abstract]
2019	$ 13,206
2020	18,400
2021	10,733
Thereafter	0
Total	$ 42,339

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Commitments and Contingencies - Other Commitments (Detail) $ in Thousands	Mar. 31, 2019 USD ($)
Other Commitments [Line Items]
2019	$ 4,453
2020	1,490
2021	745
2022	745
2023	744
Thereafter	0
Total	$ 8,177

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Commitments and Contingencies Commitments And Contingencies - Gross Future Minimum Volume Charges (Details) $ in Thousands	Mar. 31, 2019 USD ($)
Commitments and Contingencies - Gross Future Minimum Volume Charges [Abstract]
2019	$ 8,275
2020	2,167
2021	1,997
Thereafter	0
Total	$ 12,439

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Parent Guarantor - Schedule of Condensed Consolidating Balance Sheets (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2017
Assets:
Cash and cash equivalents	$ 44,658	$ 32,774			$ 224,692	$ 314,466
Accounts receivable, net of allowance for doubtful accounts	57,473	72,943
Other current assets	4,914	84,064
Property and equipment, net	2,096,160	2,029,523
Investment in subsidiaries	0	0
Noncurrent assets	9,331	33,156
Total	2,212,536	2,252,460
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	135,762	131,379
Other current liabilities	113,993	116,806
Long-term debt, net of debt issuance costs	687,768	617,387
Deferred income taxes	109,823	139,534
Other noncurrent liabilities	48,715	35,256
Stockholders' equity	1,116,475	1,212,098	$ 987,797	$ 1,015,203	1,060,340	598,554
Total liabilities and stockholders' equity	2,212,536	2,252,460
Intercompany Eliminations
Assets:
Cash and cash equivalents	0	0			0	0
Accounts receivable, net of allowance for doubtful accounts	0	0
Other current assets	0	0
Property and equipment, net	0	0
Investment in subsidiaries	(1,116,475)	(1,212,098)
Noncurrent assets	0	0
Total	(1,116,475)	(1,212,098)
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	0	0
Other current liabilities	0	0
Long-term debt, net of debt issuance costs	0	0
Deferred income taxes	0	0
Other noncurrent liabilities	0	0
Stockholders' equity	(1,116,475)	(1,212,098)
Total liabilities and stockholders' equity	(1,116,475)	(1,212,098)
Parent Guarantor | Reportable Legal Entities
Assets:
Cash and cash equivalents	0	0			0	0
Accounts receivable, net of allowance for doubtful accounts	0	0
Other current assets	0	0
Property and equipment, net	0	0
Investment in subsidiaries	1,116,475	1,212,098
Noncurrent assets	0	0
Total	1,116,475	1,212,098
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	0	0
Other current liabilities	0	0
Long-term debt, net of debt issuance costs	0	0
Deferred income taxes	0	0
Other noncurrent liabilities	0	0
Stockholders' equity	1,116,475	1,212,098
Total liabilities and stockholders' equity	1,116,475	1,212,098
Subsidiary Issuer | Reportable Legal Entities
Assets:
Cash and cash equivalents	44,658	32,774			$ 224,692	$ 314,466
Accounts receivable, net of allowance for doubtful accounts	57,473	72,943
Other current assets	4,914	84,064
Property and equipment, net	2,096,160	2,029,523
Investment in subsidiaries	0	0
Noncurrent assets	9,331	33,156
Total	2,212,536	2,252,460
Liabilities and Stockholders' Equity:
Accounts payable and other accrued liabilities	135,762	131,379
Other current liabilities	113,993	116,806
Long-term debt, net of debt issuance costs	687,768	617,387
Deferred income taxes	109,823	139,534
Other noncurrent liabilities	48,715	35,256
Stockholders' equity	1,116,475	1,212,098
Total liabilities and stockholders' equity	$ 2,212,536	$ 2,252,460

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Parent Guarantor - Schedule of Condensed Consolidating Statements of Operations (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018
Condensed Financial Statements, Captions [Line Items]
Operating revenues	$ 101,980				$ 80,810
Operating expenses	(94,290)				(58,145)
General and administrative	(12,660)				(10,107)
Merger transaction expense	(2,414)				(4,763)
Interest Expense	(13,679)				(13,090)
Interest income and other income (expense)	(104,877)				(19,642)
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	(125,940)				(24,937)
(Provision for) Benefit from Income Taxes	29,711				0
Equity in earnings (loss) of subsidiaries	0				0
Net Income (Loss)	(96,229)	$ 222,423	$ (29,360)	$ (46,906)	(24,937)
Intercompany Eliminations
Condensed Financial Statements, Captions [Line Items]
Operating revenues	0				0
Operating expenses	0				0
General and administrative	0				0
Merger transaction expense	0				0
Interest Expense	0				0
Interest income and other income (expense)	0				0
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	0				0
(Provision for) Benefit from Income Taxes	0				0
Equity in earnings (loss) of subsidiaries	96,229				24,937
Net Income (Loss)	96,229				24,937
Parent Guarantor | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Operating revenues	0				0
Operating expenses	0				0
General and administrative	0				0
Merger transaction expense	0				0
Interest Expense	0				0
Interest income and other income (expense)	0				0
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	0				0
(Provision for) Benefit from Income Taxes	0				0
Equity in earnings (loss) of subsidiaries	(96,229)				(24,937)
Net Income (Loss)	(96,229)				(24,937)
Subsidiary Issuer | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Operating revenues	101,980				80,810
Operating expenses	(94,290)				(58,145)
General and administrative	(12,660)				(10,107)
Merger transaction expense	(2,414)				(4,763)
Interest Expense	(13,679)				(13,090)
Interest income and other income (expense)	(104,877)				(19,642)
Income (loss) before income taxes and equity in earnings (loss) of subsidiaries	(125,940)				(24,937)
(Provision for) Benefit from Income Taxes	29,711				0
Equity in earnings (loss) of subsidiaries	0				0
Net Income (Loss)	$ (96,229)				$ (24,937)

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Parent Guarantor - Schedule of Condensed Consolidating Statements of Cash Flows (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	$ 77,683	$ 54,317
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	(130,862)	(88,854)
Additions to furniture, fixtures and other	(1,309)	(122)
Repayment of debt associated with merger, net of cash acquired	0	(53,357)
Other investing activities	(273)	(157)
Cash flows from financing activities:
Proceeds from debt	70,000
Principal payments on debt	(1,859)	(116)
Other financing activities	(1,496)	(1,485)
Increase (Decrease) in Cash and Cash Equivalents	11,884	(89,774)
Beginning Cash and Cash Equivalents	32,774	314,466
Ending Cash and Cash Equivalents	44,658	224,692
Intercompany Eliminations
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	0	0
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	0	0
Additions to furniture, fixtures and other	0	0
Repayment of debt associated with merger, net of cash acquired		0
Other investing activities	0	0
Cash flows from financing activities:
Proceeds from debt	0
Principal payments on debt	0	0
Other financing activities	0	0
Increase (Decrease) in Cash and Cash Equivalents	0	0
Beginning Cash and Cash Equivalents	0	0
Ending Cash and Cash Equivalents	0	0
Parent Guarantor | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	0	0
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	0	0
Additions to furniture, fixtures and other	0	0
Repayment of debt associated with merger, net of cash acquired		0
Other investing activities	0	0
Cash flows from financing activities:
Proceeds from debt	0
Principal payments on debt	0	0
Other financing activities	0	0
Increase (Decrease) in Cash and Cash Equivalents	0	0
Beginning Cash and Cash Equivalents	0	0
Ending Cash and Cash Equivalents	0	0
Subsidiary Issuer | Reportable Legal Entities
Condensed Financial Statements, Captions [Line Items]
Cash flows from operating activities	77,683	54,317
Cash flows from investing activities:
Additions to oil and gas properties, including acquisitions	(130,862)	(88,854)
Additions to furniture, fixtures and other	(1,309)	(122)
Repayment of debt associated with merger, net of cash acquired		(53,357)
Other investing activities	(273)	(157)
Cash flows from financing activities:
Proceeds from debt	70,000
Principal payments on debt	(1,859)	(116)
Other financing activities	(1,496)	(1,485)
Increase (Decrease) in Cash and Cash Equivalents	11,884	(89,774)
Beginning Cash and Cash Equivalents	32,774	314,466
Ending Cash and Cash Equivalents	$ 44,658	$ 224,692