Jagged Peak Energy 10-Q 8 Nov 17 2017 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2017	Nov. 03, 2017
Document And Entity Information [Abstract]
Document Type	10-Q
Document Fiscal Year Focus	2,017
Amendment Flag	false
Document Period End Date	Sep. 30, 2017
Document Fiscal Period Focus	Q3
Entity Registrant Name	Jagged Peak Energy Inc.
Entity Central Index Key	1,685,715
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Entity Common Stock, Shares Outstanding		212,930,655

CONSOLIDATED AND COMBINED BALAN

CONSOLIDATED AND COMBINED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
CURRENT ASSETS
Cash and cash equivalents	$ 3,900	$ 11,727
Accounts receivable	35,088	10,327
Derivative instruments	5,515	0
Other current assets	4,147	3,412
Total current assets	48,650	25,466
PROPERTY AND EQUIPMENT
Oil and natural gas properties, successful efforts method	1,006,747	531,121
Accumulated depletion	(123,448)	(57,529)
Total oil and gas properties, net	883,299	473,592
Other property and equipment, net	6,499	3,001
Total property and equipment, net	889,798	476,593
OTHER NONCURRENT ASSETS
Unamortized debt issuance costs	2,537	1,503
Derivative instruments	5,170	0
Other assets	121	14,830
Total noncurrent assets	7,828	16,333
TOTAL ASSETS	946,276	518,392
CURRENT LIABILITIES
Accounts payable	13,975	7,629
Accrued liabilities	106,488	39,225
Derivative instruments	8,820	9,567
Total current liabilities	129,283	56,421
LONG-TERM LIABILITIES
Senior secured revolving credit facility	35,000	132,000
Derivative instruments	2,490	3,287
Asset retirement obligations	690	448
Deferred income taxes	101,039	0
Other long-term liabilities	2,526	124
Total long-term liabilities	141,745	135,859
Commitments and contingencies
STOCKHOLDERS’ / MEMBERS’ EQUITY
Members' equity	0	346,098
Preferred stock, $0.01 par value, 50,000,000 shares authorized, no shares issued at September 30, 2017; no shares authorized or issued at December 31, 2016	0
Common stock, $0.01 par value; 1,000,000,000 shares authorized, 212,930,655 shares issued at September 30, 2017; no shares authorized or issued at December 31, 2016	2,129	0
Additional paid-in capital	762,340
Accumulated deficit	(89,221)	(19,986)
Total stockholders’ / members’ equity	675,248	326,112
TOTAL LIABILITIES AND STOCKHOLDERS’ / MEMBERS’ EQUITY	$ 946,276	$ 518,392

CONSOLIDATED AND COMBINED BALA3

CONSOLIDATED AND COMBINED BALANCE SHEETS (Parenthetical) - $ / shares	Sep. 30, 2017	Dec. 31, 2016
Statement of Financial Position [Abstract]
Preferred stock par value (in dollars per share)	$ 0.01	$ 0.01
Preferred stock shares authorized (in shares)	50,000,000	0
Preferred stock shares issued (in shares)	0	0
Common stock par value (in dollars per share)	$ 0.01	$ 0.01
Common stock shares authorized (in shares)	1,000,000,000	0
Common stock shares issued (in shares)	212,930,655	0

CONSOLIDATED AND COMBINED STATE

CONSOLIDATED AND COMBINED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
REVENUES
Oil sales	$ 62,585	$ 20,332	$ 147,738	$ 47,215
Natural gas sales	2,939	731	5,697	1,450
NGL sales	4,860	819	9,041	2,023
Other operating revenues	67	182	414	957
Total revenues	70,451	22,064	162,890	51,645
OPERATING EXPENSES
Lease operating expenses	5,184	2,285	10,684	5,254
Gathering and transportation expenses	1,357	294	2,404	662
Production and ad valorem taxes	4,739	1,341	10,916	3,173
Exploration	6	0	14	2,474
Depletion, depreciation, amortization and accretion	30,851	11,152	67,224	29,430
Impairment of unproved oil and natural gas properties	257	7	365	317
General and administrative expenses (including equity-based compensation of $11,903 and $0 for the three months ended September 30, 2017 and 2016, respectively, and $431,642 and $0 for the nine months ended September 30, 2017 and 2016, respectively)	17,733	2,375	449,504	7,878
Other operating expenses	41	169	223	567
Total operating expenses	60,168	17,623	541,334	49,755
INCOME (LOSS) FROM OPERATIONS	10,283	4,441	(378,444)	1,890
OTHER INCOME (EXPENSE)
Gain (loss) on commodity derivatives	(27,693)	1,728	15,922	(8,208)
Interest expense, net	(467)	(759)	(1,610)	(1,471)
Other, net	60	0	474	0
Total other income (expense)	(28,100)	969	14,786	(9,679)
INCOME (LOSS) BEFORE INCOME TAX	(17,817)	5,410	(363,658)	(7,789)
Income tax expense (benefit)	(2,598)	0	101,039	0
NET INCOME (LOSS)	$ (15,219)	5,410	$ (464,697)	(7,789)
Net income (loss) attributable to Jagged Peak Energy Inc. Stockholders per common share:
Basic (in dollars per share)	$ (0.07)		$ (0.42)
Diluted (in dollars per share)	$ (0.07)		$ (0.42)
Weighted-average common shares outstanding:
Basic (in shares)	212,931		212,933
Diluted (in shares)	212,931		212,933
Predecessor
OTHER INCOME (EXPENSE)
NET INCOME (LOSS)	$ 0	5,410	$ (375,476)	(7,789)
Successor
OTHER INCOME (EXPENSE)
NET INCOME (LOSS)	$ (15,219)	$ 0	$ (89,221)	$ 0

CONSOLIDATED AND COMBINED STAT5

CONSOLIDATED AND COMBINED STATEMENTS OF OPERATIONS (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Statement of Financial Position [Abstract]
Equity-based compensation	$ 11,903	$ 0	$ 431,642	$ 0

CONSOLIDATED AND COMBINED STAT6

CONSOLIDATED AND COMBINED STATEMENT OF CHANGES IN EQUITY - USD ($) shares in Thousands, $ in Thousands	Total	Members' Equity	Common Stock	Additional Paid-in Capital	Accumulated Deficit
Beginning Balance (Predecessor) at Dec. 31, 2016	$ 326,112	$ 346,098	$ 0	$ 0	$ (19,986)
Beginning Balance at Dec. 31, 2016	326,112
Beginning Balance (in shares) (Predecessor) at Dec. 31, 2016			0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Deemed contribution - incentive unit compensation | Predecessor	364,314	364,314
Net income (loss) | Predecessor	(375,476)				(375,476)
Net income (loss)	(375,476)
Ending Balance (Predecessor) at Jan. 26, 2017	314,950	710,412	$ 0	0	(395,462)
Ending Balance (in shares) (Predecessor) at Jan. 26, 2017			0
Beginning Balance (Predecessor) at Dec. 31, 2016	326,112	346,098	$ 0	0	(19,986)
Beginning Balance at Dec. 31, 2016	326,112
Beginning Balance (in shares) (Predecessor) at Dec. 31, 2016			0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income (loss) | Predecessor	(375,476)
Net income (loss)	(464,697)
Ending Balance at Sep. 30, 2017	675,248	0	$ 2,129	762,340	(89,221)
Ending Balance (in shares) at Sep. 30, 2017			212,931
Beginning Balance (Predecessor) at Jan. 26, 2017	314,950	710,412	$ 0	0	(395,462)
Beginning Balance (in shares) (Predecessor) at Jan. 26, 2017			0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of common stock in corporate reorganization		(710,412)	$ 1,846	313,104	395,462
Issuance of common stock in corporate reorganization (in shares)			184,605
Issuance of common stock in initial public offering, net of offering costs	396,991		$ 283	396,708
Issuance of common stock in initial public offering, net of offering costs (in shares)			28,333
Common stock reacquired and retired	(88)			(88)
Common stock reacquired and retired (in shares)			(7)
Equity-based compensation	52,616			52,616
Net income (loss)	(89,221)				(89,221)
Ending Balance at Sep. 30, 2017	$ 675,248	$ 0	$ 2,129	$ 762,340	$ (89,221)
Ending Balance (in shares) at Sep. 30, 2017			212,931

CONSOLIDATED AND COMBINED STAT7

CONSOLIDATED AND COMBINED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
CASH FLOWS FROM OPERATING ACTIVITIES
Net income (loss)	$ (464,697)	$ (7,789)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depletion, depreciation, amortization and accretion	67,224	29,430
Management incentive unit advance	0	(14,712)
Impairment of unproved oil and natural gas properties	365	317
Exploratory dry hole costs	0	1,192
Amortization of debt issuance costs	407	164
Deferred income taxes	101,039	0
Equity-based compensation	431,642	0
(Gain) loss on commodity derivatives	(15,922)	8,208
Net cash receipts (payments) on settled derivatives	3,691	(1,159)
Other	(123)	(120)
Change in operating assets and liabilities:
Accounts receivable and other current assets	(27,292)	(545)
Other assets	(3)	11
Accounts payable and accrued liabilities	9,097	1,825
Net cash provided by operating activities	105,428	16,822
CASH FLOWS FROM INVESTING ACTIVITIES
Leasehold and acquisition costs	(60,627)	(39,344)
Development of oil and natural gas properties	(349,176)	(84,809)
Other capital expenditures	(3,332)	(1,831)
Net cash used in investing activities	(413,135)	(125,984)
CASH FLOWS FROM FINANCING ACTIVITIES
Proceeds from issuance of common stock in initial public offering, net of underwriting fees	401,625	0
Proceeds from common units issued	0	31,542
Proceeds from credit facility	45,000	70,000
Repayment of credit facility	(142,000)	0
Debt issuance costs	(1,441)	(1,030)
Costs relating to initial public offering	(3,216)	(95)
Employee tax withholding for settlement of equity compensation awards	(88)	0
Net cash provided by financing activities	299,880	100,417
NET CHANGE IN CASH AND CASH EQUIVALENTS	(7,827)	(8,745)
CASH AND CASH EQUIVALENTS, BEGINNING OF PERIOD	11,727	14,165
CASH AND CASH EQUIVALENTS, END OF PERIOD	3,900	5,420
SUPPLEMENTAL DISCLOSURES OF CASH FLOW INFORMATION
Interest paid, net of capitalized interest	1,234	1,189
Cash paid for income taxes	0	0
SUPPLEMENTAL DISCLOSURE OF NONCASH INVESTING ACTIVITIES
Accrued capital expenditures	102,031	22,853
Asset retirement obligations	488	(165)
SUPPLEMENTAL DISCLOSURE OF NONCASH FINANCING ACTIVITIES
Accrued offering costs	$ 0	$ 1,086

Organization, Operations and Ba

Organization, Operations and Basis of Presentation	9 Months Ended
	Sep. 30, 2017
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization, Operations and Basis of Presentation	Organization, Operations and Basis of Presentation Organization and Operations Jagged Peak Energy Inc. (either individually or together with its subsidiaries, as the context requires, “Jagged Peak” or the “Company”) is an independent oil and natural gas company focused on the acquisition and development of unconventional oil and associated liquids-rich natural gas reserves in the Southern Delaware Basin, a sub-basin of the Permian Basin of West Texas. The Company’s acreage is located on large, contiguous blocks in the adjacent counties of Winkler, Ward, Reeves and Pecos, with significant oil-in-place within multiple stacked hydrocarbon-bearing formations. Corporate Reorganization and Initial Public Offering Jagged Peak is a Delaware corporation formed in September 2016, as a wholly owned subsidiary of Jagged Peak Energy LLC (“JPE LLC”), a Delaware limited liability company formed in April 2013. JPE LLC was formed by an affiliate of Quantum Energy Partners (“Quantum”) and members of Jagged Peak’s management team. Jagged Peak was formed to become the holding company of JPE LLC in connection with Jagged Peak’s initial public offering (the “IPO”). Immediately prior to the IPO, all capital interests and management incentive units (“MIUs”) in JPE LLC were converted into a single class of units which were then converted into common stock. Certain members of management and employees contributed a portion of common stock received upon the conversion of unvested or unallocated MIUs to JPE Management Holdings LLC, a limited liability company formed in connection with the IPO for the purpose of holding the unvested or unallocated common stock. Also immediately prior to the IPO, a corporate reorganization (the “corporate reorganization”) took place whereby Jagged Peak, initially formed as a subsidiary of JPE LLC, formed JPE Merger Sub LLC as a subsidiary. JPE LLC merged into JPE Merger Sub LLC, with JPE LLC as the surviving entity. As a result, JPE LLC became a wholly owned subsidiary of Jagged Peak. Prior to the corporate reorganization, Quantum owned 98.6% of the membership interests of JPE LLC. Immediately following the corporate reorganization and IPO, Quantum owned 68.7% of the outstanding common stock of Jagged Peak. As all power and authority to control the core functions of Jagged Peak and JPE LLC were, and continue to be, controlled by Quantum, the corporate reorganization was treated as a reorganization of entities under common control and the results of JPE LLC have been consolidated and combined for all periods. On January 27, 2017, the Company initiated its IPO of common stock to the public, and its common stock began trading on the New York Stock Exchange. During the IPO, the Company and selling stockholders sold 31,599,334 shares at $15.00 per share, raising $474.0 million of gross proceeds. Of the 31,599,334 shares issued to the public, 28,333,334 shares were sold by the Company, and 3,266,000 shares were sold by the selling stockholders. The gross proceeds of the IPO to the Company, based on the public offering price of $15.00 per share, were approximately $425.0 million , which resulted in net proceeds to the Company of $397.0 million after deducting expenses and underwriting discounts and commissions of approximately $28.0 million . The Company did not receive any proceeds from the sale of the shares by the selling stockholders. A portion of the proceeds from the IPO were used to repay the entire outstanding balance on JPE LLC’s credit facility of $142.0 million , as of the date the IPO proceeds were received. The remainder of the net proceeds from the IPO were used to fund a portion of the Company’s 2017 capital expenditures program, and for other general corporate purposes. Basis of Presentation The accompanying unaudited consolidated and combined financial statements include the accounts of Jagged Peak and JPE LLC, and have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information, and should be read in conjunction with the financial statements, summary of significant accounting policies and footnotes included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016 , as amended (the “ 2016 Form 10-K”). Accordingly, certain disclosures required by GAAP and normally included in Annual Reports on Form 10-K have been condensed or omitted from this report; however, except as disclosed herein, there has been no material change in the information disclosed in the notes to consolidated financial statements included in the Company’s 2016 Form 10-K. All significant intercompany and intra-company balances and transactions have been eliminated. It is the opinion of management that all adjustments, consisting of normal recurring adjustments considered necessary for a fair presentation of interim financial information, have been included. The Company has no items of other comprehensive income or loss; therefore, its net income or loss is identical to its comprehensive income or loss. Operating results for the periods presented are not necessarily indicative of expected results for the full year because of the impact of fluctuations in prices received for oil, natural gas and NGLs, expected production increases due to development activities, natural production declines, the uncertainty of exploration and development drilling results, the fair value of derivative instruments and other factors. The unaudited consolidated and combined financial statements for periods prior to January 27, 2017 reflect the historical results of JPE LLC, other than the equity-based compensation expense and deferred tax expense, as further described in Notes 6 and 8 , respectively. Certain reclassifications have been made to prior period amounts to conform to the current presentation.

Significant Accounting Policies

Significant Accounting Policies and Related Matters	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
Significant Accounting Policies and Related Matters	Significant Accounting Policies and Related Matters Significant Accounting Policies The significant accounting policies followed by the Company are set forth in Note 2 to the Company’s consolidated financial statements in its 2016 Form 10-K, and are supplemented by the notes to the consolidated and combined financial statements in this Quarterly Report on Form 10-Q. Any new accounting policies or updates to existing accounting policies as a result of new accounting pronouncements have been included in these notes to the consolidated and combined financial statements. Use of Estimates In the course of preparing the consolidated and combined financial statements, management makes various assumptions, judgments and estimates to determine the reported amounts of assets, liabilities, revenue and expenses, and in the disclosures of commitments and contingencies. Changes in these assumptions, judgments and estimates will occur as a result of the passage of time and the occurrence of future events. Although management believes these estimates are reasonable, actual results could differ from these estimates. Estimates made in preparing these consolidated and combined financial statements include, among other things, (1) estimates relating to certain oil and natural gas revenue and costs, (2) estimates of oil and natural gas reserve quantities, which impact depreciation, depletion and amortization and impairment calculations, (3) estimates of timing and costs used in calculating asset retirement obligations and impairment, (4) estimates used in developing fair value assumptions and estimates, and (5) estimates and assumptions used in the disclosure of commitments and contingencies. Changes in the assumptions could have a significant impact on results in future periods. Accounts Receivable At September 30, 2017 and December 31, 2016 , accounts receivable was comprised of the following: (in thousands) September 30, 2017 December 31, 2016 Oil and gas sales $ 22,946 $ 8,861 Joint interest 10,769 580 Other 1,373 886 Total accounts receivable $ 35,088 $ 10,327 At September 30, 2017 and December 31, 2016 , the Company did no t have any reserves for doubtful accounts and did not incur any bad debt expense in any period presented. Oil and Natural Gas Properties A summary of the Company’s oil and natural gas properties, net is as follows: (in thousands) September 30, 2017 December 31, 2016 Proved oil and natural gas properties $ 818,990 $ 375,129 Unproved oil and natural gas properties 187,757 155,992 Total oil and natural gas properties 1,006,747 531,121 Less: Accumulated depletion (123,448 ) (57,529 ) Total oil and natural gas properties, net $ 883,299 $ 473,592 Capitalized leasehold costs attributable to proved properties are depleted using the units-of-production method based on proved reserves on a field basis. For the three months ended September 30, 2017 and 2016 , the Company recorded depletion for oil and natural gas properties of $30.4 million and $10.8 million , respectively. For the nine months ended September 30, 2017 and 2016 , the Company recorded depletion for oil and natural gas properties of $65.9 million and $28.8 million , respectively. Accrued Liabilities The components of accrued liabilities are shown below: (in thousands) September 30, 2017 December 31, 2016 Accrued capital expenditures $ 86,433 $ 28,490 Accrued accounts payable 3,349 3,312 Royalties payable 4,313 2,653 Other current liabilities 12,393 4,770 Total accrued liabilities $ 106,488 $ 39,225 Equity-based Compensation The Company recognizes compensation cost related to equity-based awards granted to employees, members of the Company’s board of directors and non-employee contractors in the financial statements based on their estimated grant-date fair value. The Company may grant various types of equity-based awards including stock options, stock appreciation rights, restricted stock, restricted stock units (including awards with service-based vesting and market condition-based vesting provisions), stock awards, dividend equivalents and other types of awards . Service-based restricted stock and units are valued using the market price of Jagged Peak’s common stock on the grant date. The fair value of the market condition-based restricted stock units are based on the grant-date fair value of the award utilizing a statistical analysis. Compensation cost is recognized ratably over the applicable vesting period, and is recognized in general and administrative expense in the consolidated and combined statements of operations. The Company has elected to account for forfeitures in compensation expense as they occur. Equity-based compensation arrangements to nonemployees are recognized as expense over the related service period and are subject to remeasurement at the end of each reporting period until they vest. Income Taxes The Company is a subchapter C corporation and is subject to U.S. federal and state income taxes. Income taxes are accounted for under the asset and liability method. The Company recognizes deferred tax assets and liabilities for the future tax consequences attributable to differences between the financial statement carrying amounts and income tax basis of assets and liabilities and the expected benefits of utilizing net operating losses and tax credit carryforwards, using enacted tax rates in effect for the taxing jurisdiction in which the Company operates for the year in which those temporary differences are expected to be recovered or settled. The Company classifies all deferred tax assets and liabilities as noncurrent. The Company recognizes the financial statement effects of a tax position when it is more likely than not, based on technical merits, that the position will be sustained upon examination. Net deferred tax assets are then reduced by a valuation allowance if the Company believes it is more likely than not such net deferred tax assets will not be realized. Recent Accounting Pronouncements In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , which outlines a new, single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance, including industry-specific guidance. This new revenue recognition model provides a five-step analysis in determining when and how revenue is recognized. The new guidance will require a company to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration a company expects to receive in exchange for those goods or services. In May 2016, the FASB issued ASU 2016-11, which rescinds the U.S. Securities and Exchange Commission (“SEC”) accounting guidance regarding the use of the entitlements method for recognition of natural gas revenues. The standards can be adopted using either a full retrospective method or a modified retrospective method, as outlined in ASU 2014-09. The Company will adopt this standard on January 1, 2018, and will apply the modified retrospective method. The Company is in process of completing its evaluation of the impact of this standard on its financial statements and disclosures, internal controls and accounting policies. Based on the results to date, the Company has reached tentative conclusions and does not believe its existing revenue recognition processes and controls will change materially. The Company expects that certain additional disclosures will be required upon adoption of this standard. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) , which requires all leases with a term greater than one year to be recognized on the balance sheet as lease assets and lease liabilities. This ASU retains a distinction between finance and operating leases concerning the recognition and presentation of the expense and payments related to leases in the statements of operations and cash flows. The new standard is effective for the Company on January 1, 2019. Although early adoption is permitted, the Company does not plan to early adopt the standard. The ASU requires the use of the modified retrospective approach, whereby lessees will be required to recognize and measure leases at the beginning of the earliest period presented. The Company is still in the process of evaluating the impact of this new standard; however, the Company believes the initial impact of adopting the standard will result in increases to its assets and liabilities on its consolidated balance sheets, and changes to the timing and presentation of certain operating expenses on its consolidated statements of operations. In May 2017, the FASB issued ASU 2017-09, Compensation-Stock Compensation (Topic 718) Scope of Modification Accounting . The ASU clarifies which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting in Topic 718. The standard is effective for the Company on January 1, 2018, with early adoption permitted. The impact of this new standard will depend on the extent and nature of future changes to the terms of Company's equity-based payment awards.

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Derivative Instruments The Company hedges a portion of its crude oil sales through derivative instruments to mitigate volatility in commodity prices. The use of these instruments exposes the Company to market basis differential risk if the WTI price does not move in parity with the Company’s underlying sales of crude oil produced in the Southern Delaware Basin. The Company also hedges a portion of its market basis differential risk through basis swap contracts. The Company’s derivative instruments are carried at fair value on the consolidated and combined balance sheets. The Company estimates the fair value using risk adjusted discounted cash flow calculations. Cash flows are based on published future commodity price curves for the underlying commodity as of the date of the estimate. Due to the volatility of commodity prices, the estimated fair values of the Company’s derivative instruments are subject to fluctuation from period to period, which could result in significant differences between the current estimated fair value and the ultimate settlement price. For more information, refer to Note 4 , Fair Value Measurements . As of September 30, 2017 , the Company hedged commodity prices associated with a portion of its expected future oil volumes by entering into swap and basis swap derivative financial instruments. With swaps, the Company typically receives an agreed upon fixed price for a specified notional quantity of oil or natural gas, and the Company pays the hedge counterparty a floating price for that same quantity based upon published index prices. Basis swap contracts establish the differential between Cushing WTI prices and Midland WTI prices. The Company’s commodity derivatives may expose it to the risk of financial loss in certain circumstances. The Company’s derivative arrangements provide protection on the hedged volumes if market prices decline below the prices at which these derivatives are set. If market prices rise above the prices at which the Company has hedged, the Company will receive less revenue on the hedged volumes than it would receive in the absence of hedges. The following table summarizes the Company’s derivative contracts as of September 30, 2017 : Contract Period Volumes Wtd Avg Price Oil Swaps (1) : Fourth quarter 2017 1,392,700 $ 51.34 Year ending December 31, 2018 5,263,350 $ 52.18 Year ending December 31, 2019 2,372,500 $ 51.89 Oil Basis Swaps (2) : Fourth quarter 2017 460,000 $ (1.00 ) Year ending December 31, 2018 5,110,000 $ (1.08 ) Year ending December 31, 2019 2,920,000 $ (1.10 ) (1) The index prices for the oil swaps are based on the NYMEX–WTI monthly average futures price. (2) The oil basis swap differential price is between Midland–WTI and Cushing–WTI. The Company has elected to not apply hedge accounting, and as a result, its earnings are affected by the use of the mark-to-market method of accounting for derivative financial instruments. The changes in fair value of these instruments are recognized through earnings as other income or expense rather than deferred until the anticipated transaction affects earnings. The use of mark-to-market accounting for financial instruments can cause noncash earnings volatility due to changes in the underlying commodity price indices. The ultimate gain or loss upon settlement of these transactions is recognized in earnings as other income or expense. Cash settlements of the Company’s derivative contracts are included in cash flows from operating activities in the Company’s statements of cash flows. The Company recognized the following gains (losses) in earnings for the periods indicated: Three Months Ended September 30, Nine Months Ended September 30, (in thousands) 2017 2016 2017 2016 Gain (loss) on derivatives instruments, net $ (27,693 ) $ 1,728 $ 15,922 $ (8,208 ) Cash settlements of derivatives (received) paid, net $ (3,195 ) $ 337 $ (3,691 ) $ 1,159 The Company’s derivative contracts are carried at their fair value on the Company’s consolidated and combined balance sheets using Level 2 inputs, and are subject to industry standard master netting arrangements, which allow the Company to offset recognized asset and liability fair value amounts on contracts with the same counterparty. The Company’s policy is to not offset these positions in its consolidated and combined balance sheets. The following tables present the amounts and classifications of the Company’s commodity contract derivative assets and liabilities as of September 30, 2017 and December 31, 2016 (in thousands): As of September 30, 2017: Balance Sheet Location Gross amounts presented on the balance sheet Netting adjustments not offset on the balance sheet Net amounts Assets Commodity contracts Current assets - derivative instruments $ 5,515 $ (5,361 ) $ 154 Commodity contracts Noncurrent assets - derivative instruments 5,170 (1,602 ) 3,568 Total assets $ 10,685 $ (6,963 ) $ 3,722 Liabilities Commodity contracts Current liabilities - derivative instruments $ 8,820 $ (5,361 ) $ 3,459 Commodity contracts Noncurrent liabilities - derivative instruments 2,490 (1,602 ) 888 Total liabilities $ 11,310 $ (6,963 ) $ 4,347 As of December 31, 2016: Balance Sheet Location Gross amounts presented on the balance sheet Netting adjustments not offset on the balance sheet Net amounts Liabilities Commodity contracts Current liabilities - derivative instruments $ 9,567 — $ 9,567 Commodity contracts Noncurrent liabilities - derivative instruments 3,287 — 3,287 Total liabilities $ 12,854 $ — $ 12,854 Derivative Counterparty Risk Where the Company is exposed to credit risk in its financial instrument transactions, management analyzes the counterparty’s financial condition prior to entering into an agreement, and monitors the appropriateness of these counterparties on an ongoing basis. Generally, the Company does not require collateral and does not anticipate nonperformance by its counterparties. At September 30, 2017 , the Company had commodity derivative contracts with three counterparties, all of which were lenders or affiliates of lenders under the Company’s Amended and Restated Credit Facility and all of which had investment grade credit ratings. These counterparties accounted for all the Company’s counterparty credit exposure related to commodity derivative assets.

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2017
Fair Value Disclosures [Abstract]
Fair Value Measurements	Fair Value Measurements Fair value is 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). Financial assets and liabilities are measured at fair value on a recurring basis. Nonfinancial assets and liabilities, such as the initial measurement of asset retirement obligations and proved oil and natural gas properties upon acquisition or impairment, are recognized at fair value on a nonrecurring basis. The Company categorizes the inputs to the fair value of its financial assets and liabilities using a three-tier fair value hierarchy, established by the FASB, that prioritizes the significant inputs used in measuring fair value: 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 1 primarily consists of financial instruments such as exchange-traded derivatives, listed securities and U.S. government treasury securities. Level 2—Pricing inputs are other than quoted prices in active markets included in Level 1, which are either directly or indirectly observable as of the reporting date. Level 2 includes those financial instruments that are valued using models or other valuation methodologies. These models are primarily industry standard models that consider various assumptions, including quoted 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 term of the instrument, can be derived from observable data or are supported by observable levels at which transactions are executed in the marketplace. Instruments in the category include nonexchange-traded derivatives such as over-the-counter forwards, swaps and options. Level 3—Pricing inputs include significant inputs that are generally less observable from objective sources. These inputs may be used with internally developed methodologies that result in management’s best estimate of fair value, and the company does not have sufficient corroborating market evidence to support classifying these assets and liabilities as Level 2. Financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. Assets and liabilities measured on a recurring basis Certain assets and liabilities are reported at fair value on a recurring basis, including the Company’s derivative instruments. To determine the fair value at the end of each reporting period, the Company computes discounted cash flows for the duration of each commodity derivative instrument using the terms of the related contract. Inputs consist of published forward commodity price curves as of the date of the estimate. The Company compares these prices to the price parameters contained in its hedge contracts to determine estimated future cash inflows or outflows, which are then discounted. The fair values of the Company’s commodity derivative assets and liabilities include a measure of credit risk. These valuations are Level 2 inputs. The following table is a listing of the Company’s assets and liabilities that were measured at fair value on a recurring basis as of September 30, 2017 and December 31, 2016 : Level 2 (in thousands) September 30, 2017 December 31, 2016 Assets from commodity derivative contracts $ 10,685 $ — Liabilities due to commodity derivative contracts $ 11,310 $ 12,854 Assets and liabilities measured on a nonrecurring basis The Company applies the provisions of the fair value measurement standard on a nonrecurring basis to its nonfinancial assets and liabilities, such as the acquisition or impairment of proved and unproved oil and gas properties and the inception value of asset retirement obligations. These assets and liabilities are subject to fair value adjustments only in certain circumstances and are not subject to recurring revaluations. The Company reviews its proved oil and natural gas properties for impairment whenever facts and circumstances indicate their carrying value may not be recoverable. In such circumstances, the income approach is used to determine the fair value of proved oil and natural gas reserves. Under this approach, the Company estimates the expected future cash flows of oil and natural gas properties and compares these undiscounted cash flows to the carrying amount of the oil and natural gas properties to determine if the carrying amount is recoverable. If the carrying amount exceeds the estimated undiscounted future cash flows, the Company will write down the carrying amount of the oil and natural gas properties to estimated fair value. The factors used to determine fair value may include, but are not limited to, estimates of reserves, future commodity prices, future production estimates, estimated future capital expenditures and a commensurate discount rate. These assumptions and estimates represent Level 3 inputs. No impairments were recorded on proved properties during the three and nine months ended September 30, 2017 and 2016 . Unproved oil and natural 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. To measure the fair value of the unproved properties, the Company uses a market approach, and takes into account future development plans, remaining lease term, drilling results, and reservoir performance. The Company recorded impairment expense on unproved oil and gas properties of $0.3 million and $7,000 for the three months ended September 30, 2017 and 2016 , respectively, and $0.4 million and $0.3 million for the nine months ended September 30, 2017 and 2016 , respectively. These impairments resulted from the expirations of certain undeveloped leases. The inception value and revision value, if any, of the Company’s asset retirement obligations are also measured at fair value on a nonrecurring basis. The inputs used to determine such fair value are based primarily on the present value of estimated future cash inflows and outflows. Given the unobservable nature of these inputs, they represent Level 3 inputs. The fair value measurements of assets acquired and liabilities assumed are measured on a nonrecurring basis on the acquisition date using an income valuation approach based on inputs that are non-observable in the market and therefore represent Level 3 inputs. Significant inputs to the valuation of acquired oil and gas properties include estimates of future commodity prices, projections of estimated quantities of oil and natural gas reserves, expectations for timing and amount of future development and operating costs, projections of future rates of production, expected recovery rates and risk-adjusted discount rates. These inputs require significant judgments and estimates by the Company’s management at the time of the valuation. Fair Value of Other Financial Instruments The Company has other financial instruments consisting primarily of cash and cash equivalents, accounts receivable, other current assets, accounts payable and accrued liabilities that approximate fair value due to the nature of the instrument and the short-term maturities of these instruments.

Debt Obligations

Debt Obligations	9 Months Ended
	Sep. 30, 2017
Debt Disclosure [Abstract]
Debt Obligations	Debt Obligations In June 2015, JPE LLC entered into a five -year senior secured revolving credit facility (“JPE LLC’s Credit Facility”), with a maximum facility amount of $500.0 million . At December 31, 2016 , JPE LLC’s Credit Facility, as amended, had a borrowing base of $160.0 million , with $132.0 million outstanding under the credit facility, and $28.0 million in unused borrowing capacity. The weighted-average interest rate as of December 31, 2016 was 3.99% . Following the IPO, the outstanding balance under JPE LLC’s credit facility was paid in full. In January 2017, JPE LLC’s Credit Facility borrowing base was increased to $180.0 million , and the number of lenders was increased from five banks to nine banks. In February 2017, the Company, as parent guarantor, and JPE LLC, as borrower, entered into an amended and restated credit facility with Wells Fargo Bank, N.A., as administrative agent and the lenders thereto (the “Amended and Restated Credit Facility”). The borrowing base and number of banks remained at $180.0 million and nine , respectively, while the maximum facility amount increased to $1.0 billion . Further, the Amended and Restated Credit Facility no longer contains the minimum hedging requirements that existed in JPE LLC’s credit facility. At September 30, 2017 , borrowings under the Amended and Restated Credit Facility bore interest at a rate elected by the Company that is equal to an alternative base rate (which is equal to the greatest of the prime rate, the federal funds effective rate plus 0.50% , and the thirty-day adjusted LIBOR plus 1.0% ) or LIBOR, in each case, plus the applicable margin. At September 30, 2017 , the applicable margin ranged from 1.25% to 2.25% in the case of the alternative base rate and from 2.25% to 3.25% in the case of LIBOR, in each case depending on the amount of the loan outstanding in relation to the borrowing base. At September 30, 2017 , the Company paid a commitment fee of 0.50% per year on the unused portion of the borrowing base. The Amended and Restated Credit Facility matures on February 1, 2022, and is subject to semiannual borrowing base redeterminations on or around April 1 and October 1 of each year. The borrowing base increased from $180.0 million to $250.0 million after the April 2017 redetermination. The Amended and Restated Credit Facility is secured by oil and natural gas properties representing at least 90% of the value of the Company’s proved reserves. The Amended and Restated Credit Facility contains certain covenants, including among others, restrictions on indebtedness, restrictions on liens, restrictions on investments, restrictions on mergers, restrictions on sales of assets, restrictions on dividends and payments to the Company’s capital interest holders and restrictions on the Company’s hedging activity. The Amended and Restated Credit Facility contains financial covenants, which are measured on a quarterly basis. The covenants, as defined in the amended and restated credit agreement, include requirements to comply with the following financial ratios: • a current ratio, which is the ratio of consolidated current assets (including unused commitments under the credit facility and excluding noncash assets related to asset retirement obligations and derivatives) to consolidated current liabilities (excluding the current portion of long-term debt under the credit agreement and noncash liabilities related to asset retirement obligations and derivatives), as of the last day of each fiscal quarter, of not less than 1.0 to 1.0 ; and • a leverage ratio, which is the ratio of consolidated Debt (as defined in the credit agreement) as of the last day of each fiscal quarter, subject to certain exclusions (as described in the credit agreement) to EBITDAX (as defined in the credit agreement) for the last 12 months ending on the last day of that fiscal quarter, of not greater than 4.0 to 1.0 . As of September 30, 2017 , the Company was in compliance with its financial covenants. As of September 30, 2017 , there was $35.0 million outstanding balance under the Amended and Restated Credit Facility. The weighted-average interest rate as of September 30, 2017 was 3.49% . In October 2017, the Company and JPE LLC entered into an amendment to the Amended and Restated Credit Facility (“Amendment No. 1”). Under Amendment No. 1, the borrowing base increased to $425.0 million and the pricing grid was lowered, while the number of banks providing commitments remained at nine . Following Amendment No. 1, the Amended and Restated Credit Facility remains subject to semiannual borrowing base redeterminations on or around April 1 and October 1 of each year, with the next scheduled redetermination on or around April 1, 2018. Borrowings under the Amended and Restated Credit Facility following Amendment No. 1 bear interest at a rate elected by the Company that is equal to an alternative base rate (which is equal to the greatest of the prime rate, the federal funds effective rate plus 0.50% , and the thirty-day adjusted LIBOR plus 1.0% ) or LIBOR, in each case, plus the applicable margin. The applicable margin ranges from 1.00% to 2.00% in the case of the alternative base rate, and from 2.00% to 3.00% in the case of LIBOR, in each case depending on the amount of the loan outstanding in relation to the borrowing base. The Company pays a commitment fee of 0.375% to 0.50% per year on the unused portion of the borrowing base, depending on the relative amount of the loan outstanding in relation to the borrowing base.

Equity-based Compensation

Equity-based Compensation	9 Months Ended
	Sep. 30, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Equity-based Compensation	Equity-based Compensation In connection with the IPO, the Company adopted the Jagged Peak Energy Inc. 2017 Long Term Incentive Plan (the “Plan”), which allows the Company to grant up to 21,200,000 equity-based compensation shares to employees, consultants and directors of the Company and its affiliates who perform services for the Company. The Plan provides for grants of stock options, stock appreciation rights, restricted stock, restricted stock units, stock awards, dividend equivalents, performance awards and other types of awards. The terms and conditions of the awards granted are established by the Company’s Board of Directors. Equity-based compensation expense, which is recorded in general and administrative expense in the accompanying consolidated and combined statements of operations, was as follows for the periods indicated: Three Months Ended September 30, Nine Months Ended September 30, (in thousands) 2017 2016 2017 2016 Incentive unit awards $ 10,692 $ — $ 429,585 $ — Restricted stock unit awards 521 — 898 — Performance stock unit awards 527 — 866 — Restricted stock unit awards issued to nonemployee directors 163 — 293 — Total equity-based compensation expense $ 11,903 $ — $ 431,642 $ — Incentive Unit Awards In connection with its formation in April 2013, JPE LLC established an incentive pool plan, whereby JPE LLC granted MIUs to employees and selected other participants. The MIUs were considered “profits interests” that participated in certain events whereupon distributions would be made to MIU holders (only after certain return thresholds were achieved by the capital interests) following a qualifying initial public offering, sale, merger, or other qualifying transaction involving the units or assets of JPE LLC (“Vesting Event”). The MIUs were accounted for under FASB ASC Topic 710, Compensation–General , which requires compensation expense for the MIUs to be recognized when all performance, market and service conditions are probable of being satisfied, which is generally upon a Vesting Event. As of and through December 31, 2016, the vesting of the MIUs was not deemed probable, therefore no expense was recognized through December 31, 2016. The corporate reorganization provided a mechanism by which all capital interests and MIUs in JPE LLC were converted into a single class of units, which were then converted into the Company’s common stock. A portion of these shares vested and a portion were transferred to JPE Management Holdings LLC (“Management Holdco”) and became subject to the terms and conditions of the amended and restated JPE Management Holdings LLC limited liability company agreement (the “Management Holdco LLC Agreement”). As a result of the IPO, the satisfaction of all conditions relating to MIUs in JPE LLC held by the current and former officers and employees who owned equity interests in JPE LLC, was deemed probable. As a result, based on the Company’s IPO price of $15.00 per share, compensation expense of $379.0 million was recognized for the vested shares of common stock at the IPO date, all of which was noncash except for $14.7 million related to a management incentive advance payment made in April 2016. The shares of common stock transferred to Management Holdco are accounted for under ASC 718, Compensation–Stock Compensation , and generally vest over three years. During the three and nine months ended September 30, 2017 , the Company recognized $10.7 million and $50.6 million , respectively, of equity-based compensation expense related to the shares held by Management Holdco. Included in the $50.6 million for the nine months ended September 30, 2017 , is $22.2 million of equity-based compensation related to awards held by Management Holdco which were modified in conjunction with a March 2017 separation agreement of a former executive officer. The remaining compensation expense of these awards will be recognized ratably according to the terms of the Management Holdco LLC Agreement. A summary of incentive unit award activity for the nine months ended September 30, 2017 is as follows: Weighted Average Grant-date Incentive Units Fair Value Unvested at Corporate Reorganization 9,570,280 $ 15.00 Granted 235,346 $ 12.41 Vested (2,049,881 ) $ 14.97 Forfeited — $ — Unvested at September 30, 2017 7,755,745 $ 14.93 Compensation costs remaining at September 30, 2017 (in millions) $ 90.5 Weighted average remaining period at September 30, 2017 (in years) 2.3 The total fair value of incentive units that vested during the nine months ended September 30, 2017 was $25.2 million . At September 30, 2017 , there were 431,321 of unallocated shares of Company common stock held at Management Holdco which, when granted, will be valued using the closing stock price on the date of grant, and the Company will recognize expense over the requisite service period. Restricted Stock Unit Awards Restricted stock unit awards (“RSUs”) vest subject to the satisfaction of service requirements. Expense related to each RSU award is recognized on a straight-line basis over the requisite service period of the entire award. Forfeitures are accounted for as they occur through reversal of expense on awards that were forfeited during the period. The grant date fair values of these awards are determined based on the closing price of the Company’s common stock on the date of the grant. A summary of RSU award activity for the nine months ended September 30, 2017 is as follows: Weighted Average Grant-date RSUs Fair Value Unvested at December 31, 2016 — $ — Granted 576,264 $ 12.42 Vested — $ — Forfeited (5,921 ) $ 12.61 Unvested at September 30, 2017 570,343 $ 12.42 Compensation costs remaining at September 30, 2017 (in millions) $ 5.9 Weighted average remaining period at September 30, 2017 (in years) 2.4 Of the 576,264 RSUs granted during the nine months ended September 30, 2017 , nonemployee directors received 55,744 at a weighted average grant-date fair value of $12.46 . The remaining compensation costs at September 30, 2017 for these nonemployee director RSUs was $0.4 million , with a weighted average remaining period of 0.6 years. Performance Stock Unit Awards During the nine months ended September 30, 2017 , the Company granted performance stock unit awards (“PSUs”) to certain of its executive officers, which vest based on continuous employment and satisfaction of a performance metric based on the total shareholder return (“TSR”) of the Company’s common stock relative to the TSR of a peer group of companies over an approximate three -year performance period ending December 31, 2019. The number of shares which may ultimately be earned ranges from zero to 200% of the PSUs granted. Expense related to these PSUs is recognized on a straight-line basis over approximately three years. All compensation cost related to the market-based awards will be recognized if the requisite service period is fulfilled, even if the market condition is not achieved. A summary of PSU award activity for the nine months ended September 30, 2017 is as follows: Weighted Average Grant-date PSUs Fair Value Unvested at December 31, 2016 — $ — Granted 398,566 $ 16.32 Vested — $ — Forfeited — $ — Unvested at September 30, 2017 398,566 $ 16.32 Compensation costs remaining at September 30, 2017 (in millions) $ 5.6 Weighted average remaining period at September 30, 2017 (in years) 2.3 The grant-date fair value of the PSUs was determined using a Monte Carlo simulation, which uses a probabilistic approach for estimating the fair value of the awards. The expected volatility was derived from a weighted combination of implied volatility and historical volatility. The risk-free interest rate was determined using the yield available for zero-coupon U.S. government issues with remaining terms corresponding to the service periods of the PSUs. The following table presents information regarding the weighted average fair value for PSUs granted during the nine months ended September 30, 2017 and the assumptions used to determine the fair values: Nine Months Ended September 30, 2017 Dividend yield — % Volatility 55.7 % Risk-free interest rate 1.34 % Weighted average fair value of awards granted $ 16.32

Earnings Per Share

Earnings Per Share	9 Months Ended
	Sep. 30, 2017
Earnings Per Share [Abstract]
Earnings Per Share	Earnings Per Share Basic earnings per share (“EPS”) is computed by dividing net earnings by the weighted average number of shares of common stock outstanding for the period. Diluted earnings per share is similarly computed, except that the denominator includes the effect, using the treasury stock method, of unvested RSUs and PSUs, if including such potential shares of common stock units is dilutive. The PSUs included in the calculation of diluted weighted average shares outstanding based on the number of shares of common stock that would be issuable if the end of the reporting period was the end of the performance period required for the vesting of such PSU awards. During periods in which the Company incurs a net loss, diluted weighted average shares outstanding are equal to basic weighted average shares outstanding because the effect of all awards is anti-dilutive. For the nine months ended September 30, 2017 , the Company’s EPS calculation includes only the net loss for the period subsequent to the corporate reorganization and IPO, and omits income or loss prior to these events. In addition, the basic weighted average shares outstanding calculation is based on the actual days in which the shares were outstanding for the period from January 27, 2017, to September 30, 2017 . A reconciliation of the components of basic and diluted earnings per common share is presented in the table below: Three Months Ended From January 27, 2017, to (in thousands, except per share amounts) September 30, 2017 September 30, 2017 Net income (loss) attributable to Jagged Peak Energy Inc. stockholders $ (15,219 ) $ (89,221 ) Basic weighted average shares outstanding 212,931 212,933 Effect of dilutive securities: Restricted stock units — — Performance stock units — — Diluted weighted average shares outstanding 212,931 212,933 Net income (loss) per common share: Basic $ (0.07 ) $ (0.42 ) Diluted $ (0.07 ) $ (0.42 ) The following table presents amounts that have been excluded from the computation of diluted earnings per common share as their inclusion would be anti-dilutive: Three Months Ended From January 27, 2017, to (in thousands) September 30, 2017 September 30, 2017 Weighted average number of outstanding equity awards excluded from diluted earnings per share calculation: (1) Restricted stock units 527 348 Performance stock units 671 421 (1) When the Company incurs a net loss, all outstanding equity awards are excluded from the calculation of diluted loss per common share because the inclusion of these awards would be anti-dilutive.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2017
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes JPE LLC was organized as a limited liability company and treated as a pass-through entity for federal income tax purposes. As such, taxable income and any related tax credits were passed through to its members and included in their tax returns. Accordingly, provision for federal and state corporate income taxes has been made only for the operations of the Company from January 27, 2017 through September 30, 2017 in the accompanying consolidated and combined financial statements. Deferred income taxes are provided to reflect the future tax consequences or benefits of differences between the tax basis of assets and liabilities and their reported amounts in the financial statements using enacted tax rates. Upon the change in tax status as a result of the corporate reorganization, the Company established a $79.1 million provision for deferred income taxes, which was recognized as tax expense from continuing operations in the first quarter of 2017. The components of the Company’s provision for income taxes are as follows: Three Months Ended Nine Months Ended (in thousands) September 30, 2017 September 30, 2017 Current income tax expense: Federal $ — $ — State — — — — Deferred income tax expense: Federal (2,543 ) 98,904 State (55 ) 2,135 (2,598 ) 101,039 Provision for income taxes $ (2,598 ) $ 101,039 Included in the deferred federal income tax provision above for the nine months ended September 30, 2017 , is the $79.1 million related to the Company’s change in tax status. A reconciliation of the income tax expense calculated at the federal statutory rate of 35% to the total income tax expense is as follows: Three Months Ended Nine Months Ended (in thousands) September 30, 2017 September 30, 2017 Income (loss) before income taxes $ (17,817 ) $ (363,658 ) Less: net loss prior to corporate reorganization — (375,476 ) Income (loss) before income taxes subsequent to corporate reorganization $ (17,817 ) $ 11,818 Income taxes at the federal statutory rate $ (6,236 ) $ 4,136 Income tax expense relating to change in tax status — 78,019 State income taxes, net of federal benefit (35 ) 1,388 Nondeductible equity-based compensation 3,671 17,479 Other permanent differences 2 17 Income tax expense (benefit) $ (2,598 ) $ 101,039 Effective tax rate 14.6 % (27.8 )% Prior to the Company’s change in tax status in January 2017, income taxes did not significantly impact the results of operations. The components of the Company’s deferred income tax assets and liabilities as of September 30, 2017 are as follows: (in thousands) September 30, 2017 Deferred income tax assets: Net operating loss carryforwards $ 1,526 Commodity derivatives 221 Equity-based compensation 502 Other 1,302 3,551 Deferred income tax liabilities: Oil and natural gas properties 104,590 104,590 Net deferred income tax assets (liabilities) $ (101,039 ) The Company had U.S. net operating losses of approximately $4.3 million , which expire in 2036. Deferred tax assets are reduced by a valuation allowance if the Company believes it is more likely than not such deferred tax assets will not be realized. At September 30, 2017 , the Company did not have a valuation allowance. The Company recognizes interest and penalties related to uncertain tax positions in income tax expense. At September 30, 2017 , the Company had no unrecognized tax benefits that would impact the effective tax rate and has made no provisions for interest or penalties related to uncertain tax positions. The Company files income tax returns in the U.S. federal jurisdiction, Texas and Colorado. There are currently no federal or state income tax examinations underway. The Company’s U.S. federal income tax returns remain open to examination by the taxing authorities for tax years 2014 through 2017 , and its Texas and Colorado tax returns remain open to examination for the years 2013 through 2016 and 2013 through 2017 , respectively.

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Asset Retirement Obligations The following table summarizes the changes in the carrying amount of the asset retirement obligations for the nine months ended September 30, 2017 : (in thousands) Asset retirement obligations at January 1, 2017 $ 448 Liabilities incurred and assumed 492 Liability settlements and disposals (10 ) Revisions of estimated liabilities (5 ) Accretion 49 Asset retirement obligations at September 30, 2017 974 Less current portion of asset retirement obligations (284 ) Long-term asset retirement obligations $ 690 The current portion of the asset retirement obligation liability is included in accrued liabilities on the consolidated and combined balance sheets.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2017
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Commitments and Contingencies Commitments There were no material changes in commitments during the first nine months of 2017, except as discussed below. Please refer to Note 9, Commitments and Contingencies , in the 2016 Form 10-K for additional discussion. At September 30, 2017 , the Company had seven drilling rigs under contract. If the Company were to terminate these contracts at September 30, 2017 , it would be required to pay early termination penalties of $11.1 million . In the first nine months of 2016 , the Company terminated one drilling rig and incurred early termination charges of approximately $0.2 million . These charges are reflected as other operating costs in the consolidated and combined statements of operations. At September 30, 2017 , the Company had three frac fleets under contract through December 31, 2018. The remaining commitment at September 30, 2017 for these contracts is $13.8 million in 2017, and $73.2 million in 2018. The majority of the contracts allow for reassignment of the frac fleets if the Company were to terminate their services prior to the end of the contract, at which point the Company would not be required to pay termination fees. However, if the fleets were not able to be reassigned, the Company would be required to pay termination fees of $66.2 million as of September 30, 2017 . During the second quarter of 2017, the Company entered into a lease agreement of its new corporate offices, which is expected to take effect in December 2017 and expire in May 2028. Including this new lease agreement, the Company has commitments for office space and equipment under operating lease arrangements totaling $16.7 million . Contingencies Legal Matters In the ordinary course of business, the Company may at times be subject to claims and legal actions. Management believes it is remote that the impact of such matters will have a material adverse effect on the Company’s financial position, results of operations or cash flows. Environmental Matters The Company accounts for environmental contingencies in accordance with the accounting guidance related to accounting for contingencies. Environmental expenditures that relate to current operations are expensed or capitalized as appropriate. Expenditures that relate to an existing condition caused by past operations, which do not contribute to current or future revenue generation, are expensed. Liabilities are recorded when environmental assessments and/or clean-ups are probable and the costs can be reasonably estimated. Such liabilities are generally undiscounted unless the timing of cash payments is fixed and readily determinable. At both September 30, 2017 and December 31, 2016 , the Company had no environmental matters requiring specific disclosure or requiring the recognition of a liability.

Related Party Transactions

Related Party Transactions	9 Months Ended
	Sep. 30, 2017
Related Party Transactions [Abstract]
Related Party Transactions	Related Party Transactions Quantum employs certain members of the Company’s board of directors and had significant capital interests in JPE LLC. After giving effect to the IPO, Quantum owns 68.7% of the Company’s common stock. Quantum owns a 41.5% interest in Oryx Midstream Services, LLC (together with Oryx Southern Delaware Holdings, LLC, “Oryx”). The Company has a 12 -year crude oil gathering agreement with Oryx whereby Oryx provides midstream gathering services to the Company. Under that agreement, the Company has the right to designate, and has designated, a third-party shipper to market the Company’s crude oil. In addition, the Company paid fees to Oryx for the purchase and maintenance of connecting equipment. Quantum also owns a 60.9% interest in Phoenix Lease Services, LLC (“Phoenix”), and an indirect interest in Trident Water Services, LLC (“Trident”), a wholly owned subsidiary of Phoenix. The Company regularly leases frac tanks and other oil field equipment from Phoenix, and regularly uses water transfer services provided by Trident. The Company is under no obligation to use either provider, and both provide services only when selected as a vendor through the Company’s normal bidding process. The following table summarizes fees paid to Oryx, Phoenix and Trident for the periods indicated: Three Months Ended September 30, Nine Months Ended September 30, (in thousands) 2017 2016 2017 2016 Oryx via 3rd party shipper (1) $ 2,918 $ 938 $ 6,716 $ 1,037 Oryx (2) $ 97 $ 166 $ 749 $ 1,091 Phoenix $ 56 $ 111 $ 258 $ 260 Trident $ — $ 90 $ 236 $ 413 (1) Transportation fees paid by the Company’s third party shipper to Oryx pursuant to the crude oil gathering agreement. (2) Fees paid to Oryx for the purchase and maintenance of connecting equipment. At September 30, 2017 and December 31, 2016 , the Company had outstanding payables to these related parties of $1.1 million and $0.7 million , respectively.

Significant Accounting Polici19

Significant Accounting Policies and Related Matters (Policies)	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The accompanying unaudited consolidated and combined financial statements include the accounts of Jagged Peak and JPE LLC, and have been prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”) for interim financial information, and should be read in conjunction with the financial statements, summary of significant accounting policies and footnotes included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2016 , as amended (the “ 2016 Form 10-K”). Accordingly, certain disclosures required by GAAP and normally included in Annual Reports on Form 10-K have been condensed or omitted from this report; however, except as disclosed herein, there has been no material change in the information disclosed in the notes to consolidated financial statements included in the Company’s 2016 Form 10-K. All significant intercompany and intra-company balances and transactions have been eliminated. It is the opinion of management that all adjustments, consisting of normal recurring adjustments considered necessary for a fair presentation of interim financial information, have been included. The Company has no items of other comprehensive income or loss; therefore, its net income or loss is identical to its comprehensive income or loss. Operating results for the periods presented are not necessarily indicative of expected results for the full year because of the impact of fluctuations in prices received for oil, natural gas and NGLs, expected production increases due to development activities, natural production declines, the uncertainty of exploration and development drilling results, the fair value of derivative instruments and other factors. The unaudited consolidated and combined financial statements for periods prior to January 27, 2017 reflect the historical results of JPE LLC, other than the equity-based compensation expense and deferred tax expense, as further described in Notes 6 and 8 , respectively.
Reclassifications	Certain reclassifications have been made to prior period amounts to conform to the current presentation.
Use of Estimates	Use of Estimates In the course of preparing the consolidated and combined financial statements, management makes various assumptions, judgments and estimates to determine the reported amounts of assets, liabilities, revenue and expenses, and in the disclosures of commitments and contingencies. Changes in these assumptions, judgments and estimates will occur as a result of the passage of time and the occurrence of future events. Although management believes these estimates are reasonable, actual results could differ from these estimates. Estimates made in preparing these consolidated and combined financial statements include, among other things, (1) estimates relating to certain oil and natural gas revenue and costs, (2) estimates of oil and natural gas reserve quantities, which impact depreciation, depletion and amortization and impairment calculations, (3) estimates of timing and costs used in calculating asset retirement obligations and impairment, (4) estimates used in developing fair value assumptions and estimates, and (5) estimates and assumptions used in the disclosure of commitments and contingencies. Changes in the assumptions could have a significant impact on results in future periods.
Equity-based Compensation	Equity-based Compensation The Company recognizes compensation cost related to equity-based awards granted to employees, members of the Company’s board of directors and non-employee contractors in the financial statements based on their estimated grant-date fair value. The Company may grant various types of equity-based awards including stock options, stock appreciation rights, restricted stock, restricted stock units (including awards with service-based vesting and market condition-based vesting provisions), stock awards, dividend equivalents and other types of awards . Service-based restricted stock and units are valued using the market price of Jagged Peak’s common stock on the grant date. The fair value of the market condition-based restricted stock units are based on the grant-date fair value of the award utilizing a statistical analysis. Compensation cost is recognized ratably over the applicable vesting period, and is recognized in general and administrative expense in the consolidated and combined statements of operations. The Company has elected to account for forfeitures in compensation expense as they occur. Equity-based compensation arrangements to nonemployees are recognized as expense over the related service period and are subject to remeasurement at the end of each reporting period until they vest.
Income Taxes	Income Taxes The Company is a subchapter C corporation and is subject to U.S. federal and state income taxes. Income taxes are accounted for under the asset and liability method. The Company recognizes deferred tax assets and liabilities for the future tax consequences attributable to differences between the financial statement carrying amounts and income tax basis of assets and liabilities and the expected benefits of utilizing net operating losses and tax credit carryforwards, using enacted tax rates in effect for the taxing jurisdiction in which the Company operates for the year in which those temporary differences are expected to be recovered or settled. The Company classifies all deferred tax assets and liabilities as noncurrent. The Company recognizes the financial statement effects of a tax position when it is more likely than not, based on technical merits, that the position will be sustained upon examination. Net deferred tax assets are then reduced by a valuation allowance if the Company believes it is more likely than not such net deferred tax assets will not be realized.
Recent Accounting Pronouncements	Recent Accounting Pronouncements In May 2014, the FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , which outlines a new, single comprehensive model for entities to use in accounting for revenue arising from contracts with customers and supersedes most current revenue recognition guidance, including industry-specific guidance. This new revenue recognition model provides a five-step analysis in determining when and how revenue is recognized. The new guidance will require a company to recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration a company expects to receive in exchange for those goods or services. In May 2016, the FASB issued ASU 2016-11, which rescinds the U.S. Securities and Exchange Commission (“SEC”) accounting guidance regarding the use of the entitlements method for recognition of natural gas revenues. The standards can be adopted using either a full retrospective method or a modified retrospective method, as outlined in ASU 2014-09. The Company will adopt this standard on January 1, 2018, and will apply the modified retrospective method. The Company is in process of completing its evaluation of the impact of this standard on its financial statements and disclosures, internal controls and accounting policies. Based on the results to date, the Company has reached tentative conclusions and does not believe its existing revenue recognition processes and controls will change materially. The Company expects that certain additional disclosures will be required upon adoption of this standard. In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) , which requires all leases with a term greater than one year to be recognized on the balance sheet as lease assets and lease liabilities. This ASU retains a distinction between finance and operating leases concerning the recognition and presentation of the expense and payments related to leases in the statements of operations and cash flows. The new standard is effective for the Company on January 1, 2019. Although early adoption is permitted, the Company does not plan to early adopt the standard. The ASU requires the use of the modified retrospective approach, whereby lessees will be required to recognize and measure leases at the beginning of the earliest period presented. The Company is still in the process of evaluating the impact of this new standard; however, the Company believes the initial impact of adopting the standard will result in increases to its assets and liabilities on its consolidated balance sheets, and changes to the timing and presentation of certain operating expenses on its consolidated statements of operations. In May 2017, the FASB issued ASU 2017-09, Compensation-Stock Compensation (Topic 718) Scope of Modification Accounting . The ASU clarifies which changes to the terms or conditions of a share-based payment award require an entity to apply modification accounting in Topic 718. The standard is effective for the Company on January 1, 2018, with early adoption permitted. The impact of this new standard will depend on the extent and nature of future changes to the terms of Company's equity-based payment awards.

Significant Accounting Polici20

Significant Accounting Policies and Related Matters (Tables)	9 Months Ended
	Sep. 30, 2017
Accounting Policies [Abstract]
Schedule of Accounts Receivable	At September 30, 2017 and December 31, 2016 , accounts receivable was comprised of the following: (in thousands) September 30, 2017 December 31, 2016 Oil and gas sales $ 22,946 $ 8,861 Joint interest 10,769 580 Other 1,373 886 Total accounts receivable $ 35,088 $ 10,327
Property, Plant and Equipment	A summary of the Company’s oil and natural gas properties, net is as follows: (in thousands) September 30, 2017 December 31, 2016 Proved oil and natural gas properties $ 818,990 $ 375,129 Unproved oil and natural gas properties 187,757 155,992 Total oil and natural gas properties 1,006,747 531,121 Less: Accumulated depletion (123,448 ) (57,529 ) Total oil and natural gas properties, net $ 883,299 $ 473,592
Schedule of Accrued Liabilities	The components of accrued liabilities are shown below: (in thousands) September 30, 2017 December 31, 2016 Accrued capital expenditures $ 86,433 $ 28,490 Accrued accounts payable 3,349 3,312 Royalties payable 4,313 2,653 Other current liabilities 12,393 4,770 Total accrued liabilities $ 106,488 $ 39,225

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2017
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Derivative Instruments	The following table summarizes the Company’s derivative contracts as of September 30, 2017 : Contract Period Volumes Wtd Avg Price Oil Swaps (1) : Fourth quarter 2017 1,392,700 $ 51.34 Year ending December 31, 2018 5,263,350 $ 52.18 Year ending December 31, 2019 2,372,500 $ 51.89 Oil Basis Swaps (2) : Fourth quarter 2017 460,000 $ (1.00 ) Year ending December 31, 2018 5,110,000 $ (1.08 ) Year ending December 31, 2019 2,920,000 $ (1.10 ) (1) The index prices for the oil swaps are based on the NYMEX–WTI monthly average futures price. (2) The oil basis swap differential price is between Midland–WTI and Cushing–WTI.
Derivative Instruments, Gain (Loss)	The Company recognized the following gains (losses) in earnings for the periods indicated: Three Months Ended September 30, Nine Months Ended September 30, (in thousands) 2017 2016 2017 2016 Gain (loss) on derivatives instruments, net $ (27,693 ) $ 1,728 $ 15,922 $ (8,208 ) Cash settlements of derivatives (received) paid, net $ (3,195 ) $ 337 $ (3,691 ) $ 1,159
Schedule of Derivative Instruments by Balance Sheet Location	The following tables present the amounts and classifications of the Company’s commodity contract derivative assets and liabilities as of September 30, 2017 and December 31, 2016 (in thousands): As of September 30, 2017: Balance Sheet Location Gross amounts presented on the balance sheet Netting adjustments not offset on the balance sheet Net amounts Assets Commodity contracts Current assets - derivative instruments $ 5,515 $ (5,361 ) $ 154 Commodity contracts Noncurrent assets - derivative instruments 5,170 (1,602 ) 3,568 Total assets $ 10,685 $ (6,963 ) $ 3,722 Liabilities Commodity contracts Current liabilities - derivative instruments $ 8,820 $ (5,361 ) $ 3,459 Commodity contracts Noncurrent liabilities - derivative instruments 2,490 (1,602 ) 888 Total liabilities $ 11,310 $ (6,963 ) $ 4,347 As of December 31, 2016: Balance Sheet Location Gross amounts presented on the balance sheet Netting adjustments not offset on the balance sheet Net amounts Liabilities Commodity contracts Current liabilities - derivative instruments $ 9,567 — $ 9,567 Commodity contracts Noncurrent liabilities - derivative instruments 3,287 — 3,287 Total liabilities $ 12,854 $ — $ 12,854

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2017
Fair Value Disclosures [Abstract]
Fair Value, Assets and Liabilities Measured on Recurring Basis	The following table is a listing of the Company’s assets and liabilities that were measured at fair value on a recurring basis as of September 30, 2017 and December 31, 2016 : Level 2 (in thousands) September 30, 2017 December 31, 2016 Assets from commodity derivative contracts $ 10,685 $ — Liabilities due to commodity derivative contracts $ 11,310 $ 12,854

Equity-based Compensation (Tabl

Equity-based Compensation (Tables)	9 Months Ended
	Sep. 30, 2017
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Schedule of Employee Service Share-based Compensation, Allocation of Recognized Period Costs	Equity-based compensation expense, which is recorded in general and administrative expense in the accompanying consolidated and combined statements of operations, was as follows for the periods indicated: Three Months Ended September 30, Nine Months Ended September 30, (in thousands) 2017 2016 2017 2016 Incentive unit awards $ 10,692 $ — $ 429,585 $ — Restricted stock unit awards 521 — 898 — Performance stock unit awards 527 — 866 — Restricted stock unit awards issued to nonemployee directors 163 — 293 — Total equity-based compensation expense $ 11,903 $ — $ 431,642 $ —
Schedule of Share-based Compensation, Incentive Units, Activity	A summary of incentive unit award activity for the nine months ended September 30, 2017 is as follows: Weighted Average Grant-date Incentive Units Fair Value Unvested at Corporate Reorganization 9,570,280 $ 15.00 Granted 235,346 $ 12.41 Vested (2,049,881 ) $ 14.97 Forfeited — $ — Unvested at September 30, 2017 7,755,745 $ 14.93 Compensation costs remaining at September 30, 2017 (in millions) $ 90.5 Weighted average remaining period at September 30, 2017 (in years) 2.3
Schedule of Nonvested Restricted Stock Units Activity	A summary of RSU award activity for the nine months ended September 30, 2017 is as follows: Weighted Average Grant-date RSUs Fair Value Unvested at December 31, 2016 — $ — Granted 576,264 $ 12.42 Vested — $ — Forfeited (5,921 ) $ 12.61 Unvested at September 30, 2017 570,343 $ 12.42 Compensation costs remaining at September 30, 2017 (in millions) $ 5.9 Weighted average remaining period at September 30, 2017 (in years) 2.4
Share-based Compensation, Performance Shares Award Unvested Activity	A summary of PSU award activity for the nine months ended September 30, 2017 is as follows: Weighted Average Grant-date PSUs Fair Value Unvested at December 31, 2016 — $ — Granted 398,566 $ 16.32 Vested — $ — Forfeited — $ — Unvested at September 30, 2017 398,566 $ 16.32 Compensation costs remaining at September 30, 2017 (in millions) $ 5.6 Weighted average remaining period at September 30, 2017 (in years) 2.3
Schedule of Assumptions Used	The following table presents information regarding the weighted average fair value for PSUs granted during the nine months ended September 30, 2017 and the assumptions used to determine the fair values: Nine Months Ended September 30, 2017 Dividend yield — % Volatility 55.7 % Risk-free interest rate 1.34 % Weighted average fair value of awards granted $ 16.32

Earnings Per Share (Tables)

Earnings Per Share (Tables)	9 Months Ended
	Sep. 30, 2017
Earnings Per Share [Abstract]
Schedule of Earnings Per Share	A reconciliation of the components of basic and diluted earnings per common share is presented in the table below: Three Months Ended From January 27, 2017, to (in thousands, except per share amounts) September 30, 2017 September 30, 2017 Net income (loss) attributable to Jagged Peak Energy Inc. stockholders $ (15,219 ) $ (89,221 ) Basic weighted average shares outstanding 212,931 212,933 Effect of dilutive securities: Restricted stock units — — Performance stock units — — Diluted weighted average shares outstanding 212,931 212,933 Net income (loss) per common share: Basic $ (0.07 ) $ (0.42 ) Diluted $ (0.07 ) $ (0.42 )
Schedule of Antidilutive Securities Excluded from Computation of Earnings Per Share	The following table presents amounts that have been excluded from the computation of diluted earnings per common share as their inclusion would be anti-dilutive: Three Months Ended From January 27, 2017, to (in thousands) September 30, 2017 September 30, 2017 Weighted average number of outstanding equity awards excluded from diluted earnings per share calculation: (1) Restricted stock units 527 348 Performance stock units 671 421 (1) When the Company incurs a net loss, all outstanding equity awards are excluded from the calculation of diluted loss per common share because the inclusion of these awards would be anti-dilutive.

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2017
Income Tax Disclosure [Abstract]
Schedule of Components of Income Tax Expense (Benefit)	The components of the Company’s provision for income taxes are as follows: Three Months Ended Nine Months Ended (in thousands) September 30, 2017 September 30, 2017 Current income tax expense: Federal $ — $ — State — — — — Deferred income tax expense: Federal (2,543 ) 98,904 State (55 ) 2,135 (2,598 ) 101,039 Provision for income taxes $ (2,598 ) $ 101,039
Schedule of Effective Income Tax Rate Reconciliation	A reconciliation of the income tax expense calculated at the federal statutory rate of 35% to the total income tax expense is as follows: Three Months Ended Nine Months Ended (in thousands) September 30, 2017 September 30, 2017 Income (loss) before income taxes $ (17,817 ) $ (363,658 ) Less: net loss prior to corporate reorganization — (375,476 ) Income (loss) before income taxes subsequent to corporate reorganization $ (17,817 ) $ 11,818 Income taxes at the federal statutory rate $ (6,236 ) $ 4,136 Income tax expense relating to change in tax status — 78,019 State income taxes, net of federal benefit (35 ) 1,388 Nondeductible equity-based compensation 3,671 17,479 Other permanent differences 2 17 Income tax expense (benefit) $ (2,598 ) $ 101,039 Effective tax rate 14.6 % (27.8 )%
Schedule of Deferred Tax Assets and Liabilities	The components of the Company’s deferred income tax assets and liabilities as of September 30, 2017 are as follows: (in thousands) September 30, 2017 Deferred income tax assets: Net operating loss carryforwards $ 1,526 Commodity derivatives 221 Equity-based compensation 502 Other 1,302 3,551 Deferred income tax liabilities: Oil and natural gas properties 104,590 104,590 Net deferred income tax assets (liabilities) $ (101,039 )

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2017
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The following table summarizes the changes in the carrying amount of the asset retirement obligations for the nine months ended September 30, 2017 : (in thousands) Asset retirement obligations at January 1, 2017 $ 448 Liabilities incurred and assumed 492 Liability settlements and disposals (10 ) Revisions of estimated liabilities (5 ) Accretion 49 Asset retirement obligations at September 30, 2017 974 Less current portion of asset retirement obligations (284 ) Long-term asset retirement obligations $ 690

Related Party Transactions (Tab

Related Party Transactions (Tables)	9 Months Ended
	Sep. 30, 2017
Related Party Transactions [Abstract]
Schedule of Related Party Transactions	The following table summarizes fees paid to Oryx, Phoenix and Trident for the periods indicated: Three Months Ended September 30, Nine Months Ended September 30, (in thousands) 2017 2016 2017 2016 Oryx via 3rd party shipper (1) $ 2,918 $ 938 $ 6,716 $ 1,037 Oryx (2) $ 97 $ 166 $ 749 $ 1,091 Phoenix $ 56 $ 111 $ 258 $ 260 Trident $ — $ 90 $ 236 $ 413 (1) Transportation fees paid by the Company’s third party shipper to Oryx pursuant to the crude oil gathering agreement. (2) Fees paid to Oryx for the purchase and maintenance of connecting equipment.

Organization, Operations and 28

Organization, Operations and Basis of Presentation (Details) - USD ($) $ / shares in Units, $ in Thousands	Jan. 27, 2017	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Debt Instrument [Line Items]
Gross proceeds		$ 401,625	$ 0
Expenses and underwriting discounts and commissions		$ 3,216	$ 95
Quantum
Debt Instrument [Line Items]
Ownership interest	68.70%			98.60%
Line of Credit | JPE LLC
Debt Instrument [Line Items]
Credit facility repayments	$ 142,000
IPO
Debt Instrument [Line Items]
Shares sold (in shares)	31,599,334
Price per share (in dollars per share)	$ 15
Gross proceeds	$ 474,000
IPO Sold By Company
Debt Instrument [Line Items]
Shares sold (in shares)	28,333,334
Gross proceeds	$ 425,000
Net proceeds	397,000
Expenses and underwriting discounts and commissions	$ 28,000
IPO Sold by Stockholders
Debt Instrument [Line Items]
Shares sold (in shares)	3,266,000

Significant Accounting Polici29

Significant Accounting Policies and Related Matters - Schedule of Accounts Receivable (Details) - USD ($)	Sep. 30, 2017	Dec. 31, 2016
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total accounts receivable	$ 35,088,000	$ 10,327,000
Reserve for doubtful accounts	0	0
Oil and gas sales
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total accounts receivable	22,946,000	8,861,000
Joint interest
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total accounts receivable	10,769,000	580,000
Other
Accounts, Notes, Loans and Financing Receivable [Line Items]
Total accounts receivable	$ 1,373,000	$ 886,000

Significant Accounting Polici30

Significant Accounting Policies and Related Matters - Oil and Natural Gas Properties (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Accounting Policies [Abstract]
Proved oil and natural gas properties	$ 818,990		$ 818,990		$ 375,129
Unproved oil and natural gas properties	187,757		187,757		155,992
Total oil and natural gas properties	1,006,747		1,006,747		531,121
Less: Accumulated depletion	(123,448)		(123,448)		(57,529)
Total oil and gas properties, net	883,299		883,299		$ 473,592
Depletion for oil and natural gas properties	$ 30,400	$ 10,800	$ 65,900	$ 28,800

Significant Accounting Polici31

Significant Accounting Policies and Related Matters - Schedule of Accrued Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Accounting Policies [Abstract]
Accrued capital expenditures	$ 86,433	$ 28,490
Accrued accounts payable	3,349	3,312
Royalties payable	4,313	2,653
Other current liabilities	12,393	4,770
Total accrued liabilities	$ 106,488	$ 39,225

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Derivatives (Details) - Not Designated as Hedging Instrument	Sep. 30, 2017$ / bblbbl
Fourth quarter 2017
Derivative [Line Items]
Volumes (Bbls) | bbl	1,392,700
Wtd Avg Price ($/Bbl) | $ / bbl	(51.34)
Year ending December 31, 2018
Derivative [Line Items]
Volumes (Bbls) | bbl	5,263,350
Wtd Avg Price ($/Bbl) | $ / bbl	(52.18)
Year ending December 31, 2019
Derivative [Line Items]
Volumes (Bbls) | bbl	2,372,500
Wtd Avg Price ($/Bbl) | $ / bbl	(51.89)
Fourth quarter 2017
Derivative [Line Items]
Volumes (Bbls) | bbl	460,000
Wtd Avg Price ($/Bbl) | $ / bbl	(1)
Year ending December 31, 2018
Derivative [Line Items]
Volumes (Bbls) | bbl	5,110,000
Wtd Avg Price ($/Bbl) | $ / bbl	(1.08)
Year ending December 31, 2019
Derivative [Line Items]
Volumes (Bbls) | bbl	2,920,000
Wtd Avg Price ($/Bbl) | $ / bbl	(1.10)

Derivative Instruments - Gains

Derivative Instruments - Gains (Losses) in Earnings (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Gain (loss) on derivatives instruments, net	$ (27,693)	$ 1,728	$ 15,922	$ (8,208)
Cash settlements of derivatives (received) paid, net	$ (3,195)	$ 337	$ (3,691)	$ 1,159

Derivative Instruments - Balanc

Derivative Instruments - Balance Sheet Location (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Derivatives, Fair Value [Line Items]
Gross amounts presented on the balance sheet, assets	$ 10,685
Netting adjustments not offset on the balance sheet, assets	(6,963)
Assets from commodity derivative contracts, assets	3,722
Gross amounts presented on the balance sheet, liabilities	11,310	$ 12,854
Netting adjustments not offset on the balance sheet, liabilities	(6,963)	0
Liabilities from commodity derivative contracts, liabilities	4,347	12,854
Commodity contracts | Current assets - derivative instruments
Derivatives, Fair Value [Line Items]
Gross amounts presented on the balance sheet, assets	5,515
Netting adjustments not offset on the balance sheet, assets	(5,361)
Assets from commodity derivative contracts, assets	154
Commodity contracts | Noncurrent assets - derivative instruments
Derivatives, Fair Value [Line Items]
Gross amounts presented on the balance sheet, assets	5,170
Netting adjustments not offset on the balance sheet, assets	(1,602)
Assets from commodity derivative contracts, assets	3,568
Commodity contracts | Current liabilities - derivative instruments
Derivatives, Fair Value [Line Items]
Gross amounts presented on the balance sheet, liabilities	8,820	9,567
Netting adjustments not offset on the balance sheet, liabilities	(5,361)	0
Liabilities from commodity derivative contracts, liabilities	3,459	9,567
Commodity contracts | Noncurrent liabilities - derivative instruments
Derivatives, Fair Value [Line Items]
Gross amounts presented on the balance sheet, liabilities	2,490	3,287
Netting adjustments not offset on the balance sheet, liabilities	(1,602)	0
Liabilities from commodity derivative contracts, liabilities	$ 888	$ 3,287

Derivative Instruments - Narrat

Derivative Instruments - Narrative (Details)	Sep. 30, 2017counterparty
Commodity contracts
Derivative [Line Items]
Number of counterparties	3

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from commodity derivative contracts	$ 10,685,000		$ 10,685,000
Liabilities due to commodity derivative contracts	11,310,000		11,310,000		$ 12,854,000
Proved property impairment	0	$ 0	0	$ 0
Impairment of unproved oil and gas properties	257,000	$ 7,000	365,000	$ 317,000
Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets from commodity derivative contracts	10,685,000		10,685,000		0
Liabilities due to commodity derivative contracts	$ 11,310,000		$ 11,310,000		$ 12,854,000

Debt Obligations (Details)

Debt Obligations (Details)	Dec. 31, 2016USD ($)bank	Oct. 31, 2017USD ($)	Feb. 28, 2017USD ($)	Jan. 31, 2017USD ($)bank	Jun. 30, 2015USD ($)	Sep. 30, 2017USD ($)bank	Apr. 30, 2017USD ($)
Debt Instrument [Line Items]
Balance outstanding	$ 132,000,000					$ 35,000,000
Revolving Credit Facility | Amended And Restated Credit Facility
Debt Instrument [Line Items]
Maximum borrowing capacity			$ 1,000,000,000
Current borrowing capacity			$ 180,000,000				$ 250,000,000
Balance outstanding						$ 35,000,000
Weighted average interest rate						3.49%
Number of lenders | bank						9
Commitment fee						0.50%
Percent of proved reserves (at least)			90.00%
Minimum current ratio			1
Maximum leverage ratio			4
Revolving Credit Facility | Amended And Restated Credit Facility | Federal Funds Effective Rate
Debt Instrument [Line Items]
Basis spread on variable rate						0.50%
Revolving Credit Facility | Amended And Restated Credit Facility | Federal Funds Effective Rate | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate						1.25%
Revolving Credit Facility | Amended And Restated Credit Facility | Federal Funds Effective Rate | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate						2.25%
Revolving Credit Facility | Amended And Restated Credit Facility | LIBOR
Debt Instrument [Line Items]
Basis spread on variable rate						1.00%
Revolving Credit Facility | Amended And Restated Credit Facility | LIBOR | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate						2.25%
Revolving Credit Facility | Amended And Restated Credit Facility | LIBOR | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate						3.25%
JPE LLC | Revolving Credit Facility | The Credit Facility
Debt Instrument [Line Items]
Debt term					5 years
Maximum borrowing capacity					$ 500,000,000
Current borrowing capacity	160,000,000
Balance outstanding	132,000,000
Borrowing capacity remaining	$ 28,000,000
Weighted average interest rate	3.99%
Number of lenders | bank	5
JPE LLC | Revolving Credit Facility | The Amended Credit Facility
Debt Instrument [Line Items]
Current borrowing capacity				$ 180,000,000
Number of lenders | bank				9
Subsequent Event | Revolving Credit Facility | Amendment No. 1
Debt Instrument [Line Items]
Current borrowing capacity		$ 425,000,000
Subsequent Event | Revolving Credit Facility | Amendment No. 1 | Minimum
Debt Instrument [Line Items]
Commitment fee		0.375%
Subsequent Event | Revolving Credit Facility | Amendment No. 1 | Maximum
Debt Instrument [Line Items]
Commitment fee		0.50%
Subsequent Event | Revolving Credit Facility | Amendment No. 1 | Federal Funds Effective Rate
Debt Instrument [Line Items]
Basis spread on variable rate		0.50%
Subsequent Event | Revolving Credit Facility | Amendment No. 1 | Federal Funds Effective Rate | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate		1.00%
Subsequent Event | Revolving Credit Facility | Amendment No. 1 | Federal Funds Effective Rate | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate		2.00%
Subsequent Event | Revolving Credit Facility | Amendment No. 1 | LIBOR
Debt Instrument [Line Items]
Basis spread on variable rate		1.00%
Subsequent Event | Revolving Credit Facility | Amendment No. 1 | LIBOR | Minimum
Debt Instrument [Line Items]
Basis spread on variable rate		2.00%
Subsequent Event | Revolving Credit Facility | Amendment No. 1 | LIBOR | Maximum
Debt Instrument [Line Items]
Basis spread on variable rate		3.00%

Equity-based Compensation - Add

Equity-based Compensation - Additional Information (Details) - USD ($)	1 Months Ended		3 Months Ended		9 Months Ended		12 Months Ended
	Jan. 26, 2017	Apr. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016	Jan. 27, 2017
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation awards authorized for grant (up to) (in shares)			21,200,000		21,200,000
Equity-based compensation expense			$ 11,903,000	$ 0	$ 431,642,000	$ 0
Profit Interest Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based compensation expense	$ 379,000,000	$ 14,700,000	10,692,000	0	$ 429,585,000	0	$ 0
Vesting period					3 years
Fair value of vested units					$ 25,200,000
Granted (in shares)					235,346
Weighted average grant date fair value (in dollars per share)					$ 12.41
Compensation costs remaining			90,500,000		$ 90,500,000
Weighted average remaining period					2 years 3 months 18 days
Restricted stock unit awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based compensation expense			521,000	0	$ 898,000	0
Granted (in shares)					576,264
Weighted average grant date fair value (in dollars per share)					$ 12.42
Compensation costs remaining			5,900,000		$ 5,900,000
Weighted average remaining period					2 years 4 months 24 days
Performance stock unit awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based compensation expense			527,000	$ 0	$ 866,000	$ 0
Granted (in shares)					398,566
Weighted average grant date fair value (in dollars per share)					$ 16.32
Compensation costs remaining			5,600,000		$ 5,600,000
Weighted average remaining period					2 years 3 months 18 days
Performance awards service period					3 years
IPO
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Price per share (in dollars per share)								$ 15
Management Holdco | Profit Interest Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based compensation expense			$ 10,700,000		$ 50,600,000
Unallocated shares held (in shares)			431,321		431,321
Management Holdco | Profit Interest Awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity-based compensation expense					$ 22,200,000
Minimum | Performance stock unit awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percent of units granted					0.00%
Maximum | Performance stock unit awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Percent of units granted					200.00%
Nonemployee Director | Restricted stock unit awards
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Granted (in shares)					55,744
Weighted average grant date fair value (in dollars per share)					$ 12.46
Compensation costs remaining			$ 400,000		$ 400,000
Weighted average remaining period					7 months 21 days

Equity-based Compensation - Sha

Equity-based Compensation - Share-based Compensation Expense (Details) - USD ($)	1 Months Ended		3 Months Ended		9 Months Ended		12 Months Ended
	Jan. 26, 2017	Apr. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Total equity-based compensation expense			$ 11,903,000	$ 0	$ 431,642,000	$ 0
Incentive unit awards
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Total equity-based compensation expense	$ 379,000,000	$ 14,700,000	10,692,000	0	429,585,000	0	$ 0
Restricted stock unit awards
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Total equity-based compensation expense			521,000	0	898,000	0
Performance stock unit awards
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Total equity-based compensation expense			527,000	0	866,000	0
Restricted stock unit awards issued to nonemployee directors
Share-based Compensation Arrangement by Share-based Payment Award, Compensation Cost [Line Items]
Total equity-based compensation expense			$ 163,000	$ 0	$ 293,000	$ 0

Equity-based Compensation - Sto

Equity-based Compensation - Stock Options Activity (Details) - Profit Interest Awards $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2017USD ($)$ / sharesshares
Incentive Units
Unvested beginning balance (in shares) | shares	9,570,280
Granted (in shares) | shares	235,346
Vested (in shares) | shares	(2,049,881)
Forfeited (in shares) | shares	0
Unvested ending balance (in shares) | shares	7,755,745
Weighted Average Grant-date Fair Value
Unvested beginning balance (in dollars per share) | $ / shares	$ 15
Granted (in dollars per share) | $ / shares	12.41
Vested (in dollars per share) | $ / shares	14.97
Forfeited (in dollars per share) | $ / shares	0
Unvested ending balance (in dollars per share) | $ / shares	$ 14.93
Compensation costs remaining | $	$ 90.5
Weighted average remaining period	2 years 3 months 18 days

Equity-based Compensation - Non

Equity-based Compensation - Nonvested Restricted Stock Units Activity (Details) - Restricted stock unit awards $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2017USD ($)$ / sharesshares
RSUs
Unvested beginning balance (in shares) | shares	0
Granted (in shares) | shares	576,264
Vested (in shares) | shares	0
Forfeited (in shares) | shares	(5,921)
Unvested ending balance (in shares) | shares	570,343
Weighted Average Grant-date Fair Value
Unvested beginning balance (in dollars per share) | $ / shares	$ 0
Granted (in dollars per share) | $ / shares	12.42
Vested (in dollars per share) | $ / shares	0
Forfeited (in dollars per share) | $ / shares	12.61
Unvested ending balance (in dollars per share) | $ / shares	$ 12.42
Compensation costs remaining | $	$ 5.9
Weighted average remaining period	2 years 4 months 24 days

Equity-based Compensation - N42

Equity-based Compensation - Nonvested Performance Shares Award Activity (Details) - PSUs $ / shares in Units, $ in Millions	9 Months Ended
	Sep. 30, 2017USD ($)$ / sharesshares
PSUs
Unvested beginning balance (in shares) | shares	0
Granted (in shares) | shares	398,566
Vested (in shares) | shares	0
Forfeited (in shares) | shares	0
Unvested ending balance (in shares) | shares	398,566
Weighted Average Grant-date Fair Value
Unvested beginning balance (in dollars per share) | $ / shares	$ 0
Granted (in dollars per share) | $ / shares	16.32
Vested (in dollars per share) | $ / shares	0
Forfeited (in dollars per share) | $ / shares	0
Unvested ending balance (in dollars per share) | $ / shares	$ 16.32
Compensation costs remaining | $	$ 5.6
Weighted average remaining period	2 years 3 months 18 days

Equity-based Compensation - Val

Equity-based Compensation - Valuation Assumptions (Details) - Performance stock unit awards	9 Months Ended
	Sep. 30, 2017$ / shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Dividend yield	0.00%
Volatility	55.70%
Risk-free interest rate	1.34%
Weighted average fair value of awards granted	$ 16.32

Earnings Per Share - Schedule o

Earnings Per Share - Schedule of Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	1 Months Ended	3 Months Ended		8 Months Ended	9 Months Ended
	Jan. 26, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2017	Sep. 30, 2016
Earnings Per Share [Line Items]
Net income (loss)	$ (375,476)	$ (15,219)	$ 5,410	$ (89,221)	$ (464,697)	$ (7,789)
Weighted average shares outstanding - basic (in shares)		212,931		212,933	212,933
Effect of dilutive securities:
Weighted average shares outstanding - diluted (in shares)		212,931		212,933	212,933
Net income (loss) per common share:
Basic (in dollars per share)		$ (0.07)		$ (0.42)	$ (0.42)
Diluted (in dollars per share)		$ (0.07)		$ (0.42)	$ (0.42)
Restricted stock unit awards
Effect of dilutive securities:
Effect of dilutive securities (in shares)		0		0
Performance stock unit awards
Effect of dilutive securities:
Effect of dilutive securities (in shares)		0		0

Earnings Per Share - Antidiluti

Earnings Per Share - Antidilutive Securities (Details) - shares shares in Thousands	3 Months Ended	8 Months Ended
	Sep. 30, 2017	Sep. 30, 2017
Restricted stock unit awards
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Weighted average number of outstanding equity awards excluded from diluted earnings per share calculation (in shares)	527	348
Performance stock unit awards
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Weighted average number of outstanding equity awards excluded from diluted earnings per share calculation (in shares)	671	421

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($)	3 Months Ended
	Mar. 31, 2017	Sep. 30, 2017
Income Tax Disclosure [Abstract]
Deferred income taxes	$ 79,100,000
Operating loss carryforwards, domestic		$ 4,300,000
Valuation allowance		0
Unrecognized tax benefits		0
Income tax penalties and interest accrued		$ 0

Income Taxes - Components of In

Income Taxes - Components of Income Tax Expense (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Current income tax expense:
Federal	$ 0		$ 0
State	0		0
Current income taxes	0		0
Deferred income tax expense:
Federal	(2,543)		98,904
State	(55)		2,135
Deferred income taxes	(2,598)		101,039	$ 0
Provision for income taxes	$ (2,598)	$ 0	$ 101,039	$ 0

Income Taxes - Effective Tax Ra

Income Taxes - Effective Tax Rate Reconciliation (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		8 Months Ended	9 Months Ended
	Jan. 26, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2017	Sep. 30, 2016
Income Tax Disclosure [Abstract]
Federal statutory rate					35.00%
Income (loss) before income taxes		$ (17,817)	$ 5,410	$ 11,818	$ (363,658)	$ (7,789)
Net income (loss)	$ (375,476)	(15,219)	5,410	$ (89,221)	(464,697)	(7,789)
Income taxes at the federal statutory rate		(6,236)			4,136
Income tax expense relating to change in tax status		0			78,019
State income taxes, net of federal benefit		(35)			1,388
Nondeductible equity-based compensation		3,671			17,479
Other permanent differences		2			17
Provision for income taxes		$ (2,598)	$ 0		$ 101,039	$ 0
Effective tax rate		14.60%			(27.80%)

Income Taxes - Deferred Tax Ass

Income Taxes - Deferred Tax Assets and Liabilities (Details) $ in Thousands	Sep. 30, 2017USD ($)
Deferred income tax assets:
Net operating loss carryforwards	$ 1,526
Commodity derivatives	221
Equity-based compensation	502
Other	1,302
Total deferred tax assets	3,551
Deferred income tax liabilities:
Oil and natural gas properties	104,590
Total deferred tax liabilities	104,590
Net deferred income tax assets (liabilities)	$ (101,039)

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Dec. 31, 2016
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation, beginning balance	$ 448
Liabilities incurred and assumed	492
Liability settlements and disposals	(10)
Revisions of estimated liabilities	(5)
Accretion	49
Asset retirement obligation, ending balance	974
Less current portion of asset retirement obligations	(284)
Long-term asset retirement obligations	$ 690	$ 448

Commitments and Contingencies (

Commitments and Contingencies (Details) $ in Millions	9 Months Ended
	Sep. 30, 2016USD ($)contract	Sep. 30, 2017USD ($)contractfrac_fleet_contract
Loss Contingencies [Line Items]
Number of drilling rig contracts | contract		7
Early termination penalties		$ 11.1
Number of drilling rig contracts terminated | contract	1
Early termination charges	$ 0.2
Operating lease arrangement		$ 16.7
Frac Fleet Contract
Loss Contingencies [Line Items]
Frac fleet under contract | frac_fleet_contract		3
Remaining contract commitment during fiscal year		$ 13.8
Remaining contract commitment year two		73.2
Termination fees		$ 66.2

Related Party Transactions - Na

Related Party Transactions - Narrative (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2017	Jan. 27, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Outstanding payables	$ 1.1		$ 0.7
Quantum
Related Party Transaction [Line Items]
Ownership interest		68.70%	98.60%
IPO | Quantum
Related Party Transaction [Line Items]
Ownership percent after IPO	68.70%
Oryx Midstream Services, LLC | Oil Gathering Agreement
Related Party Transaction [Line Items]
Contract agreement term	12 years
Investee | Oryx Midstream Services, LLC | Quantum
Related Party Transaction [Line Items]
Ownership interest	41.50%
Investee | Phoenix Lease Services, LLC | Quantum
Related Party Transaction [Line Items]
Ownership interest	60.90%

Related Party Transactions - Sc

Related Party Transactions - Schedule of Related Party Transactions (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Phoenix Lease Services, LLC
Related Party Transaction [Line Items]
Fees paid to related party	$ 56	$ 111	$ 258	$ 260
Trident Water Services, LLC
Related Party Transaction [Line Items]
Fees paid to related party	0	90	236	413
Oil Gathering Agreement | Oryx Midstream Services, LLC
Related Party Transaction [Line Items]
Fees paid to related party	2,918	938	6,716	1,037
Leasing Of Equipment | Oryx Midstream Services, LLC
Related Party Transaction [Line Items]
Fees paid to related party	$ 97	$ 166	$ 749	$ 1,091