Pressburg (ROAN) 10-Q 6 Nov 19 2019 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2019	Nov. 04, 2019
Document And Entity Information [Abstract]
Entity Registrant Name	ROAN RESOURCES, INC.
Entity Central Index Key	0001326428
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Sep. 30, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding		154,333,746
Entity Emerging Growth Company	false
Entity Small Business	false
Entity Current Reporting Status	Yes
Entity Shell Company	false

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Current assets
Cash and cash equivalents	$ 3,464	$ 6,883
Accounts receivable
Oil, natural gas and natural gas liquid sales, net	41,635	55,564
Joint interest owners and other, net	146,449	133,387
Affiliates	2,684	9,669
Prepaid drilling advances	3,898	28,977
Derivative contracts	47,840	82,180
Other current assets	5,922	6,655
Total current assets	251,892	323,315
Noncurrent assets
Oil and natural gas properties, successful efforts method	3,040,279	2,628,333
Accumulated depreciation, depletion, amortization and impairment	(400,710)	(230,836)
Oil and natural gas properties, net	2,639,569	2,397,497
Derivative contracts	18,794	20,638
Other	11,780	7,659
Total assets	2,922,035	2,749,109
Current liabilities
Accounts payable	67,821	49,746
Accrued liabilities	84,716	176,494
Accounts payable and accrued liabilities – Affiliates	7,721	8,577
Revenue payable	99,623	97,963
Drilling advances	15,885	31,058
Derivative contracts	0	845
Other current liabilities	2,666	790
Total current liabilities	278,432	365,473
Noncurrent liabilities
Long-term debt	732,639	514,639
Long-term debt, net - Affiliates	45,595	0
Deferred tax liabilities, net	353,274	356,862
Asset retirement obligations	17,887	16,058
Derivative contracts	0	141
Other	5,661	902
Total liabilities	1,433,488	1,254,075
Commitments and contingencies (Note 14)
Equity
Class A common stock, $0.001 par value; 800,000,000 shares authorized; 154,333,746 shares issued and outstanding at September 30, 2019 and 152,539,532 shares issued and outstanding at December 31, 2018	154	153
Preferred stock, $0.001 par value; 50,000,000 shares authorized; no shares issued and outstanding at September 30, 2019 or December 31, 2018	0	0
Additional paid-in capital	1,651,556	1,646,401
Treasury stock, at cost	(128)	0
Accumulated deficit	(163,035)	(151,520)
Total equity	1,488,547	1,495,034
Total liabilities and equity	$ 2,922,035	$ 2,749,109

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - $ / shares	Sep. 30, 2019	Dec. 31, 2018
Statement of Financial Position [Abstract]
Common stock, par value (usd per share)	$ 0.001	$ 0.001
Common shares authorized (shares)	800,000,000	800,000,000
Common shares issued (shares)	154,333,746	152,539,532
Common shares outstanding (shares)	154,333,746	152,539,532
Preferred stock, par value (usd per share)	$ 0.001	$ 0.001
Preferred shares authorized (shares)	50,000,000	50,000,000
Preferred shares issued (shares)	0	0
Preferred shares outstanding (shares)	0	0

Condensed Consolidated Statemen

Condensed Consolidated Statements of Operations (Unaudited) - USD ($) shares in Thousands, $ in Thousands	3 Months Ended			9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018		Sep. 30, 2019	Sep. 30, 2018
Revenues
Gain (loss) on derivative contracts	$ 40,675	$ (36,704)		$ (5,913)	$ (100,920)
Total revenues	133,055	83,448		282,126	210,769
Operating Expenses
Production expenses	7,439	14,737		29,008	30,111
Production taxes	4,839	6,210		14,943	10,892
Exploration expenses	14,578	11,646		38,472	30,129
Depreciation, depletion, amortization and accretion	55,504	37,164		141,969	83,630
General and administrative	8,752	13,177		36,888	40,283
Gain on sale of other assets	(31)	0		(645)	0
Total operating expenses	96,512	82,934		270,646	195,045
Total operating income	36,543	514		11,480	15,724
Other income (expense)
Interest expense, net	(9,051)	(2,092)		(24,230)	(4,978)
Interest expense - Affiliates	(2,317)	0		(2,344)	0
Other	18	0		(10)	0
Net income (loss) before income taxes	25,193	(1,578)		(15,104)	10,746
Income tax expense (benefit)	5,898	299,662		(3,589)	299,662
Net income (loss)	$ 19,295	$ (301,240)	[1]	$ (11,515)	$ (288,916)
Earnings (loss) per share
Basic (usd per share)	$ 0.13	$ (1.97)		$ (0.08)	$ (1.90)
Diluted (usd per share)	$ 0.13	$ (1.97)		$ (0.08)	$ (1.90)
Weighted average number of shares outstanding
Basic (shares)	154,150	152,540		153,104	152,129
Diluted (shares)	154,150	152,540		153,104	152,129
Affiliates
Operating Expenses
Production expenses	$ 5,431	$ 0		$ 10,011	$ 0
Oil sales
Revenues
Revenues	70,371	74,987		200,138	197,356
Natural gas sales
Revenues
Revenues	7,114	10,442		24,962	31,900
Natural gas sales | Affiliates
Revenues
Revenues	4,070	7,617		21,092	17,056
Natural gas liquid sales
Revenues
Revenues	6,901	12,983		23,721	38,127
Natural gas liquid sales | Affiliates
Revenues
Revenues	$ 3,924	$ 14,123		$ 18,126	$ 27,250
[1]	Amounts were allocated to stockholders’ equity and members’ equity to reflect the Reorganization. See Note 10 – Equity for discussion of the Reorganization.

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Changes in Equity (Unaudited) - USD ($) shares in Thousands, $ in Thousands		Total	Common Stock	Additional Paid-in Capital	Accumulated Deficit	Treasury Stock	Members’ Equity
Beginning balance (shares) at Dec. 31, 2017			0
Beginning balance at Dec. 31, 2017		$ 1,584,769	$ 0	$ 0	$ 0	$ 0	$ 1,584,769
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Acquisition of oil and natural gas properties in exchange for equity units		39,906					39,906
Equity-based compensation		2,292					2,292
Net (loss) income		35,081					35,081
Ending balance (shares) at Mar. 31, 2018			0
Ending balance at Mar. 31, 2018		1,662,048	$ 0	0	0	0	1,662,048
Beginning balance (shares) at Dec. 31, 2017			0
Beginning balance at Dec. 31, 2017		1,584,769	$ 0	0	0	0	1,584,769
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Acquisition of oil and natural gas properties in exchange for equity units		39,906
Net (loss) income		(288,916)
Ending balance (shares) at Sep. 30, 2018			152,540
Ending balance at Sep. 30, 2018		1,343,819	$ 153	1,643,431	(299,765)	0	0
Beginning balance (shares) at Mar. 31, 2018			0
Beginning balance at Mar. 31, 2018		1,662,048	$ 0	0	0	0	1,662,048
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Equity-based compensation		2,835					2,835
Net (loss) income		(22,757)					(22,757)
Ending balance (shares) at Jun. 30, 2018			0
Ending balance at Jun. 30, 2018		1,642,126	$ 0	0	0	0	1,642,126
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of common stock (shares)			152,540
Issuance of common stock			$ 153	1,643,239			(1,643,392)
Equity-based compensation	[1]	2,933		192			2,741
Net (loss) income	[1]	(301,240)			(299,765)		(1,475)
Ending balance (shares) at Sep. 30, 2018			152,540
Ending balance at Sep. 30, 2018		1,343,819	$ 153	1,643,431	(299,765)	0	0
Beginning balance (shares) at Dec. 31, 2018			152,540
Beginning balance at Dec. 31, 2018		1,495,034	$ 153	1,646,401	(151,520)	0	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Equity-based compensation		3,065		3,065
Net (loss) income		(58,056)			(58,056)
Ending balance (shares) at Mar. 31, 2019			152,540
Ending balance at Mar. 31, 2019		1,440,043	$ 153	1,649,466	(209,576)	0	0
Beginning balance (shares) at Dec. 31, 2018			152,540
Beginning balance at Dec. 31, 2018		1,495,034	$ 153	1,646,401	(151,520)	0	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Acquisition of oil and natural gas properties in exchange for equity units		0
Net (loss) income		(11,515)
Ending balance (shares) at Sep. 30, 2019			154,334
Ending balance at Sep. 30, 2019		1,488,547	$ 154	1,651,556	(163,035)	(128)	0
Beginning balance (shares) at Mar. 31, 2019			152,540
Beginning balance at Mar. 31, 2019		1,440,043	$ 153	1,649,466	(209,576)	0	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of common stock (shares)			1,525
Issuance of common stock		2,318	$ 1	2,317
Equity-based compensation		(3,222)		(3,222)
Net (loss) income		27,246			27,246
Ending balance (shares) at Jun. 30, 2019			154,065
Ending balance at Jun. 30, 2019		1,466,385	$ 154	1,648,561	(182,330)	0	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Vesting of restricted stock units (shares)			269
Purchase of treasury stock		(128)				(128)
Equity-based compensation		2,995		2,995
Net (loss) income		19,295			19,295
Ending balance (shares) at Sep. 30, 2019			154,334
Ending balance at Sep. 30, 2019		$ 1,488,547	$ 154	$ 1,651,556	$ (163,035)	$ (128)	$ 0
[1]	Amounts were allocated to stockholders’ equity and members’ equity to reflect the Reorganization. See Note 10 – Equity for discussion of the Reorganization.

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018
Cash flows from operating activities
Net loss	$ (11,515)	$ (288,916)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion, amortization and accretion	141,969	83,630
Unproved leasehold amortization and impairment	35,932	25,642
Gain on sale of other assets	(645)	0
Amortization of deferred financing costs	2,332	571
Loss on derivative contracts	5,913	100,920
Net cash received (paid) upon settlement of derivative contracts	20,006	(27,462)
Equity-based compensation	2,838	8,060
Deferred income taxes	(3,589)	299,662
Other	4,110	551
Changes in operating assets and liabilities increasing (decreasing) cash:
Accounts receivable and other assets	(31,775)	(154,716)
Accounts payable and other liabilities	4,422	158,702
Net cash provided by operating activities	169,998	206,644
Cash flows from investing activities
Acquisition of oil and natural gas properties	0	(22,935)
Capital expenditures for oil and natural gas properties	(447,433)	(485,580)
Acquisition of other property and equipment	(83)	(2,353)
Proceeds from sale of other assets	1,475	0
Net cash used in investing activities	(446,041)	(510,868)
Cash flows from financing activities
Proceeds from borrowings	263,000	309,300
Proceeds from borrowings - Affiliates	48,750	0
Repayment of borrowings	(45,000)	0
Other	5,874	(2,647)
Net cash provided by financing activities	272,624	306,653
Net (decrease) increase in cash and cash equivalents	(3,419)	2,429
Cash and cash equivalents, beginning of period	6,883	1,471
Cash and cash equivalents, end of period	3,464	3,900
Supplemental disclosure of cash flow information
Cash paid for interest, net of capitalized interest	22,172	4,024
Supplemental disclosure of non-cash investing and financing activities
Change in accrued capital expenditures	(61,408)	38,593
Acquisition of oil and natural gas properties for equity	0	39,906
Right of use assets obtained in exchange for operating lease liabilities	6,336	0
Issuance of common stock in connection with Term Loan	$ 2,317	$ 0

Business and Organization

Business and Organization	9 Months Ended
	Sep. 30, 2019
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Business and Organization	Note 1 – Business and Organization Roan Resources, Inc. (“Roan Inc.” or the “Company”) was formed in September 2018 to facilitate a reorganization and to become the holding company for Roan Resources LLC (“Roan LLC”). In September 2018, a series of transactions were executed with Roan LLC’s members which resulted in Roan LLC becoming a wholly owned subsidiary of Roan Inc. These transactions are hereafter referred to as the “Reorganization.” See Note 10 – Equity for further discussion of the Reorganization transaction. The accompanying historical financial statements for the three and nine months ended September 30, 2018 are the financial statements of Roan LLC, our accounting predecessor. Following the Reorganization, the historical financial statements are the results of Roan Inc. Roan LLC was initially formed by Citizen Energy II, LLC (“Citizen”) in May 2017. On August 31, 2017, a contribution agreement (the “Contribution Agreement”) by and among Roan LLC, Citizen, Linn Energy Holdings, LLC (“LEH”) and Linn Operating, LLC (together with LEH, “Linn”) was executed, pursuant to which, among other things, Citizen and Linn agreed to contribute oil and natural gas properties within an area-of-mutual-interest to Roan LLC (collectively the “Contribution”). In exchange for their contributions, Citizen and Linn each received a 50% equity interest in Roan LLC. In conjunction with the Contribution Agreement, Roan LLC entered into management services agreements with both Citizen and Linn (“MSAs”). See Note 12 –Transactions with Affiliates for additional discussion of the MSAs and transactions with Citizen and Linn. The Company was formed to engage in the acquisition, exploration, development, production, and sale of oil and natural gas reserves. The Company’s oil and natural gas properties are located in Central Oklahoma. The Company’s corporate headquarters is located in Oklahoma City, Oklahoma. On October 1, 2019, the Company entered into an Agreement and Plan of Merger (the “Merger Agreement”) by and among Citizen Energy Operating, LLC, a Delaware limited liability company (“Citizen Operating”), Citizen Energy Pressburg, Inc., a Delaware corporation and wholly owned subsidiary of Citizen Operating (“Merger Sub”) and the Company. The Merger Agreement provides for, among other things, the merger of the Company into Merger Sub with the Company as the surviving entity and a wholly owned subsidiary of Citizen Operating (the “Merger”). See Note 15 – Subsequent Events for additional discussion of the merger transaction.

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Note 2 – Summary of Significant Accounting Policies For a description of the Company’s significant accounting policies, refer to Note 2 to the Company’s 2018 audited financial statements included in the Annual Report on Form 10-K. The accompanying condensed consolidated financial statements were prepared in conformity with accounting principles generally accepted in the United States of America (“GAAP”). Certain amounts in the prior period financial statements have been reclassified to conform to the 2019 presentation. These reclassifications had no impact on net income (loss), total stockholders’ equity or total cash flows. Principles of Consolidation The condensed consolidated financial statements of the Company include the accounts of Roan Inc. and its wholly owned subsidiaries. All material intercompany balances and transactions have been eliminated. Interim Financial Statements The accompanying condensed consolidated financial statements as of December 31, 2018 were derived from the annual financial statements included in the Annual Report on Form 10-K. The unaudited interim condensed consolidated financial statements for the three and nine months ended September 30, 2019 and 2018 were prepared by the Company in accordance with the accounting policies stated in the audited financial statements. In the opinion of management, the Company’s unaudited condensed consolidated financial statements reflect all known adjustments necessary to fairly state the financial position of the Company and its results of operations and cash flows for such periods. All such adjustments are of a normal, recurring nature. Certain information and disclosures normally included in financial statements prepared in conformity with GAAP have been consolidated or omitted, although the Company believes that the disclosures contained herein are adequate to make the information presented not misleading. These unaudited condensed consolidated financial statements should be read in conjunction with the Company’s annual financial statements and notes thereto. Use of Estimates The preparation of financial statements and related footnotes in conformity with GAAP requires that management formulate estimates and assumptions that affect revenues, expenses, assets, liabilities and the disclosure of contingent assets and liabilities. A significant item that requires management’s estimates and assumptions is the estimate of proved oil, natural gas and NGL reserves which are used in the calculation of depletion of the Company’s oil and natural gas properties and impairment, if any, of proved oil and natural gas properties. Changes in estimated quantities of its reserves could impact the Company’s reported financial results as well as disclosures regarding the quantities and value of proved oil and natural gas reserves. Although management believes these estimates are reasonable, actual results could differ from these estimates. Recent Accounting Standards Issued In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) (“ASC 842”). This update applies to any entity that enters into a lease, with some specified scope exemptions. Under this update, a lessee should recognize in the statement of financial position a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. While there were no major changes to the lessor accounting, changes were made to align key aspects with the revenue recognition guidance. The Company adopted the new standard using the simplified transition method described in ASU 2018-11 Leases (Topic 842): Targeted Improvements as of January 1, 2019 and did not retrospectively apply the new standard to periods before adoption. Accordingly, comparative information has not been adjusted and continues to be reported under the previous leasing standard. See Note 3 - Lease Accounting for additional information on the adoption of ASC 842.

Lease Accounting

Lease Accounting	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Lease Accounting	Note 3 - Lease Accounting The Company adopted ASC 842 on January 1, 2019 using the simplified transition method described in ASU 2018-11 Leases (Topic 842): Targeted Improvements . Accordingly, comparative information was not adjusted and will continue to be reported under the previous lease standard. The adoption did not require an adjustment to opening retained earnings for the cumulative effect adjustment. The Company further utilized the package of practical expedients within ASC 842 that allows an entity to not reassess the following prior to the effective date (i) whether any expired or existing contracts were or contained leases, (ii) the lease classification for any expired or existing leases or (iii) initial direct costs for any existing leases. The Company also elected the practical expedient under ASU 2018-01 Leases (Topic 842): Land Easement Practical Expedient for Transition to Topic 842 that allows it to not evaluate existing or expired land easements not previously accounted for as leases prior to the effective date. Finally, the Company has elected the short-term lease recognition exemption for all leases that qualify and the practical expedient to not separate lease and non-lease components for all asset classes with multiple component types. The Company enters into lease agreements to support its operations, such as office space, drilling rigs and field equipment. ASC 842 does not impact the accounting or financial presentation of the Company’s mineral leases and also does not apply to leases used in the exploration or use of oil and natural gas, including the rights to explore for those natural resources and rights to use the land in which those natural resources are contained. To facilitate compliance with ASC 842, the Company evaluated its existing lease arrangements and enhanced its systems, processes and internal controls to identify, track and record applicable leases. The implementation and adoption of this standard resulted in the Company recognizing right-of-use assets and lease liabilities for certain of its operating leases on the accompanying condensed consolidated balance sheet as of September 30, 2019 . The Company has no finance leases. The following table shows the impact of the adoption of ASC 842 on the Company’s current period balance sheet as compared to the previous lease accounting standard, ASC Topic 840, Leases (“ASC 840”): As of September 30, 2019 Under ASC 842 Under ASC 840 Increase/(decrease) (in thousands) Other noncurrent assets $ 5,312 $ — $ 5,312 Other current liabilities $ 1,892 $ — $ 1,892 Other noncurrent liabilities $ 4,444 $ 1,024 $ 3,420 Lease Accounting Policies The Company determines if an arrangement is a lease at the inception of the arrangement by (i) identifying any assets within the contract (ii) determining whether the Company has the right to obtain substantially all of the economic benefits from use of the asset throughout the period of use and (iii) if the Company has the right to direct how and for what purpose the identified asset is used throughout the period of use. To the extent that it is determined that an arrangement represents a lease, the lease is classified as an operating lease or a finance lease. The Company capitalizes both lease classifications on its consolidated balance sheets through a right-of-use (“ROU”) asset and a corresponding lease liability. ROU assets represent the Company’s right to use an underlying asset for the lease term, and lease liabilities represent the Company’s obligation to make lease payments arising from the lease. Operating leases are included in other noncurrent assets, other current liabilities, and other noncurrent liabilities in the consolidated balance sheets. Operating lease ROU assets and liabilities are recognized at the commencement date of an arrangement based on the present value of lease payments over the lease term. The operating lease ROU asset also includes any lease payments made to the lessor prior to lease commencement, less any lease incentives, and initial direct costs incurred. Lease expense for operating lease payments is recognized on a straight-line basis over the lease term. Certain of the Company’s lease agreements include lease and non-lease components. For all asset classes with multiple component types, the Company has utilized the practical expedient that exempts it from separating lease components from non-lease components. Accordingly, the Company accounts for the lease and non-lease components in an arrangement as a single lease component. In addition, for all asset classes, the Company has made an accounting policy election not to apply the lease recognition requirements to its short-term leases (that is, a lease that, at commencement, has a lease term of 12 months or less and does not include an option to purchase the underlying asset that the Company is reasonably certain to exercise). Accordingly, the Company recognizes lease payments related to its short-term leases in profit or loss on a straight-line basis over the lease term. To the extent that there are variable lease payments, the Company recognizes those payments in profit or loss in the period in which the obligation for those payments is incurred. Refer to “ Nature of Leases ” below for further information regarding those asset classes that include material short-term leases. Nature of Leases The Company leases certain office space, drilling rigs and field equipment under cancelable and non-cancelable leases to support our operations. Office Buildings. The Company leases its corporate office space in Oklahoma City, Oklahoma and additional office space for its field location in Oklahoma. In general, the Company’s office lease agreements contain provisions to extend the lease and contain protective provisions that allow for early termination. Beginning in March 2019, the Company began paying its portion of the building’s operating expenses, as defined in the corporate office lease agreement. These expenses are considered variable leases payments, which were not included in the measurement of the lease liability. The Company’s office building leases are long term leases reflected under ASC 842 on the accompanying condensed consolidated balance sheet as of September 30, 2019. Drilling Rigs. The Company enters into daywork contracts for drilling rigs with third party service contractors to support the development and exploitation of undeveloped reserves. All of the Company’s current drilling contracts have a term of one year or less. Field Equipment. The Company rents various field equipment, including compressors, from third parties in order to facilitate its operations. Compressor arrangements are typically structured with a non-cancelable primary term of twelve months and continue thereafter on a month-to-month basis subject to termination by either party with thirty days’ notice. The Company has concluded that its compressor rental agreements represent operating leases with a lease term that equals the primary non-cancelable contract term. Upon completion of the primary term, both parties have substantive rights to terminate the lease. As a result, enforceable rights and obligations do not exist under the rental agreement subsequent to the primary term. Other field equipment arrangements are typically structured on a month-to-month basis subject to termination by either party. To the extent that field equipment rental arrangements have a primary term of twelve months or less, the Company has elected to apply the practical expedient for short-term leases. For those short-term arrangements, the Company does not apply the lease recognition requirements, and recognizes lease payments related to these arrangements in profit or loss on a straight-line basis over the lease term. Refer to the “ Lease Accounting Policies ” section above for discussion of practical expedients applied. Discount Rate. The Company’s leases typically do not provide an implicit rate, and thus, it is required that the Company use its incremental borrowing rate in determining the present value of lease payments based on the information available at commencement date. The Company’s incremental borrowing rate reflects the rate of interest that it would pay to borrow on a collateralized basis over a similar term an amount equal to the lease payments in a similar economic environment. The Company uses the implicit rate in the limited circumstances in which that rate is readily determinable.

Revenue from Contracts with Cus

Revenue from Contracts with Customers	9 Months Ended
	Sep. 30, 2019
Revenue from Contract with Customer [Abstract]
Revenue from Contracts with Customers	Note 4 – Revenue from Contracts with Customers Revenues from the sale of oil, natural gas and NGLs are recognized when control of the product has been transferred to the customer, all performance obligations have been satisfied and collectability is reasonably assured. We recognize revenues from the sale of oil, natural gas and NGLs based on our share of volumes sold. Performance Obligations The Company satisfies the performance obligations under its oil and natural gas sales contracts through delivery of its production and transfer of control to a customer. Upon delivery of production, the Company has the right to receive consideration from its customers in amounts that correspond with the value of the production transferred. The Company typically receives payment for oil, natural gas and NGL sales within 30 days of the month of delivery for operated properties and within 90 days of the month of delivery for non-operated properties. The Company’s oil sales contracts are short-term in nature with a contract term of one year or less. For those contracts, the Company utilized the practical expedient in Revenue from Contracts with Customers (Topic 606) (“ASC 606”), which provides an exemption from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less. For the Company’s natural gas and NGL sales contracts that have a contract term greater than one year, the Company utilized the practical expedient in ASC 606 which states the Company is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under these sales contracts, each unit of product generally represents a separate performance obligation; therefore, future volumes are wholly unsatisfied, and disclosure of the transaction price allocated to remaining performance obligations is not required. Contract Balances The Company recognizes sales of oil, natural gas, and NGLs at a point in time when it satisfies a performance obligation and at that point the Company has an unconditional right to receive payment. Accordingly, these contracts do not give rise to contract assets or contract liabilities under ASC 606. The Company had accounts receivable related to revenue from contracts with customers as of September 30, 2019 and December 31, 2018 of approximately $44.3 million and $65.2 million , respectively, which represent this unconditional right to receive payment. Prior Period Performance Obligations To record revenues for oil, natural gas and NGLs, the Company estimates the amount of production delivered at the end of each month and the prices expected to be received for those sales. Differences between estimated revenues and actual amounts received for all prior months are recorded in the month payment is received from the customer. For the three and nine months ended September 30, 2019 and 2018 , revenue recognized related to performance obligations satisfied in prior reporting periods was not material.

Oil and Natural Gas Properties

Oil and Natural Gas Properties	9 Months Ended
	Sep. 30, 2019
Property, Plant and Equipment [Abstract]
Oil and Natural Gas Properties	Note 5 – Oil and Natural Gas Properties The Company’s oil and natural gas properties are in the continental United States. The oil and natural gas properties include the following: September 30, 2019 December 31, 2018 (in thousands) Oil and natural gas properties Proved $ 1,991,687 $ 1,538,379 Unproved 1,048,592 1,089,954 Less: accumulated depreciation, depletion, amortization and impairment (400,710 ) (230,836 ) Oil and natural gas properties, net $ 2,639,569 $ 2,397,497 The Company recorded amortization expense on its unproved oil and natural gas properties of $13.7 million and $11.2 million for the three months ended September 30, 2019 and 2018 , respectively, and $35.9 million and $25.6 million for the nine months ended September 30, 2019 and 2018 , respectively. Unproved leasehold amortization expense is reflected in exploration expense on the accompanying condensed consolidated statements of operations and reflects consideration of the Company’s drilling plans and the lease terms of its existing unproved properties. No impairment of proved oil and natural gas properties was recorded for the three and nine months ended September 30, 2019 or 2018 .

Asset Retirement Obligations

Asset Retirement Obligations	9 Months Ended
	Sep. 30, 2019
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations	Note 6 – Asset Retirement Obligations The following is a reconciliation of the changes in the Company’s asset retirement obligation (“ARO”) for the nine months ended September 30, 2019 (in thousands): Asset retirement obligation, December 31, 2018 $ 16,848 Liabilities incurred or acquired 1,024 Revisions in estimated cash flows — Liabilities settled (80 ) Accretion expense 869 Asset retirement obligation, September 30, 2019 18,661 Less: current portion of obligations (1) 774 Asset retirement obligation – long term $ 17,887 (1) The current portion of the ARO liability is included in other current liabilities on the condensed consolidated balance sheet.

Long-Term Debt

Long-Term Debt	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Long-Term Debt	Note 7 – Long-Term Debt Long-term debt consists of the following: September 30, 2019 December 31, 2018 (in thousands) Credit Facility $ 732,639 $ 514,639 Term Loan $ 50,000 $ — Unamortized original issue discount on Term Loan (1,022 ) — Repayment premium on Term Loan 97 — Deferred financing costs on Term Loan (3,480 ) — Term Loan, net $ 45,595 $ — Credit Facility In September 2017, the Company entered into a $750.0 million credit agreement with a maturity date of September 5, 2022 (as amended, the “Credit Facility”). Redetermination of the borrowing base of the Credit Facility generally occurs semiannually on or about October 1 and April 1. In October 2019, the Company entered into an amendment to its Credit Facility to postpone the October 2019 redetermination to January 2020 as well as to limit the Company’s borrowings under the Credit Facility to the lesser of (i) $732.6 million , (ii) the borrowing base, (iii) the maximum aggregate amount (as defined in the credit agreement), or (iv) the total commitments (as defined in the agreement) until the January 2020 redetermination is effective. As of September 30, 2019 , the Company had $732.6 million of outstanding borrowings and no letters of credit outstanding under the Credit Facility. The Credit Facility is secured by substantially all of the assets of Roan LLC. As discussed below, the Company entered into a Term Loan in June 2019 and used a majority of the proceeds from the initial borrowing to pay down $45.0 million of outstanding borrowings under the Credit Facility. The Company amended the Credit Facility in March 2019 to increase the borrowing base as well as to allow for (i) secured permitted additional debt of up to $250 million before any reduction in the borrowing base would occur and (ii) unsecured permitted additional debt of up to $400 million before any reduction in the borrowing base would occur. Effective June 2019, the Credit Facility was amended to (i) reaffirm the borrowing base at $750.0 million , (ii) temporarily reduce the current ratio to 0.85 to 1.00 at June 30, 2019 and to 0.80 to 1.00 at September 30, 2019, (iii) increase the rates in the utilization grid for London Interbank Offered Rate (“LIBOR”) and alternate base rate (“ABR”) loans by 0.25% until the Company delivers a compliance certificate demonstrating a current ratio of not less than 1.00 to 1.00, (iv) increase the mortgage coverage requirements from 85% to 95% ; and (v) restrict certain payments between Roan Inc. and Roan LLC in the event that Roan LLC transfers any of its oil and natural gas properties to Roan Inc. Amounts borrowed under the Credit Facility bear interest at LIBOR or the ABR at the Company’s election. The rate used for ABR loans is based on the higher of the prime rate, the federal funds effective rate plus 0.50% or the one-month LIBOR rate plus 1% . Either rate is adjusted upward by an applicable margin, based on the utilization percentage of the Credit Facility. Additionally, the Credit Facility provides for a commitment fee, which is payable at the end of each calendar quarter. The pricing grid below shows the applicable margin for LIBOR or ABR loans as well as the commitment fee depending on the Utilization Level (as defined in the credit agreement) for the Company during the nine months ended September 30, 2019 . Utilization Level Utilization LIBOR Margin ABR Margin Commitment Fee Level I <25% 2.00% 1.00% 0.375% Level II >25% but <50% 2.25% 1.25% 0.375% Level III >50% but <75% 2.50% 1.50% 0.500% Level IV >75% but <90% 2.75% 1.75% 0.500% Level V >90% 3.00% 2.00% 0.500% Due to the Company’s current ratio at September 30, 2019 being less than 1.00 to 1.00, the LIBOR margin and ABR margin will increase by 0.25% from the amounts noted in the table above for the fourth quarter of 2019. The Credit Facility contains representations, warranties, covenants, conditions and defaults customary for transactions of this type, including but not limited to: (i) limitations on liens and incurrence of debt covenants; (ii) limitations on the sale of property, mergers, consolidations and other similar transactions covenants; (iii) limitations on investments, loans and advances covenants; and (iv) limitations on dividends, distributions, redemptions and restricted payments covenants. Additionally, the Company is prohibited from hedging in excess of (a) 80% of reasonably anticipated projected production for the first thirty (30) month rolling period (based upon the Company’s internal projections) and (b) 80% of reasonably anticipated projected production from proved reserves for the second thirty (30) month rolling period of such sixty (60) month period (based on the most recently delivered reserve report). If the amount of borrowings outstanding exceed 50% of the borrowing base, the Company is required to hedge a minimum of 50% of the future production expected to be derived from proved developed reserves for the next eight quarters per its most recent reserve report. The Credit Facility also contains financial covenants requiring the Company to comply with a leverage ratio of the Company’s consolidated debt to consolidated EBITDAX (as defined in the credit agreement) for the period of four fiscal quarters then ended of not more than 4.00 to 1.00 and a current ratio of the Company’s consolidated current assets to consolidated current liabilities (as defined in the credit agreement to exclude non-cash assets and liabilities under ASC Topic 815 Derivatives and Hedging and ASC Topic 410 Asset Retirement and Environmental Obligations ) of not less than 0.80 to 1.00 for the quarter ended September 30, 2019 and not less than 1.00 to 1.00 for all quarters thereafter. As of September 30, 2019 , the Company was in compliance with the covenants under the Credit Facility and expects to remain in compliance for the next twelve months based on the current borrowing base. If the Company is not able to maintain compliance with the covenants under the Credit Facility in the future, it would be in default under the Credit Facility. A default, if not waived, could result in acceleration of the indebtedness outstanding under the Credit Facility and a default with respect to, and an acceleration of, the indebtedness outstanding under any other debt agreements, including the Term Loan. Term Loan In June 2019, Roan Inc. entered into a term loan facility (“Term Loan”) with initial commitments of $100.0 million and a potential incremental commitment of $50.0 million at the Company’s election. The lenders in the facility are funds affiliated with certain significant stockholders of Roan Inc. that are represented on the board of directors. The Term Loan matures in October 2020 and is secured by all of the assets of Roan Inc. Borrowings under the Term Loan bear interest at the three-month LIBOR rate plus 7.5% or ABR rate plus 6.5% , as elected by the Company. The ABR rate is the highest of the prime rate, the federal funds effective rate plus 0.50% and the one-month LIBOR rate plus 1% . The Company can elect, subject to certain conditions included in the Term Loan agreement, to pay the interest on the Term Loan in kind. Interest is payable semi-annually for LIBOR loans and quarterly for ABR loans. The borrowings under the Term Loan are issued at a discount of 2.5% . Additionally, in conjunction with the initial Term Loan commitment and any future incremental commitments, the Company is required to issue shares to the lenders equal to approximately 1% of the outstanding Class A common stock at the time of the commitment. As of September 30, 2019 , the Company had borrowed $50.0 million and received proceeds of $47.8 million , which were net of the issuance discount and certain issuance fees. These proceeds were primarily used to pay down amounts outstanding under the Credit Facility. As of September 30, 2019 , the outstanding borrowings under the Term Loan have an interest rate of 9.60% . The Company issued 1,525,395 shares of Class A common stock in June 2019 to the lenders of the Term Loan and received cash equal to the par value of the shares issued in return. The difference between the fair market value of the shares issued and the amount paid for such shares was considered a fee paid to the lenders and was included as deferred financing costs that will be amortized over the term of the Term Loan. The initial discount and all related financing costs are being amortized over the term of the Term Loan using the effective interest method. Under the Term Loan, any repayment of outstanding borrowings incurs a premium equal to 1% plus any interest that would have accrued on the repaid amount if it had been outstanding for a year; provided, that such additional interest is only due in the event of prepayment before the maturity date. This premium associated with the initial borrowing, or $0.5 million , is being amortized over the term of the Term Loan. In September 2019, the Company amended the Term Loan to permit the transfer of specified wellbore rights from Roan Inc. to Roan LLC. Additionally, the Company amended the Term Loan to specify that while the Merger Agreement, as defined in Note 15 – Subsequent Events , is effective no repayment premium would be due on any loans made after the amendment date and to specify that payment of interest in kind would not qualify as an additional loan under the Term Loan. The Term Loan contains customary negative covenants including, but not limited to, restrictions on the Company’s ability to incur additional indebtedness or create certain liens on assets, restrictions on selling of assets and restrictions on investments, dividends and other specified transactions. These covenants are subject to a number of important exceptions and qualifications. The Term Loan also contains certain affirmative covenants which, among other things, require the Company to maintain $10.0 million of liquidity, defined in the agreement as unrestricted cash plus the available borrowings under the Credit Facility and require periodic financial and reserve reporting. In addition, the Term Loan agreement contains financial covenants consistent with those required by the Credit Facility. As of September 30, 2019 , the Company was in compliance with the covenants under the Term Loan and expects to remain in compliance for the next twelve months. If the Company is not able to maintain compliance with the covenants under the Term Loan in the future, it would be in default under the Term Loan. A default, if not waived, could result in acceleration of the indebtedness outstanding under the Term Loan and a default with respect to, and an acceleration of, the indebtedness outstanding under any other debt agreements, including the Credit Facility.

Derivative Instruments

Derivative Instruments	9 Months Ended
	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative Instruments	Note 8 – Derivative Instruments The Company utilizes fixed price swaps and basis swaps to manage the price risk associated with the sale of its oil, natural gas and NGL production. Fixed price swaps are settled monthly based on differences between the fixed price specified in the contract and the referenced settlement price. Basis swaps are settled monthly based on differences between a fixed price differential and the applicable market price differential, the Panhandle Eastern Pipeline or Natural Gas Pipeline Company of America Mid Continent. When the referenced settlement price is less than the price specified in the contract, the Company receives an amount from the counterparty based on the price difference multiplied by the volume. Similarly, when the referenced settlement price exceeds the price specified in the contract, the Company pays the counterparty an amount based on the price difference multiplied by the volume. The following table reflects the Company’s open commodity contracts at September 30, 2019 : 2019 2020 2021 Total Oil fixed price swaps Volume (Bbl) 1,200,730 3,429,500 1,730,000 6,360,230 Weighted-average price $ 60.75 $ 60.57 $ 56.08 $ 59.38 Natural gas fixed price swaps Volume (MMBtu) 11,040,000 19,665,000 7,250,000 37,955,000 Weighted-average price $ 2.90 $ 2.63 $ 2.65 $ 2.71 Natural gas basis swaps Volume (MMBtu) 7,360,000 10,980,000 — 18,340,000 Weighted-average price $ 0.52 $ 0.49 $ — $ 0.50 Natural gas liquids fixed price swaps Volume (Bbl) 460,000 1,281,000 730,000 2,471,000 Weighted-average price $ 28.66 $ 23.22 $ 21.90 $ 23.84 The Company nets the fair value of derivative instruments by counterparty in the accompanying condensed consolidated balance sheets where the right to offset exists. See Note 9 – Fair Value Measurements for further information regarding the fair value measurement of the Company’s derivatives. As the Company has elected to not account for commodity derivative instruments as hedging instruments, gains or losses resulting from the change in fair value along with the gains or losses resulting from settlement of derivative contracts are reflected in gain (loss) on derivative contracts included in the accompanying condensed consolidated statements of operations. The following table presents the Company’s gain (loss) on derivative contracts and net cash received (paid) upon settlement of its derivative contracts for the three and nine months ended September 30, 2019 and 2018 : Three Months Ended Nine Months Ended 2019 2018 2019 2018 (in thousands) Gain (loss) on derivative contracts $ 40,675 $ (36,704 ) $ (5,913 ) $ (100,920 ) Net cash received (paid) upon settlement of derivative contracts (1) $ 16,541 $ (13,551 ) $ 29,284 $ (27,462 ) (1) Includes $0.4 million of cash received upon settlement of derivative contracts prior to their contractual maturity for the nine months ended September 30, 2018 . During 2018 and 2019, the Company modified certain existing derivative contracts to comply with hedging requirements under its Credit Facility. During the three and nine months ended September 30, 2019 , $5.2 million and $9.3 million , respectively, of net cash received upon settlement was related to such modified derivative contracts. The cash settlements for these derivatives are classified as cash flows from financing activities in the accompanying condensed consolidated statement of cash flows due to the other-than-insignificant financing element contained in the modified derivative contract. There were no settlements received or paid related to modified contracts during the three and nine months ended September 30, 2018 .

Fair Value Measurements

Fair Value Measurements	9 Months Ended
	Sep. 30, 2019
Fair Value Disclosures [Abstract]
Fair Value Measurements	Note 9 – Fair Value Measurements The Company measures and reports certain assets and liabilities on a fair value basis and has classified and disclosed its fair value measurements using the following levels of the fair value hierarchy: Level 1— Observable inputs that reflect unadjusted quoted prices for identical assets or liabilities in active markets as of the reporting date. Level 2— Observable market-based inputs or unobservable inputs that are corroborated by market data. These are inputs other than quoted prices in active markets included in Level 1 that are either directly or indirectly observable as of the reporting date. Level 3— Unobservable inputs that are not corroborated by market data and may be used with internally developed methodologies that result in management’s best estimate of fair value. Assets and liabilities that are measured at fair value are classified based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values, stated below, considers the market for the Company’s financial assets and liabilities, the associated credit risk and other factors. The Company considers active markets as those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis. The Company recognizes transfers between fair value hierarchy levels as of the end of the reporting period in which the event or change in circumstances causing the transfer occurred. During the three and nine months ended September 30, 2019 and 2018 , the Company did not have any transfers between Level 1, Level 2 or Level 3 fair value measurements. Assets and Liabilities Measured at Fair Value on a Recurring Basis The Company’s recurring fair value measurements are performed for its commodity derivatives. Please refer to Note 8 – Derivative Instruments for additional discussion. Commodity Derivative Instruments Commodity derivative contracts are stated at fair value in the accompanying condensed consolidated balance sheets. The Company adjusts the valuations from the valuation model for nonperformance risk and for counterparty risk. The fair values of the Company’s commodity derivative instruments are classified as Level 2 measurements as they are calculated using industry standard models using assumptions and inputs which are substantially observable in active markets throughout the full term of the instruments. These include market price curves, contract terms and prices, credit risk adjustments, implied market volatility and discount factors. The following table presents the amounts and classifications of the Company’s derivative assets and liabilities as of September 30, 2019 and December 31, 2018 , as well as the potential effect of netting arrangements on contracts with the same counterparty (in thousands): September 30, 2019 Level 1 Level 2 Level 3 Gross Fair Value Netting Carrying Value Assets Current commodity derivatives $ — $ 48,521 $ — $ 48,521 $ (681 ) $ 47,840 Noncurrent commodity derivatives — 19,189 — 19,189 (395 ) 18,794 Total assets $ — $ 67,710 $ — $ 67,710 $ (1,076 ) $ 66,634 Liabilities Current commodity derivatives $ — $ (681 ) $ — $ (681 ) $ 681 $ — Noncurrent commodity derivatives — (395 ) — (395 ) 395 — Total liabilities $ — $ (1,076 ) $ — $ (1,076 ) $ 1,076 $ — December 31, 2018 Level 1 Level 2 Level 3 Gross Fair Value Netting Carrying Value Assets Current commodity derivatives $ — $ 85,728 $ — $ 85,728 $ (3,548 ) $ 82,180 Noncurrent commodity derivatives — 21,565 — 21,565 (927 ) 20,638 Total assets $ — $ 107,293 $ — $ 107,293 $ (4,475 ) $ 102,818 Liabilities Current commodity derivatives $ — $ (4,393 ) $ — $ (4,393 ) $ 3,548 $ (845 ) Noncurrent commodity derivatives — (1,068 ) — (1,068 ) 927 (141 ) Total liabilities $ — $ (5,461 ) $ — $ (5,461 ) $ 4,475 $ (986 ) Non-Recurring Fair Value Measurements The Company’s non‑recurring fair value measurements include the determination of the grant date fair value of the Company’s performance share units. The grant date fair value of the Company’s performance share units is determined using a Monte Carlo simulation model and is classified as a Level 3 measurement. Please refer to Note 11 – Equity Compensation for additional discussion. Other Financial Instruments The Company’s financial instruments, not otherwise recorded at fair value, consist primarily of cash, trade receivables, trade payables, and long-term debt. The carrying values of cash and cash equivalents, accounts payable, revenue payable, and accounts receivable approximate fair values due to the short-term maturities of these instruments and the carrying value of long-term debt approximates fair value as the applicable interest rates are variable and reflective of market rates.

Equity

Equity	9 Months Ended
	Sep. 30, 2019
Equity [Abstract]
Equity	Note 10 – Equity In connection with the Term Loan commitment, the Company issued 1,525,395 shares of its Class A common stock to the lenders. See further discussion in Note 7 – Long-Term Debt . The lenders paid cash equal to the par value of the shares issued or $1,525 . The difference between the fair market value of the shares and the amount paid was considered a fee paid to the lenders that will be amortized over the term of the Term Loan. The fair market value of the shares was calculated as the closing price of the Company’s Class A common stock on the day before the subscription agreement was executed. When restricted stock units vest and are settled in the Company’s common stock, the Company makes the required statutory tax payments on behalf of the restricted stock unit holder and withholds from the vested award a number of shares of common stock with a value on the date of settlement equal to the tax obligation associated with such vested restricted stock units. In September 2019, the Company withheld 112,945 shares of Class A common stock for the payment of taxes due with an associated value of approximately $0.1 million . These shares were accounted for as treasury stock when withheld. Earnings per Share The Company uses the treasury stock method to determine the diluted weighted average shares. All performance share unit and restricted stock unit awards were deemed anti-dilutive for all periods presented in the accompanying condensed consolidated statements of operations and were therefore excluded from dilutive weighted average shares. See further discussion of the Company’s equity awards in Note 11 – Equity Compensation . Reorganization In September 2018 and in conjunction with the Reorganization, the Company issued 152.5 million shares of its Class A common stock to the members of Roan LLC in exchange for their equity interest in Roan LLC. The Reorganization was accounted for as a reverse recapitalization with Roan Inc. as the accounting acquirer and therefore did not result in any change in the accounting basis for the underlying assets. Net income before taxes and equity-based compensation were allocated ratably to the members of Roan LLC and the stockholders of Roan Inc. for the period before and after the Reorganization, respectively. For comparative purposes, the issuance of the shares to the members of Roan LLC at the time of the Reorganization was reflected on a retroactive basis with the units outstanding during each period presented. Roan LLC Equity For the period of September 1, 2017 through the date of the Reorganization, Roan LLC was governed by the Amended and Restated Limited Liability Company Agreement of Roan Resources LLC. In connection with the Contribution in August 2017, Roan LLC issued 1.5 billion membership units representing capital interests in Roan LLC (the “LLC Units”) for a 50% equity interest in Roan LLC, to Linn in exchange for the contribution of oil and natural gas properties. Additionally, Roan LLC issued 1.5 billion LLC Units, which represented a 50% equity interest, to Citizen in exchange for the contribution of oil and natural gas properties. The fair value of the LLC Units issued to Citizen was the same as that of the LLC Units issued to Linn. In March 2018, Roan LLC issued 19.2 million LLC Units to each Citizen and Linn to settle amounts due for the leasehold acreage acquired on Roan LLC’s behalf during 2017.

Equity Compensation

Equity Compensation	9 Months Ended
	Sep. 30, 2019
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Equity Compensation	Note 11 – Equity Compensation In connection with the Reorganization, the Company adopted the Roan Resources, Inc. Amended and Restated Management Incentive Plan (the “Plan”), which provides for grants of options, stock appreciation rights, restricted stock unit, stock awards, dividend equivalents, other stock-based awards, cash awards and substitute awards. Performance Share Units Prior to the Reorganization, Roan LLC granted performance share units to certain of its employees under the Roan LLC Management Incentive Plan. The performance share units were converted into awards of performance share units under the Plan, hereafter referred to as the “Roan LLC PSUs,” and are subject to the terms of the Plan and individual award agreements. The amount of Roan LLC PSUs that can be earned range from 0% to 200% based on the Company’s market value on December 31, 2020 (“Performance Period End Date”). The Company’s market value on the Performance Period End Date will be determined by reference to the volume-weighted average price of the Company’s Class A common stock for the 30 consecutive trading days immediately preceding the Performance Period End Date. Each earned Roan LLC PSU will be settled through the issuance of one share of the Company’s Class A common stock. Other than the security in which the Roan LLC PSUs are settled, no terms of the Roan LLC PSUs were modified in connection with the conversion of the Roan LLC PSUs. The following table presents activity for the Roan LLC PSUs during the nine months ended September 30, 2019 : Number of Weighted Total Fair Outstanding at December 31, 2018 1,158,750 $ 30.95 $ 35,864 Granted — — — Vested — — — Forfeited (518,750 ) 29.71 (15,411 ) Outstanding at September 30, 2019 640,000 $ 31.96 $ 20,453 During the nine months ended September 30, 2019 , the Company granted performance share units (“Roan Inc PSUs”) to certain of its employees under the Plan. The amount of Roan Inc PSUs that can be earned range from 0% to 100% based on the 60 -day volume weighted average price of the Company’s Class A common stock for any 60 consecutive trading days during the specified performance period beginning on the date of grant. There were no such grants during 2018. The following table presents activity for the Roan Inc PSUs during the nine months ended September 30, 2019 : Number of Weighted Total Fair Outstanding at December 31, 2018 — $ — $ — Granted 2,716,636 1.58 4,301 Vested — — — Forfeited (190,735 ) 2.55 (486 ) Outstanding at September 30, 2019 2,525,901 $ 1.51 $ 3,815 Compensation expense associated with the Roan LLC PSUs and Roan Inc PSUs for the three months ended September 30, 2019 and 2018 was $1.5 million and $2.9 million , respectively, and for the nine months ended September 30, 2019 and 2018 was $0.8 million and $8.1 million , respectively. During 2019, forfeitures of Roan LLC PSUs and Roan Inc PSUs resulted in the reversal of compensation expense of $6.5 million . Compensation expense is included in general and administrative expenses on the accompanying condensed consolidated statements of operations. Unrecognized expense as of September 30, 2019 for the outstanding Roan LLC PSUs and the outstanding Roan Inc PSUs was $12.1 million , which will be recognized over a weighted-average remaining period of 2.21 years. The grant date fair value of both the Roan LLC PSUs and the Roan Inc PSUs was determined using a Monte Carlo simulation model, which results in an estimated percentage of performance share units earned and estimated Company value at the end of the performance period. The grant date fair value of the Roan LLC PSUs and the Roan Inc PSUs is expensed on a straight-line basis from the grant date to the end of the performance period. The following assumptions were used for the Monte Carlo simulation model to determine the grant date fair value and associated compensation expense for the Roan Inc PSU awards granted in 2019: Equity volatility 65.00 % Weighted average risk-free interest rate 2.25 % Restricted Stock Units Under the Plan, the Company is authorized to issue restricted stock units, hereafter referred to as the “RSUs,” to eligible employees and other service providers. The Company estimates the fair values of RSUs as of the closing price of the Company’s Class A common stock on the grant date of the award, which is expensed over the applicable vesting period. The following table presents activity for the Company’s RSUs during the nine months ended September 30, 2019 : Number of Weighted Total Fair Outstanding at December 31, 2018 11,800 $ 16.95 $ 200 Granted 1,676,325 3.86 6,476 Vested (381,764 ) 4.65 (1,775 ) Forfeited (187,235 ) 4.60 (861 ) Outstanding at September 30, 2019 1,119,126 $ 3.61 $ 4,040 Compensation expense associated with the RSUs for three and nine months ended September 30, 2019 was $1.5 million and $2.1 million , respectively, and is included in general and administrative expenses on the accompanying condensed consolidated statements of operations. There were no RSUs issued prior to the Reorganization in 2018. Unrecognized expense as of September 30, 2019 for all outstanding RSUs was $3.7 million , which will be recognized over a weighted-average remaining period of 1.61 years.

Transactions with Affiliates

Transactions with Affiliates	9 Months Ended
	Sep. 30, 2019
Related Party Transactions [Abstract]
Transactions with Affiliates	Note 12 –Transactions with Affiliates Natural Gas Dedication Agreement The Company has a gas dedication agreement with Blue Mountain Midstream LLC (“Blue Mountain”), a subsidiary of Riviera Resources, Inc. (“Riviera”), which has directors and shareholders in common with the Company. Amounts due from Blue Mountain at September 30, 2019 and December 31, 2018 are reflected as Accounts receivable – Affiliates in the accompanying condensed consolidated balance sheets and represent accrued revenue for the Company’s portion of the production sold to Blue Mountain. Sales to Blue Mountain are reflected as Natural gas sales – Affiliates and Natural gas liquids sales – Affiliates in the accompanying condensed consolidated statements of operations. See further discussion of this gas dedication agreement in Note 14 – Commitments and Contingencies . Water Management Services Agreement In January 2019, the Company entered into a water management services agreement with a subsidiary of Blue Mountain, Wildcat Water Gathering LLC (“Wildcat Water”). Under this agreement, Wildcat Water will provide water management services including pipeline gathering, disposal, treatment and redelivery of recycled water. The agreement provides for an acreage dedication for water management services through January 2029. Wildcat Water began providing services under this agreement in April 2019. During the three and nine months ended September 30, 2019 , the Company incurred costs of $8.7 million and $17.2 million , respectively, related to these services as operator of the related wells. For the three months ended September 30, 2019 , the Company’s portion of these costs totaled $7.4 million , of which $5.4 million was included in production expenses in the accompanying condensed consolidated statements of operations and $2.0 million was capitalized in oil and natural gas properties on the accompanying condensed consolidated balance sheets. For the nine months ended September 30, 2019 , the Company’s portion of these costs totaled $13.8 million , of which $10.0 million was included in production expenses in the accompanying condensed consolidated statements of operations and $3.8 million was capitalized in oil and natural gas properties on the accompanying condensed consolidated balance sheets. The remainder of the costs are billed out to third-party interest owners for their share of such costs. Amounts payable and accrued under this agreement at September 30, 2019 of $6.5 million are included in accounts payable and accrued liabilities - Affiliates on the accompanying condensed consolidated balance sheets. Oil Gathering Agreement In July 2019, the Company entered into an oil gathering agreement with a subsidiary of Blue Mountain, Wildcat Oil Gathering LLC (“Wildcat Oil”). This agreement provides for dedication of certain of the Company’s acreage for oil gathering services for a term of ten years . Wildcat Oil is expected to begin providing services under this agreement in the fourth quarter of 2019 or early 2020. Corporate Office Lease During 2018, the Company entered into a lease for office space in Oklahoma City, Oklahoma that is owned by a subsidiary of Riviera under a lease with an initial term of 5 years with an option to extend the lease for an additional 5 years at the end of the initial term. The Company paid $0.4 million and $1.1 million during the three and nine months ended September 30, 2019 , respectively, under this lease. During the three and nine months ended September 30, 2018 , the Company paid $0.2 million and $0.3 million , respectively. Total remaining payments under the lease are $6.7 million , excluding the Company’s portion of the operating expenses of the building. Tax Matters Agreement In conjunction with the Reorganization, the Company entered into a tax matters agreement (“TMA”) with Riviera. See Note 13 – Income Taxes for further discussion of the TMA. As a result of the TMA and the refund of an overpayment of estimated federal taxes by Linn Energy, Inc. related to the Riviera business that was received by the Company in November 2018, the Company paid $7.6 million to Riviera during the nine months ended September 30, 2019 . Term Loan In June 2019, the Company entered into the Term Loan agreement with lenders affiliated with certain stockholders of the Company that are represented on the board of directors. See further discussion in Note 7 – Long-Term Debt . Interest expense related to the Term Loan agreement for the three and nine months ended September 30, 2019 was $2.3 million , including amortization of the discount of $0.3 million and deferred financing costs related to the Term Loan of $0.7 million and excluding any interest capitalized, and is included in interest expense - Affiliates on the accompanying condensed consolidated statements of operations. Accrued interest due on the Term Loan of $1.3 million at September 30, 2019 is included in accounts payable and accrued liabilities - Affiliates on the accompanying condensed consolidated balance sheets. Management Service Agreements Under the MSAs, Citizen and Linn provided certain services in respect to the oil and natural gas properties they contributed to Roan LLC. Such services included serving as operator of the oil and natural gas properties contributed, land administration, marketing, information technology and accounting services. As a result of Citizen and Linn continuing to serve as operator of the contributed assets and contracting directly with vendors for goods and services for operations, Citizen and Linn collected amounts due from joint interest owners for their share of costs and billed Roan LLC for its share of costs. The services provided under the MSAs ended in April 2018 when Roan LLC took over as operator for the oil and natural gas properties contributed by Citizen and Linn. In conjunction with the conclusion of the MSAs in April 2018, Roan LLC assumed certain working capital accounts associated with the properties contributed from Citizen and Linn. During the nine months ended September 30, 2018 , Roan LLC incurred approximately $10.0 million for charges related to the services provided under the MSAs, which were recorded in general and administrative expenses in the condensed consolidated statements of operations. As the MSAs ended in April 2018, there were no such charges related to the MSAs in 2019 or the three months ended September 30, 2018 . Acquisition of Acreage As provided for in the Contribution Agreement, Citizen and Linn acquired additional acreage totaling $63.0 million as of December 31, 2017 within an area of mutual interest on behalf of the Company. See Note 10 – Equity for further discussion of the settlement of the payable due to Citizen and Linn related to the additional acquired acreage.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2019
Income Tax Disclosure [Abstract]
Income Taxes	Note 13 – Income Taxes As discussed in Note 1 – Business and Organization , Roan Inc. was formed in September 2018 in connection with the Reorganization. Roan Inc.’s accounting predecessor, Roan LLC, was treated as a flow-through entity for income tax purposes. As a result, the net taxable income or loss of Roan LLC and any related tax credits, for income tax purposes, flowed through to its members. Accordingly, no tax provision was made in the historical financial statements of Roan LLC since the income tax was an obligation of its members. Roan Inc. is a corporation and subject to U.S. federal and state income tax. The Company records its quarterly tax provision based on an estimate of the annual effective tax rate expected to apply to continuing operations for the various jurisdictions in which it operates. The Company’s effective combined U.S. federal and state income tax rate for the three and nine months ended September 30, 2019 was 23.4% and 23.8% , respectively, based on estimated net income for the year. The Company’s effective tax rate for three and nine months ended September 30, 2019 approximates the Company’s estimated annual effective tax rate which includes the federal and state income tax. The tax effects of certain items, such as tax rate changes, significant unusual or infrequent items, and certain changes in the assessment of the realizability of deferred taxes, are recognized as discrete items in the period in which they occur and are excluded from the estimated annual effective tax rate. In conjunction with the Reorganization, the Company entered into the TMA with Riviera. The TMA, in part, provides for the indemnification of the Company and the entitlement of Riviera to refunds related to certain taxes of Linn Energy, Inc. prior to the spinoff of Riviera from Linn Energy, Inc.

Commitments and Contingencies

Commitments and Contingencies	9 Months Ended
	Sep. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Commitments and Contingencies	Note 14 – Commitments and Contingencies Lease Commitments As discussed in Note 3 - Lease Accounting , the Company leases certain office buildings, drilling rigs, and field equipment under cancelable and non-cancelable leases to support our operations. The Company’s lease costs for the three and nine months ended September 30, 2019 included operating lease costs of $0.6 million and $1.6 million , respectively, and short-term lease costs of $9.7 million and $56.8 million , respectively. Short-term lease costs exclude leases with a contract term of one month or less. Included in short-term lease costs is $8.4 million and $53.1 million , respectively, of gross costs related to the Company’s drilling rig leases. The Company’s portion of the drilling rig costs are capitalized to oil and natural gas properties and the remainder is billed out to third-party interest owners for their share of such costs. Payments made for operating leases included in lease liabilities for the three and nine months ended September 30, 2019 were $0.5 million and $1.2 million , respectively. The Company’s condensed consolidated balance sheet as of September 30, 2019 included lease assets and liabilities as follows (in thousands): Operating Leases Operating lease right of use assets $ 5,312 Current operating lease liabilities $ 1,892 Noncurrent operating lease liabilities 4,444 Total operating lease liabilities $ 6,336 The weighted average remaining lease term for our operating leases is 3.5 years and the weighted average discount rate is 8.5% . The Company’s operating lease liabilities as of September 30, 2019 with enforceable contract terms that are greater than one year mature as follows (in thousands): 2019 $ 478 2020 1,986 2021 2,073 2022 2,163 2023 445 Thereafter 171 Total lease payments 7,316 Less imputed interest (980 ) Total $ 6,336 The Company’s future lease payments under ASC 840 as of December 31, 2018 were not materially different than those presented above. Litigation The Company is party to lawsuits arising in the ordinary course of business, including, but not limited to, commercial disputes, personal injury claims, royalty claims, property damage claims and contract actions. The Company cannot predict the outcome of any such lawsuits with certainty, but management does not currently believe that any pending or threatened legal matters will have a material adverse impact on the Company’s financial condition. Due to the nature of its business, the Company is, from time to time, involved in other routine litigation or subject to disputes or claims related to its business activities, including workers’ compensation claims and employment related disputes. In the opinion of management, none of these other pending litigation disputes or claims against the Company, if decided adversely, will have a material adverse effect on the Company’s financial condition, cash flows or results of operations. Environmental Matters The Company is subject to various federal, state and local laws and regulations relating to the protection of the environment. These laws, which are often changing, regulate the discharge of materials into the environment and may require the Company to remove or mitigate the environmental effects of the disposal or release of petroleum or chemical substances at various sites. The Company has established procedures for the ongoing evaluation of its operations to identify potential environmental exposures and to comply with regulatory policies and procedures. At September 30, 2019 , the Company had no environmental matters requiring specific disclosure or requiring the recognition of a liability. Natural Gas Dedication Agreements The Company has dedicated its natural gas production from the oil and natural gas properties contributed by Citizen under an agreement with a third party. Under this dedication agreement, the Company is required to deliver its natural gas production from the contract area, as defined in the agreement, through November 2030. There is no specified volume or volume penalty in the agreement. For the oil and natural gas properties contributed by Linn, the Company assumed Linn’s dedication agreement with Blue Mountain. The agreement with Blue Mountain requires the Company to deliver its natural gas production from the contract area, as defined in the agreement, through November 2030. There is no specified volume or volume penalty in the agreement. Volume Commitment Under an agreement with a third party, the Company has a requirement to deliver a minimum volume of natural gas from a specified area, as defined in the agreement. In the event that the Company is unable to meet this natural gas volume delivery commitment, it would incur deficiency fees on any undelivered volumes as of November 2021. Based on expected production from currently producing wells in the specified area, the Company anticipates that it may not deliver the required minimum volume of natural gas by November 2021. As a result, the Company has accrued $1.0 million for its share of the estimated shortfall deficiency fees as of September 30, 2019 . The accrued liability is included in other noncurrent liabilities in the accompanying condensed consolidated balance sheet. If the Company is unable to deliver any natural gas volumes subsequent to September 30, 2019 through November 2021, total shortfall deficiency fees of $6.4 million would be due at the end of the commitment period.

Subsequent Events

Subsequent Events	9 Months Ended
	Sep. 30, 2019
Subsequent Events [Abstract]
Subsequent Events	Merger Agreement On October 1, 2019, the Company entered into the Merger Agreement by and among Citizen Operating, the Merger Sub, a wholly owned subsidiary of Citizen Operating, and the Company. The Merger Agreement provides for, among other things, the merger of the Company into Merger Sub with the Company as the surviving entity and a wholly owned subsidiary of Citizen Operating (the “Merger”). As consideration for the Merger, Citizen Operating will purchase all outstanding Class A common stock of the Company, as described in the Merger Agreement, for cash consideration of $1.52 per share. This would exclude shares that are held in treasury by the Company or owned by its wholly owned subsidiaries, shares owned by Citizen Operating or any of its wholly owned subsidiaries and shares held by stockholders who do not vote in favor of or consent to the adoption of the Merger Agreement and who properly demand appraisal of such shares and complied in all respects with all the provisions of the Delaware General Corporation Law concerning the right of holders of shares to require appraisal. Conditions to Close and Covenants The Merger Agreement includes specified closing conditions that must be met or waived. These conditions include, but are not limited to, (i) the stockholders of the Company voting in favor of adopting the Merger Agreement, (ii) the expiration or termination of applicable waiting periods under applicable antitrust laws, (iii) the absence of any law, order, judgment or injunction by any governmental entity restraining, prohibiting or rendering the consummation of the Merger illegal, (iv) the Test Indebtedness of the Company, as defined in the Merger Agreement, being less than or equal to $760.0 million and (v) certain other customary closing conditions. The Merger Agreement also includes customary representations, warranties and covenants of the Company, Citizen Operating and Merger Sub. These include a covenant by the Company to enter into additional natural gas liquid, natural gas and oil hedging arrangements. See Commodity Contracts below for discussion of the additional derivative contracts entered into by the Company in October 2019. Termination Fees Either the Company or Citizen Operating may terminate the Merger Agreement if the Merger is not consummated by March 17, 2020. The Merger Agreement includes specifications regarding fees to be paid by either party should the agreement be terminated prior to March 17, 2020. The Company’s board of directors may terminate the Merger Agreement to enter into a superior proposal upon satisfaction of certain conditions, as specified in the Merger Agreement, and upon payment of a termination fee of $25.0 million . If Citizen Operating terminates the Merger Agreement, under certain circumstances as specified in the Merger Agreement, Citizen Operating would be obligated to pay a termination fee of $35.0 million . The Merger Agreement also contains a provision that would require Citizen Operating to pay for the cost (subject to a cap of $15.0 million ) to unwind certain hedging arrangements if the transaction is terminated due to Citizen Operating’s breach or failure to obtain financing and the $35.0 million termination fee is insufficient to cover the unwind costs. Commodity Contracts Per the covenants of the Merger Agreement, the Company was required to enter into additional commodity contracts. The following table presents the additional derivative contracts entered into in October 2019: 2019 2020 2021 2022 2023 2024 Oil fixed price swaps Volume (Bbl) — — — 1,261,500 1,047,000 686,500 Weighted-average price $ — $ — $ — $ 50.00 $ 50.00 $ 50.00 Natural gas fixed price swaps Volume (MMBtu) — 9,845,000 15,370,000 — — — Weighted-average price $ — $ 2.39 $ 2.39 $ — $ — $ — Natural gas basis swaps Volume (MMBtu) — 18,580,000 22,610,000 — — — Weighted-average price $ — $ 0.45 $ 0.38 $ — $ — $ — Natural gas liquids fixed price swaps Volume (Bbl) 456,500 1,574,400 1,441,100 — — — Weighted-average price $ 22.62 $ 19.09 $ 18.91 $ — $ — $ — Credit Facility Amendment In October 2019, the Company entered into an amendment to its Credit Facility to postpone the October 2019 redetermination to January 2020 as well as to limit the Company’s borrowings to the lesser of (i) $732.6 million (ii) the borrowing base, (iii) the maximum aggregate amount (as defined in the credit agreement), or (iv) the total commitments (as defined in the agreement) until the January 2020 redetermination is complete. See Note 7 – Long-Term Debt for further discussion of the Credit Facility.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2019
Accounting Policies [Abstract]
Principles of Consolidation	Principles of Consolidation The condensed consolidated financial statements of the Company include the accounts of Roan Inc. and its wholly owned subsidiaries. All material intercompany balances and transactions have been eliminated.
Interim Financial Statements	Interim Financial Statements The accompanying condensed consolidated financial statements as of December 31, 2018 were derived from the annual financial statements included in the Annual Report on Form 10-K. The unaudited interim condensed consolidated financial statements for the three and nine months ended September 30, 2019 and 2018 were prepared by the Company in accordance with the accounting policies stated in the audited financial statements. In the opinion of management, the Company’s unaudited condensed consolidated financial statements reflect all known adjustments necessary to fairly state the financial position of the Company and its results of operations and cash flows for such periods. All such adjustments are of a normal, recurring nature. Certain information and disclosures normally included in financial statements prepared in conformity with GAAP have been consolidated or omitted, although the Company believes that the disclosures contained herein are adequate to make the information presented not misleading. These unaudited condensed consolidated financial statements should be read in conjunction with the Company’s annual financial statements and notes thereto.
Use of Estimates	Use of Estimates The preparation of financial statements and related footnotes in conformity with GAAP requires that management formulate estimates and assumptions that affect revenues, expenses, assets, liabilities and the disclosure of contingent assets and liabilities. A significant item that requires management’s estimates and assumptions is the estimate of proved oil, natural gas and NGL reserves which are used in the calculation of depletion of the Company’s oil and natural gas properties and impairment, if any, of proved oil and natural gas properties. Changes in estimated quantities of its reserves could impact the Company’s reported financial results as well as disclosures regarding the quantities and value of proved oil and natural gas reserves. Although management believes these estimates are reasonable, actual results could differ from these estimates.
Recent Accounting Standards Issued	Recent Accounting Standards Issued In February 2016, the FASB issued ASU 2016-02, Leases (Topic 842) (“ASC 842”). This update applies to any entity that enters into a lease, with some specified scope exemptions. Under this update, a lessee should recognize in the statement of financial position a liability to make lease payments (the lease liability) and a right-of-use asset representing its right to use the underlying asset for the lease term. While there were no major changes to the lessor accounting, changes were made to align key aspects with the revenue recognition guidance. The Company adopted the new standard using the simplified transition method described in ASU 2018-11 Leases (Topic 842): Targeted Improvements as of January 1, 2019 and did not retrospectively apply the new standard to periods before adoption. Accordingly, comparative information has not been adjusted and continues to be reported under the previous leasing standard. See Note 3 - Lease Accounting for additional information on the adoption of ASC 842.
Revenue from Contracts with Customers	Revenues from the sale of oil, natural gas and NGLs are recognized when control of the product has been transferred to the customer, all performance obligations have been satisfied and collectability is reasonably assured. We recognize revenues from the sale of oil, natural gas and NGLs based on our share of volumes sold. Performance Obligations The Company satisfies the performance obligations under its oil and natural gas sales contracts through delivery of its production and transfer of control to a customer. Upon delivery of production, the Company has the right to receive consideration from its customers in amounts that correspond with the value of the production transferred. The Company typically receives payment for oil, natural gas and NGL sales within 30 days of the month of delivery for operated properties and within 90 days of the month of delivery for non-operated properties. The Company’s oil sales contracts are short-term in nature with a contract term of one year or less. For those contracts, the Company utilized the practical expedient in Revenue from Contracts with Customers (Topic 606) (“ASC 606”), which provides an exemption from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less. For the Company’s natural gas and NGL sales contracts that have a contract term greater than one year, the Company utilized the practical expedient in ASC 606 which states the Company is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under these sales contracts, each unit of product generally represents a separate performance obligation; therefore, future volumes are wholly unsatisfied, and disclosure of the transaction price allocated to remaining performance obligations is not required. Contract Balances The Company recognizes sales of oil, natural gas, and NGLs at a point in time when it satisfies a performance obligation and at that point the Company has an unconditional right to receive payment. Accordingly, these contracts do not give rise to contract assets or contract liabilities under ASC 606. The Company had accounts receivable related to revenue from contracts with customers as of September 30, 2019 and December 31, 2018 of approximately $44.3 million and $65.2 million , respectively, which represent this unconditional right to receive payment. Prior Period Performance Obligations To record revenues for oil, natural gas and NGLs, the Company estimates the amount of production delivered at the end of each month and the prices expected to be received for those sales. Differences between estimated revenues and actual amounts received for all prior months are recorded in the month payment is received from the customer. For the three and nine months ended September 30, 2019 and 2018 , revenue recognized related to performance obligations satisfied in prior reporting periods was not material.
Fair Value Measurements	The Company measures and reports certain assets and liabilities on a fair value basis and has classified and disclosed its fair value measurements using the following levels of the fair value hierarchy: Level 1— Observable inputs that reflect unadjusted quoted prices for identical assets or liabilities in active markets as of the reporting date. Level 2— Observable market-based inputs or unobservable inputs that are corroborated by market data. These are inputs other than quoted prices in active markets included in Level 1 that are either directly or indirectly observable as of the reporting date. Level 3— Unobservable inputs that are not corroborated by market data and may be used with internally developed methodologies that result in management’s best estimate of fair value. Assets and liabilities that are measured at fair value are classified based on the lowest level of input that is significant to the fair value measurement. The Company’s assessment of the significance of a particular input to the fair value measurement requires judgment, which may affect the valuation of the fair value of assets and liabilities and their placement within the fair value hierarchy levels. The determination of the fair values, stated below, considers the market for the Company’s financial assets and liabilities, the associated credit risk and other factors. The Company considers active markets as those in which transactions for the assets or liabilities occur in sufficient frequency and volume to provide pricing information on an ongoing basis. The Company recognizes transfers between fair value hierarchy levels as of the end of the reporting period in which the event or change in circumstances causing the transfer occurred.

Lease Accounting (Tables)

Lease Accounting (Tables)	9 Months Ended
	Sep. 30, 2019
Leases [Abstract]
Impact of Adoption of ASC 842	The following table shows the impact of the adoption of ASC 842 on the Company’s current period balance sheet as compared to the previous lease accounting standard, ASC Topic 840, Leases (“ASC 840”): As of September 30, 2019 Under ASC 842 Under ASC 840 Increase/(decrease) (in thousands) Other noncurrent assets $ 5,312 $ — $ 5,312 Other current liabilities $ 1,892 $ — $ 1,892 Other noncurrent liabilities $ 4,444 $ 1,024 $ 3,420

Oil and Natural Gas Properties

Oil and Natural Gas Properties (Tables)	9 Months Ended
	Sep. 30, 2019
Property, Plant and Equipment [Abstract]
Capitalized Costs Relating to Oil, Natural Gas and NGL Producing Activities	The oil and natural gas properties include the following: September 30, 2019 December 31, 2018 (in thousands) Oil and natural gas properties Proved $ 1,991,687 $ 1,538,379 Unproved 1,048,592 1,089,954 Less: accumulated depreciation, depletion, amortization and impairment (400,710 ) (230,836 ) Oil and natural gas properties, net $ 2,639,569 $ 2,397,497

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	9 Months Ended
	Sep. 30, 2019
Asset Retirement Obligation Disclosure [Abstract]
Schedule of Reconciliation of Asset Retirement Obligations	The following is a reconciliation of the changes in the Company’s asset retirement obligation (“ARO”) for the nine months ended September 30, 2019 (in thousands): Asset retirement obligation, December 31, 2018 $ 16,848 Liabilities incurred or acquired 1,024 Revisions in estimated cash flows — Liabilities settled (80 ) Accretion expense 869 Asset retirement obligation, September 30, 2019 18,661 Less: current portion of obligations (1) 774 Asset retirement obligation – long term $ 17,887 (1) The current portion of the ARO liability is included in other current liabilities on the condensed consolidated balance sheet.

Long-Term Debt (Tables)

Long-Term Debt (Tables)	9 Months Ended
	Sep. 30, 2019
Debt Disclosure [Abstract]
Schedule of Long-term Debt	Long-term debt consists of the following: September 30, 2019 December 31, 2018 (in thousands) Credit Facility $ 732,639 $ 514,639 Term Loan $ 50,000 $ — Unamortized original issue discount on Term Loan (1,022 ) — Repayment premium on Term Loan 97 — Deferred financing costs on Term Loan (3,480 ) — Term Loan, net $ 45,595 $ —
Schedule of Applicable Margin for LIBOR Rate Loans Depending on the Utilization Level	The pricing grid below shows the applicable margin for LIBOR or ABR loans as well as the commitment fee depending on the Utilization Level (as defined in the credit agreement) for the Company during the nine months ended September 30, 2019 . Utilization Level Utilization LIBOR Margin ABR Margin Commitment Fee Level I <25% 2.00% 1.00% 0.375% Level II >25% but <50% 2.25% 1.25% 0.375% Level III >50% but <75% 2.50% 1.50% 0.500% Level IV >75% but <90% 2.75% 1.75% 0.500% Level V >90% 3.00% 2.00% 0.500%

Derivative Instruments (Tables)

Derivative Instruments (Tables)	9 Months Ended
	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Schedule of Company's Open Commodity Contracts	The following table reflects the Company’s open commodity contracts at September 30, 2019 : 2019 2020 2021 Total Oil fixed price swaps Volume (Bbl) 1,200,730 3,429,500 1,730,000 6,360,230 Weighted-average price $ 60.75 $ 60.57 $ 56.08 $ 59.38 Natural gas fixed price swaps Volume (MMBtu) 11,040,000 19,665,000 7,250,000 37,955,000 Weighted-average price $ 2.90 $ 2.63 $ 2.65 $ 2.71 Natural gas basis swaps Volume (MMBtu) 7,360,000 10,980,000 — 18,340,000 Weighted-average price $ 0.52 $ 0.49 $ — $ 0.50 Natural gas liquids fixed price swaps Volume (Bbl) 460,000 1,281,000 730,000 2,471,000 Weighted-average price $ 28.66 $ 23.22 $ 21.90 $ 23.84
Schedule of Net Gains and Loss on Derivative Contracts	The following table presents the Company’s gain (loss) on derivative contracts and net cash received (paid) upon settlement of its derivative contracts for the three and nine months ended September 30, 2019 and 2018 : Three Months Ended Nine Months Ended 2019 2018 2019 2018 (in thousands) Gain (loss) on derivative contracts $ 40,675 $ (36,704 ) $ (5,913 ) $ (100,920 ) Net cash received (paid) upon settlement of derivative contracts (1) $ 16,541 $ (13,551 ) $ 29,284 $ (27,462 ) (1) Includes $0.4 million of cash received upon settlement of derivative contracts prior to their contractual maturity for the nine months ended September 30, 2018 .

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2019
Fair Value Disclosures [Abstract]
Summary of Classifications of the Company's Derivative Assets and Liabilities	The following table presents the amounts and classifications of the Company’s derivative assets and liabilities as of September 30, 2019 and December 31, 2018 , as well as the potential effect of netting arrangements on contracts with the same counterparty (in thousands): September 30, 2019 Level 1 Level 2 Level 3 Gross Fair Value Netting Carrying Value Assets Current commodity derivatives $ — $ 48,521 $ — $ 48,521 $ (681 ) $ 47,840 Noncurrent commodity derivatives — 19,189 — 19,189 (395 ) 18,794 Total assets $ — $ 67,710 $ — $ 67,710 $ (1,076 ) $ 66,634 Liabilities Current commodity derivatives $ — $ (681 ) $ — $ (681 ) $ 681 $ — Noncurrent commodity derivatives — (395 ) — (395 ) 395 — Total liabilities $ — $ (1,076 ) $ — $ (1,076 ) $ 1,076 $ — December 31, 2018 Level 1 Level 2 Level 3 Gross Fair Value Netting Carrying Value Assets Current commodity derivatives $ — $ 85,728 $ — $ 85,728 $ (3,548 ) $ 82,180 Noncurrent commodity derivatives — 21,565 — 21,565 (927 ) 20,638 Total assets $ — $ 107,293 $ — $ 107,293 $ (4,475 ) $ 102,818 Liabilities Current commodity derivatives $ — $ (4,393 ) $ — $ (4,393 ) $ 3,548 $ (845 ) Noncurrent commodity derivatives — (1,068 ) — (1,068 ) 927 (141 ) Total liabilities $ — $ (5,461 ) $ — $ (5,461 ) $ 4,475 $ (986 )

Equity Compensation (Tables)

Equity Compensation (Tables)	9 Months Ended
	Sep. 30, 2019
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Summary of Activity	The following table presents activity for the Roan LLC PSUs during the nine months ended September 30, 2019 : Number of Weighted Total Fair Outstanding at December 31, 2018 1,158,750 $ 30.95 $ 35,864 Granted — — — Vested — — — Forfeited (518,750 ) 29.71 (15,411 ) Outstanding at September 30, 2019 640,000 $ 31.96 $ 20,453 The following table presents activity for the Roan Inc PSUs during the nine months ended September 30, 2019 : Number of Weighted Total Fair Outstanding at December 31, 2018 — $ — $ — Granted 2,716,636 1.58 4,301 Vested — — — Forfeited (190,735 ) 2.55 (486 ) Outstanding at September 30, 2019 2,525,901 $ 1.51 $ 3,815
Summary of Activity	The following table presents activity for the Company’s RSUs during the nine months ended September 30, 2019 : Number of Weighted Total Fair Outstanding at December 31, 2018 11,800 $ 16.95 $ 200 Granted 1,676,325 3.86 6,476 Vested (381,764 ) 4.65 (1,775 ) Forfeited (187,235 ) 4.60 (861 ) Outstanding at September 30, 2019 1,119,126 $ 3.61 $ 4,040
Schedule of Fair Value of Share Based Payments or Units Granted, Valuation Assumptions [Table Text Block]	The following assumptions were used for the Monte Carlo simulation model to determine the grant date fair value and associated compensation expense for the Roan Inc PSU awards granted in 2019: Equity volatility 65.00 % Weighted average risk-free interest rate 2.25 %

Commitments and Contingencies (

Commitments and Contingencies (Tables)	9 Months Ended
	Sep. 30, 2019
Commitments and Contingencies Disclosure [Abstract]
Lease Assets and Liabilities	The Company’s condensed consolidated balance sheet as of September 30, 2019 included lease assets and liabilities as follows (in thousands): Operating Leases Operating lease right of use assets $ 5,312 Current operating lease liabilities $ 1,892 Noncurrent operating lease liabilities 4,444 Total operating lease liabilities $ 6,336
Schedule of Operating Lease Liabilities Payments	The Company’s operating lease liabilities as of September 30, 2019 with enforceable contract terms that are greater than one year mature as follows (in thousands): 2019 $ 478 2020 1,986 2021 2,073 2022 2,163 2023 445 Thereafter 171 Total lease payments 7,316 Less imputed interest (980 ) Total $ 6,336

Subsequent Events (Tables)

Subsequent Events (Tables)	9 Months Ended
	Sep. 30, 2019
Subsequent Events [Abstract]
Schedule of Additional Commodity Contracts	Per the covenants of the Merger Agreement, the Company was required to enter into additional commodity contracts. The following table presents the additional derivative contracts entered into in October 2019: 2019 2020 2021 2022 2023 2024 Oil fixed price swaps Volume (Bbl) — — — 1,261,500 1,047,000 686,500 Weighted-average price $ — $ — $ — $ 50.00 $ 50.00 $ 50.00 Natural gas fixed price swaps Volume (MMBtu) — 9,845,000 15,370,000 — — — Weighted-average price $ — $ 2.39 $ 2.39 $ — $ — $ — Natural gas basis swaps Volume (MMBtu) — 18,580,000 22,610,000 — — — Weighted-average price $ — $ 0.45 $ 0.38 $ — $ — $ — Natural gas liquids fixed price swaps Volume (Bbl) 456,500 1,574,400 1,441,100 — — — Weighted-average price $ 22.62 $ 19.09 $ 18.91 $ — $ — $ —

Business and Organization - Add

Business and Organization - Additional information (Details)	Aug. 31, 2017
Citizen
Schedule of Equity Method Investments [Line Items]
Ownership percentage	50.00%
Linn
Schedule of Equity Method Investments [Line Items]
Ownership percentage	50.00%

Lease Accounting (Details)

Lease Accounting (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other noncurrent assets	$ 11,780	$ 7,659
Other current liabilities	2,666	790
Other noncurrent liabilities	5,661	$ 902
Under ASC 842
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other noncurrent assets	5,312
Other current liabilities	1,892
Other noncurrent liabilities	4,444
Under ASC 840
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other noncurrent assets	0
Other current liabilities	0
Other noncurrent liabilities	1,024
Increase/(decrease) | Under ASC 842
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other noncurrent assets	5,312
Other current liabilities	1,892
Other noncurrent liabilities	$ 3,420

Revenue from Contracts with C_2

Revenue from Contracts with Customers - Additional Information (Details) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Revenue from Contract with Customer [Abstract]
Performance obligations	The Company satisfies the performance obligations under its oil and natural gas sales contracts through delivery of its production and transfer of control to a customer. Upon delivery of production, the Company has the right to receive consideration from its customers in amounts that correspond with the value of the production transferred. The Company typically receives payment for oil, natural gas and NGL sales within 30 days of the month of delivery for operated properties and within 90 days of the month of delivery for non-operated properties. The Company’s oil sales contracts are short-term in nature with a contract term of one year or less. For those contracts, the Company utilized the practical expedient in Revenue from Contracts with Customers (Topic 606) (“ASC 606”), which provides an exemption from disclosure of the transaction price allocated to remaining performance obligations if the performance obligation is part of a contract that has an original expected duration of one year or less. For the Company’s natural gas and NGL sales contracts that have a contract term greater than one year, the Company utilized the practical expedient in ASC 606 which states the Company is not required to disclose the transaction price allocated to remaining performance obligations if the variable consideration is allocated entirely to a wholly unsatisfied performance obligation. Under these sales contracts, each unit of product generally represents a separate performance obligation; therefore, future volumes are wholly unsatisfied, and disclosure of the transaction price allocated to remaining performance obligations is not required.
Contract with customer accounts receivable	$ 44.3	$ 65.2

Oil and Natural Gas Propertie_2

Oil and Natural Gas Properties - Schedule of Oil and Natural Gas Properties (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Oil and Gas Property [Abstract]
Proved	$ 1,991,687	$ 1,538,379
Unproved	1,048,592	1,089,954
Less: accumulated depreciation, depletion, amortization and impairment	(400,710)	(230,836)
Oil and natural gas properties, net	$ 2,639,569	$ 2,397,497

Oil and Natural Gas Propertie_3

Oil and Natural Gas Properties - Additional Information (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Amortization expense	$ 13,700,000	$ 11,200,000	$ 35,900,000	$ 25,600,000
Impairment of proved oil and natural gas properties	$ 0	$ 0	$ 0	$ 0

Asset Retirement Obligations -

Asset Retirement Obligations - Schedule of Reconciliation of Asset Retirement Obligations (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2019	Dec. 31, 2018
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Asset retirement obligation, beginning balance	$ 16,848
Liabilities incurred or acquired	1,024
Revisions in estimated cash flows	0
Liabilities settled	(80)
Accretion expense	869
Asset retirement obligation, ending balance	18,661
Less: current portion of obligations	774
Asset retirement obligation – long term	$ 17,887	$ 16,058

Long-Term Debt - Schedule of Lo

Long-Term Debt - Schedule of Long-term Debt (Details) - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Debt Instrument [Line Items]
Long-term debt	$ 732,639	$ 514,639
Credit Facility
Debt Instrument [Line Items]
Long-term debt	732,639	514,639
Term Loan
Debt Instrument [Line Items]
Long-term debt	50,000
Term Loan | Affiliates
Debt Instrument [Line Items]
Long-term debt	50,000	0
Unamortized original issue discount on Term Loan	(1,022)	0
Repayment premium on Term Loan	97	0
Deferred financing costs on Term Loan	(3,480)	0
Long-term debt	$ 45,595	$ 0

Long-Term Debt - Credit Facilit

Long-Term Debt - Credit Facility (Details)	1 Months Ended	3 Months Ended	9 Months Ended
	Jun. 30, 2019USD ($)	Dec. 31, 2019	Sep. 30, 2019USD ($)	Sep. 30, 2018USD ($)	May 31, 2019	Mar. 31, 2019USD ($)	Sep. 30, 2017USD ($)
Line of Credit Facility [Line Items]
Repayment of borrowings			$ 45,000,000	$ 0
ABR Margin | Forecast
Line of Credit Facility [Line Items]
Margin percentage		0.25%
2017 Credit Facility
Line of Credit Facility [Line Items]
Line of credit facility, maximum borrowing capacity							$ 750,000,000
Line of credit facility, outstanding borrowings			$ 732,600,000
Increase in borrowing base						$ 400,000,000
Line of credit facility, current borrowing capacity	$ 750,000,000
Current assets to current liabilities	0.85		0.80
Current ratio threshold			100.00%
Mortgage coverage requirements			95.00%		85.00%
Percentage of projected production hedged, first rolling 30 months			80.00%
Percentage of projected production hedged, second rolling 30 months			80.00%
Borrowings outstanding threshold percentage			50.00%
Minimum future production hedge percentage			50.00%
Debt to EBITDAX Ratio			4
2017 Credit Facility | Forecast
Line of Credit Facility [Line Items]
Current assets to current liabilities		1
2017 Credit Facility | Letter of credit
Line of Credit Facility [Line Items]
Line of credit facility, outstanding borrowings			$ 0
2017 Credit Facility | Secured
Line of Credit Facility [Line Items]
Increase in borrowing base						$ 250,000,000
2017 Credit Facility | LIBOR Margin
Line of Credit Facility [Line Items]
Increase on variable rate	0.25%
Margin percentage			1.00%
2017 Credit Facility | Federal funds effective rate
Line of Credit Facility [Line Items]
Margin percentage			0.50%
2017 Credit Facility | ABR Margin
Line of Credit Facility [Line Items]
Increase on variable rate	0.25%

Long-Term Debt - Term Loan (Det

Long-Term Debt - Term Loan (Details) - USD ($)	1 Months Ended	9 Months Ended
	Jun. 30, 2019	Sep. 30, 2019
Class A common stock
Line of Credit Facility [Line Items]
Shares issued in connection with Term Loan (shares)		1,525,395
Term Loan
Line of Credit Facility [Line Items]
Borrowing capacity	$ 100,000,000
Potential incremental commitment	$ 50,000,000
Discount percent		2.50%
Percent of outstanding shares		1.00%
Long-term debt		$ 50,000,000
Proceeds		$ 47,800,000
Interest rate		9.60%
Premium percent		1.00%
Prepayment premium		$ 500,000
Liquidity		$ 10,000,000
Term Loan | ABR Margin
Line of Credit Facility [Line Items]
Margin percentage	6.50%
Term Loan | Three-month LIBOR
Line of Credit Facility [Line Items]
Margin percentage	7.50%
Term Loan | Federal funds effective rate
Line of Credit Facility [Line Items]
Margin percentage	0.50%
Term Loan | One-month LIBOR
Line of Credit Facility [Line Items]
Margin percentage	1.00%

Long-Term Debt - Schedule of Ap

Long-Term Debt - Schedule of Applicable Margin for LIBOR Rate Loans Depending on the Utilization Level (Details) - 2017 Credit Facility	9 Months Ended
	Sep. 30, 2019
Level I
Line of Credit Facility [Line Items]
Commitment Fee	0.375%
Level II
Line of Credit Facility [Line Items]
Commitment Fee	0.375%
Level III
Line of Credit Facility [Line Items]
Commitment Fee	0.50%
Level IV
Line of Credit Facility [Line Items]
Commitment Fee	0.50%
Level V
Line of Credit Facility [Line Items]
Commitment Fee	0.50%
LIBOR Margin
Line of Credit Facility [Line Items]
Margin percentage	1.00%
LIBOR Margin | Level I
Line of Credit Facility [Line Items]
Margin percentage	2.00%
LIBOR Margin | Level II
Line of Credit Facility [Line Items]
Margin percentage	2.25%
LIBOR Margin | Level III
Line of Credit Facility [Line Items]
Margin percentage	2.50%
LIBOR Margin | Level IV
Line of Credit Facility [Line Items]
Margin percentage	2.75%
LIBOR Margin | Level V
Line of Credit Facility [Line Items]
Margin percentage	3.00%
ABR Margin | Level I
Line of Credit Facility [Line Items]
Margin percentage	1.00%
ABR Margin | Level II
Line of Credit Facility [Line Items]
Margin percentage	1.25%
ABR Margin | Level III
Line of Credit Facility [Line Items]
Margin percentage	1.50%
ABR Margin | Level IV
Line of Credit Facility [Line Items]
Margin percentage	1.75%
ABR Margin | Level V
Line of Credit Facility [Line Items]
Margin percentage	2.00%

Derivative Instruments - Schedu

Derivative Instruments - Schedule of Company's Open Commodity Contracts (Details) MMBTU in Thousands	9 Months Ended
	Sep. 30, 2019MMBTU$ / MMBTU$ / bblbbl
Fixed price/basis swaps | Oil fixed price swaps
Derivative Instruments [Line Items]
Volume (Bbl) | bbl	6,360,230
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	59.38
Fixed price/basis swaps | Oil fixed price swaps | 2019
Derivative Instruments [Line Items]
Volume (Bbl) | bbl	1,200,730
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	60.75
Fixed price/basis swaps | Oil fixed price swaps | 2020
Derivative Instruments [Line Items]
Volume (Bbl) | bbl	3,429,500
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	60.57
Fixed price/basis swaps | Oil fixed price swaps | 2021
Derivative Instruments [Line Items]
Volume (Bbl) | bbl	1,730,000
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	56.08
Fixed price/basis swaps | Natural gas fixed price swaps
Derivative Instruments [Line Items]
Volume (MMBtu) | MMBTU	37,955
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	2.71
Fixed price/basis swaps | Natural gas fixed price swaps | 2019
Derivative Instruments [Line Items]
Volume (MMBtu) | MMBTU	11,040
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	2.90
Fixed price/basis swaps | Natural gas fixed price swaps | 2020
Derivative Instruments [Line Items]
Volume (MMBtu) | MMBTU	19,665
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	2.63
Fixed price/basis swaps | Natural gas fixed price swaps | 2021
Derivative Instruments [Line Items]
Volume (MMBtu) | MMBTU	7,250
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	2.65
Fixed price/basis swaps | Natural gas liquids fixed price swaps
Derivative Instruments [Line Items]
Volume (Bbl) | bbl	2,471,000
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	23.84
Fixed price/basis swaps | Natural gas liquids fixed price swaps | 2019
Derivative Instruments [Line Items]
Volume (Bbl) | bbl	460,000
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	28.66
Fixed price/basis swaps | Natural gas liquids fixed price swaps | 2020
Derivative Instruments [Line Items]
Volume (Bbl) | bbl	1,281,000
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	23.22
Fixed price/basis swaps | Natural gas liquids fixed price swaps | 2021
Derivative Instruments [Line Items]
Volume (Bbl) | bbl	730,000
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	21.90
Natural gas basis swaps | Natural gas basis swaps
Derivative Instruments [Line Items]
Volume (MMBtu) | MMBTU	18,340
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0.50
Natural gas basis swaps | Natural gas basis swaps | 2019
Derivative Instruments [Line Items]
Volume (MMBtu) | MMBTU	7,360
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0.52
Natural gas basis swaps | Natural gas basis swaps | 2020
Derivative Instruments [Line Items]
Volume (MMBtu) | MMBTU	10,980
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0.49
Natural gas basis swaps | Natural gas basis swaps | 2021
Derivative Instruments [Line Items]
Volume (MMBtu) | MMBTU	0
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0

Derivative Instruments - Sche_2

Derivative Instruments - Schedule of Net Gains and Loss on Derivative Contracts (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Gain (loss) on derivative contracts	$ 40,675	$ (36,704)	$ (5,913)	$ (100,920)
Net cash received (paid) upon settlement of derivative contracts	$ 16,541	$ (13,551)	$ 29,284	(27,462)
Net cash received upon settlement of derivative contracts prior to contractual maturity				$ 400

Derivative Instruments - Additi

Derivative Instruments - Additional Information (Details) - USD ($) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Cash received on settlement of hedge	$ 5.2	$ 9.3

Fair Value Measurements - Summa

Fair Value Measurements - Summary of Classifications of the Company's Derivative Assets and Liabilities (Details) - Fair Value, Measurements, Recurring - USD ($) $ in Thousands	Sep. 30, 2019	Dec. 31, 2018
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	$ 67,710	$ 107,293
Netting	(1,076)	(4,475)
Total assets, Carrying Value	66,634	102,818
Derivative Liabilities	(1,076)	(5,461)
Netting	1,076	4,475
Total liabilities, Carrying Value	0	(986)
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0
Derivative Liabilities	0	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	67,710	107,293
Derivative Liabilities	(1,076)	(5,461)
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0
Derivative Liabilities	0	0
Current commodity derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	48,521	85,728
Netting	(681)	(3,548)
Total assets, Carrying Value	47,840	82,180
Derivative Liabilities	(681)	(4,393)
Netting	681	3,548
Total liabilities, Carrying Value	0	(845)
Current commodity derivatives | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0
Derivative Liabilities	0	0
Current commodity derivatives | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	48,521	85,728
Derivative Liabilities	(681)	(4,393)
Current commodity derivatives | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0
Derivative Liabilities	0	0
Noncurrent commodity derivatives
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	19,189	21,565
Netting	(395)	(927)
Total assets, Carrying Value	18,794	20,638
Derivative Liabilities	(395)	(1,068)
Netting	395	927
Total liabilities, Carrying Value	0	(141)
Noncurrent commodity derivatives | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0
Derivative Liabilities	0	0
Noncurrent commodity derivatives | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	19,189	21,565
Derivative Liabilities	(395)	(1,068)
Noncurrent commodity derivatives | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Derivative Assets	0	0
Derivative Liabilities	$ 0	$ 0

Equity - Additional Information

Equity - Additional Information (Details) - USD ($)	1 Months Ended			3 Months Ended	9 Months Ended
	Sep. 30, 2019	Mar. 31, 2018	Aug. 31, 2017	Jun. 30, 2019	Sep. 30, 2019	Dec. 31, 2018	Sep. 30, 2018
Capital Unit [Line Items]
Shares issued in connection with Term Loan				$ 2,318,000
Common stock withheld for the payment of taxes (in shares)	112,945
Common stock withheld for the payment of taxes	$ 100,000
Common shares issued (shares)	154,333,746				154,333,746	152,539,532
Linn Energy Holdings | Roan LLC
Capital Unit [Line Items]
Ownership percentage			50.00%
Linn Energy Holdings | Membership units | Roan LLC
Capital Unit [Line Items]
Units issued (shares)		19,200,000	1,500,000,000
Citizen | Roan LLC
Capital Unit [Line Items]
Ownership percentage			50.00%
Citizen | Membership units | Roan LLC
Capital Unit [Line Items]
Units issued (shares)		19,200,000	1,500,000,000
Class A common stock
Capital Unit [Line Items]
Shares issued in connection with Term Loan (shares)					1,525,395
Shares issued in connection with Term Loan					$ 1,525
Class A common stock | Members of Roan LLC
Capital Unit [Line Items]
Common shares issued (shares)							152,500,000

Equity Compensation - Additiona

Equity Compensation - Additional Information (Details) - USD ($) $ in Millions	Dec. 31, 2020	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018
Roan Inc PSU
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Consecutive trading days		60 days
Volume weighted average price, days		60 days
Roan Inc PSU | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awarded PSUs recipient vesting		0.00%
Roan Inc PSU | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awarded PSUs recipient vesting		100.00%
PSUs and PSAs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		$ 1.5	$ 2.9	$ 0.8	$ 8.1
Reversal of compensation expense				6.5
Unrecognized expense		12.1		$ 12.1
Weighted average remaining period				2 years 2 months 15 days
Restricted Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense		1.5		$ 2.1
Unrecognized expense		$ 3.7		$ 3.7
Weighted average remaining period				1 year 7 months 10 days
Forecast | Roan LLC PSUs
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Consecutive trading days	30 days
Forecast | Roan LLC PSUs | Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awarded PSUs recipient vesting	0.00%
Forecast | Roan LLC PSUs | Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Awarded PSUs recipient vesting	200.00%

Equity Compensation - Summary o

Equity Compensation - Summary of Activity (Details) $ / shares in Units, $ in Thousands	9 Months Ended
	Sep. 30, 2019USD ($)$ / sharesshares
Roan LLC PSUs
Number of PSUs
Beginning balance (shares) | shares	1,158,750
Units granted (shares) | shares	0
Units vested (shares) | shares	0
Forfeited (shares) | shares	(518,750)
Ending balance (shares) | shares	640,000
Weighted Average Fair Value
Beginning balance (usd per share) | $ / shares	$ 30.95
Units granted (usd per share) | $ / shares	0
Units vested (usd per share) | $ / shares	0
Forfeited (usd per share) | $ / shares	29.71
Ending balance (usd per share) | $ / shares	$ 31.96
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value [Roll Forward]
Units outstanding | $	$ 35,864
Granted | $	0
Vested | $	0
Forfeited | $	(15,411)
Units outstanding | $	$ 20,453
Roan Inc PSU
Number of PSUs
Beginning balance (shares) | shares	0
Units granted (shares) | shares	2,716,636
Units vested (shares) | shares	0
Forfeited (shares) | shares	(190,735)
Ending balance (shares) | shares	2,525,901
Weighted Average Fair Value
Beginning balance (usd per share) | $ / shares	$ 0
Units granted (usd per share) | $ / shares	1.58
Units vested (usd per share) | $ / shares	0
Forfeited (usd per share) | $ / shares	2.55
Ending balance (usd per share) | $ / shares	$ 1.51
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value [Roll Forward]
Units outstanding | $	$ 0
Granted | $	4,301
Vested | $	0
Forfeited | $	(486)
Units outstanding | $	$ 3,815
Restricted Stock Units
Number of PSUs
Beginning balance (shares) | shares	11,800
Units granted (shares) | shares	1,676,325
Units vested (shares) | shares	(381,764)
Forfeited (shares) | shares	(187,235)
Ending balance (shares) | shares	1,119,126
Weighted Average Fair Value
Beginning balance (usd per share) | $ / shares	$ 16.95
Units granted (usd per share) | $ / shares	3.86
Units vested (usd per share) | $ / shares	4.65
Forfeited (usd per share) | $ / shares	4.60
Ending balance (usd per share) | $ / shares	$ 3.61
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Aggregate Intrinsic Value [Roll Forward]
Units outstanding | $	$ 200
Granted | $	6,476
Vested | $	(1,775)
Forfeited | $	(861)
Units outstanding | $	$ 4,040

Equity Compensation - Schedule

Equity Compensation - Schedule of Assumptions Used to Determine the Grant Date Fair Value and Associated Compensation Expense (Details) - Roan Inc PSU	9 Months Ended
	Sep. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Equity volatility	65.00%
Weighted average risk-free interest rate	2.25%

Transactions with Affiliates -

Transactions with Affiliates - Additional Information (Details) - USD ($)	1 Months Ended	3 Months Ended		9 Months Ended
	Jul. 31, 2019	Sep. 30, 2019	Sep. 30, 2018	Sep. 30, 2019	Sep. 30, 2018	Dec. 31, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Accounts payable and accrued liabilities – Affiliates		$ 7,721,000		$ 7,721,000		$ 8,577,000
Total remaining lease payments		6,336,000		6,336,000
Interest expense		9,051,000	$ 2,092,000	24,230,000	$ 4,978,000
Linn Energy Holdings and Citizen Energy LLC
Related Party Transaction [Line Items]
Accounts payable and accrued liabilities – Affiliates							$ 63,000,000
MSAs
Related Party Transaction [Line Items]
Charges related to services			0		10,000,000
Corporate office lease | Riviera | Affiliates
Related Party Transaction [Line Items]
Initial term						5 years
Renewal term						5 years
Lease expense		400,000		1,100,000
Lease expense			$ 200,000		$ 300,000
Total remaining lease payments		6,700,000		6,700,000
TMA | Riviera
Related Party Transaction [Line Items]
Amount of transaction				7,600,000
Wildcat Water Management Services Agreement
Related Party Transaction [Line Items]
Charges related to services		7,400,000		13,800,000
Charged related to services capitalized		2,000,000		3,800,000
Accounts payable and accrued liabilities – Affiliates		6,500,000		6,500,000
Production expenses | Wildcat Water Management Services Agreement
Related Party Transaction [Line Items]
Charges related to services		5,400,000		10,000,000
Wildcat Water | Wildcat Water Management Services Agreement
Related Party Transaction [Line Items]
Amount of transaction		8,700,000		17,200,000
Wildcat Oil | Oil Gathering Agreement
Related Party Transaction [Line Items]
Agreement term	10 years
Term Loan | Affiliates
Related Party Transaction [Line Items]
Interest expense		2,300,000		2,300,000
Amortization of discount		300,000
Deferred financing cost		700,000
Accrued interest		$ 1,300,000		$ 1,300,000

Income Taxes - Additional Infor

Income Taxes - Additional Information (Details)	3 Months Ended	9 Months Ended
	Sep. 30, 2019	Sep. 30, 2019
Income Tax Disclosure [Abstract]
Effective combined U.S. federal and state income excluding discrete items, tax rate	23.40%	23.80%

Commitments and Contingencies -

Commitments and Contingencies - Additional Information (Details) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2019USD ($)	Sep. 30, 2019USD ($)
Commitments and Contingencies Disclosure [Abstract]
Operating lease costs	$ 0.6	$ 1.6
Lessee, Lease, Description [Line Items]
Short-term lease costs	9.7	56.8
Operating cash flows related to operating leases	$ 0.5	$ 1.2
Weighted average remaining lease term	3 years 6 months	3 years 6 months
Weighted average discount rate	8.50%	8.50%
Accrued deficiency fee	$ 1	$ 1
Deficiency fees	6.4	6.4
Drilling Rig
Lessee, Lease, Description [Line Items]
Short-term lease costs	$ 8.4	$ 53.1

Commitments and Contingencies_2

Commitments and Contingencies - Lease Assets and Liabilities (Details) $ in Thousands	Sep. 30, 2019USD ($)
Commitments and Contingencies Disclosure [Abstract]
Operating lease right of use assets	$ 5,312
Current operating lease liabilities	1,892
Noncurrent operating lease liabilities	4,444
Total operating lease liabilities	$ 6,336

Commitments and Contingencies_3

Commitments and Contingencies - Schedule of Operating Lease Liabilities Payments (Details) $ in Thousands	Sep. 30, 2019USD ($)
Commitments and Contingencies Disclosure [Abstract]
2019	$ 478
2020	1,986
2021	2,073
2022	2,163
2023	445
Thereafter	171
Total lease payments	7,316
Less imputed interest	(980)
Total	$ 6,336

Subsequent Events - Additional

Subsequent Events - Additional Information (Details) - USD ($)	Oct. 01, 2019	Jun. 30, 2019
Subsequent event
Subsequent Event [Line Items]
Maximum indebtedness	$ 760,000,000
Termination fees if terminated by Roan	25,000,000
Termination fees if terminated by Citizen	35,000,000
Termination fees	$ 15,000,000
Roan Resources, Inc. | Citizen | Class A common stock | Subsequent event
Subsequent Event [Line Items]
Cash consideration per share (usd per share)	$ 1.52
2017 Credit Facility
Subsequent Event [Line Items]
Line of credit facility, current borrowing capacity		$ 750,000,000

Subsequent Events - Schedule of

Subsequent Events - Schedule of Additional Commodity Contracts (Details) MMBTU in Thousands	1 Months Ended	9 Months Ended
	Oct. 31, 2019MMBTU$ / MMBTU$ / bblbbl	Sep. 30, 2019MMBTU$ / MMBTU$ / bblbbl
Oil fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Volume (Bbl) | bbl		6,360,230
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl		59.38
Natural gas fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU		2.71
Volume (MMBtu) | MMBTU		37,955
Natural gas basis swaps | Natural gas basis swaps
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU		0.50
Volume (MMBtu) | MMBTU		18,340
Natural gas liquids fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Volume (Bbl) | bbl		2,471,000
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl		23.84
2019 | Oil fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Volume (Bbl) | bbl		1,200,730
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl		60.75
2019 | Oil fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	0
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	0
2019 | Natural gas fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU		2.90
Volume (MMBtu) | MMBTU		11,040
2019 | Natural gas fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0
Volume (MMBtu) | MMBTU	0
2019 | Natural gas basis swaps | Natural gas basis swaps
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU		0.52
Volume (MMBtu) | MMBTU		7,360
2019 | Natural gas basis swaps | Natural gas basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0
Volume (MMBtu) | MMBTU	0
2019 | Natural gas liquids fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Volume (Bbl) | bbl		460,000
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl		28.66
2019 | Natural gas liquids fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	456,500
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	22.62
2020 | Oil fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Volume (Bbl) | bbl		3,429,500
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl		60.57
2020 | Oil fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	0
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	0
2020 | Natural gas fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU		2.63
Volume (MMBtu) | MMBTU		19,665
2020 | Natural gas fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	2.39
Volume (MMBtu) | MMBTU	9,845
2020 | Natural gas basis swaps | Natural gas basis swaps
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU		0.49
Volume (MMBtu) | MMBTU		10,980
2020 | Natural gas basis swaps | Natural gas basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0.45
Volume (MMBtu) | MMBTU	18,580
2020 | Natural gas liquids fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Volume (Bbl) | bbl		1,281,000
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl		23.22
2020 | Natural gas liquids fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	1,574,400
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	19.09
2021 | Oil fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Volume (Bbl) | bbl		1,730,000
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl		56.08
2021 | Oil fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	0
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	0
2021 | Natural gas fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU		2.65
Volume (MMBtu) | MMBTU		7,250
2021 | Natural gas fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	2.39
Volume (MMBtu) | MMBTU	15,370
2021 | Natural gas basis swaps | Natural gas basis swaps
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU		0
Volume (MMBtu) | MMBTU		0
2021 | Natural gas basis swaps | Natural gas basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0.38
Volume (MMBtu) | MMBTU	22,610
2021 | Natural gas liquids fixed price swaps | Fixed price/basis swaps
Subsequent Event [Line Items]
Volume (Bbl) | bbl		730,000
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl		21.90
2021 | Natural gas liquids fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	1,441,100
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	18.91
2022 | Oil fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	1,261,500
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	50
2022 | Natural gas fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0
Volume (MMBtu) | MMBTU	0
2022 | Natural gas basis swaps | Natural gas basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0
Volume (MMBtu) | MMBTU	0
2022 | Natural gas liquids fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	0
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	0
2023 | Oil fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	1,047,000
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	50
2023 | Natural gas fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0
Volume (MMBtu) | MMBTU	0
2023 | Natural gas basis swaps | Natural gas basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0
Volume (MMBtu) | MMBTU	0
2023 | Natural gas liquids fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	0
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	0
2024 | Oil fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	686,500
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	50
2024 | Natural gas fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0
Volume (MMBtu) | MMBTU	0
2024 | Natural gas basis swaps | Natural gas basis swaps | Subsequent event
Subsequent Event [Line Items]
Weighted average price (usd per bbl or usd per MMBtu) | $ / MMBTU	0
Volume (MMBtu) | MMBTU	0
2024 | Natural gas liquids fixed price swaps | Fixed price/basis swaps | Subsequent event
Subsequent Event [Line Items]
Volume (Bbl) | bbl	0
Weighted average price (usd per bbl or usd per MMBtu) | $ / bbl	0