Matador Resources (MTDR) 10-K1 Mar 232022 FY Annual reportFinancial data

Company Profile

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
Document and Entity Information - USD ($)	Dec. 31, 2022	Feb. 21, 2023	Jun. 30, 2022
Document and Entity Information [Abstract]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2022
Document Transition Report	false
Entity File Number	001-35410
Entity Registrant Name	Matador Resources Company
Entity Incorporation, State or Country Code	TX
Entity Address, Address Line Two	Suite 1500
Entity Tax Identification Number	27-4662601
Entity Address, Address Line One	5400 LBJ Freeway,
Entity Address, City or Town	Dallas,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	75240
City Area Code	972
Local Phone Number	371-5200
Title of 12(b) Security	Common Stock, par value $0.01 per share
Trading Symbol	MTDR
Security Exchange Name	NYSE
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 5,188,536,396
Entity Common Stock, Shares Outstanding		119,071,975
Entity Central Index Key	0001520006
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Documents Incorporated by Reference	The information required by Part III of this Annual Report on Form 10-K, to the extent not set forth herein, is incorporated by reference to the registrant’s definitive proxy statement relating to the 2022 Annual Meeting of Shareholders, which will be filed with the Securities and Exchange Commission within 120 days after the end of the fiscal year to which this Annual Report on Form 10-K relates.

Audit Information

Audit Information	12 Months Ended
Audit Information	Dec. 31, 2022
Audit Information [Abstract]
Auditor Name	KPMG LLP
Auditor Location	Dallas, TX
Auditor Firm ID	185

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Current assets
Cash	$ 505,179	$ 48,135
Restricted cash	42,151	38,785
Accounts receivable
Oil and natural gas revenues	224,860	164,242
Joint interest billings	180,947	48,366
Other	48,011	28,808
Derivative instruments	3,930	1,971
Lease and well equipment inventory	15,184	12,188
Prepaid expenses and other current assets	51,570	28,810
Total current assets	1,071,832	371,305
Oil and natural gas properties, full-cost method
Evaluated	6,862,455	6,007,325
Unproved and unevaluated	977,502	964,714
Midstream properties	1,057,668	900,979
Midstream properties	32,847	30,123
Less accumulated depletion, depreciation and amortization	(4,512,275)	(4,046,456)
Net property and equipment	4,418,197	3,856,685
Other assets
Other long-term assets	64,476	34,163
Total assets	5,554,505	4,262,153
Current liabilities
Accounts payable	58,848	26,256
Accrued liabilities	261,310	253,283
Royalties payable	117,698	94,359
Amounts due to affiliates	32,803	27,324
Derivative instruments	0	16,849
Advances from joint interest owners	52,357	18,074
Other current liabilities	52,857	28,692
Total current liabilities	575,873	464,837
Long-term liabilities
Borrowings under Credit Agreement	0	100,000
Borrowings under San Mateo Credit Facility	465,000	385,000
Senior unsecured notes payable	695,245	1,042,580
Asset retirement obligations	52,985	41,689
Deferred income taxes	428,351	77,938
Other long-term liabilities	19,960	22,721
Total long-term liabilities	1,661,541	1,669,928
Commitments and contingencies (Note 14)
Shareholders' equity
Common stock — $0.01 par value, 160,000,000 shares authorized; 118,953,381 and 117,861,923 shares issued; and 118,948,624 and 117,850,233 shares outstanding, respectively	1,190	1,179
Additional paid-in capital	2,101,999	2,077,592
Retained earnings (accumulated deficit)	1,007,642	(171,318)
Treasury stock, at cost, 4,757 and 11,945 shares, respectively	(34)	(243)
Total shareholders' equity	3,110,797	1,907,210
Non-controlling interest in subsidiaries	206,294	220,178
Total shareholders’ equity	3,317,091	2,127,388
Total liabilities and shareholders’ equity	$ 5,554,505	$ 4,262,153

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - $ / shares	Dec. 31, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Common stock, par value (usd per share)	$ 0.01	$ 0.01
Common stock, shares authorized (in shares)	160,000,000	160,000,000
Common stock, shares issued (in shares)	118,953,381	117,861,923
Common stock, shares outstanding (in shares)	118,948,624	117,850,233
Treasury stock (in shares)	4,757	11,945

Consolidated Statements of Oper

Consolidated Statements of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Revenues
Revenues	$ 3,196,699	$ 1,862,075	$ 851,135
Lease bonus - mineral acreage	0	0	4,062
Realized (loss) gain on derivatives	(157,483)	(220,105)	38,937
Unrealized gain (loss) on derivatives	18,809	21,011	(32,008)
Total revenues	3,058,025	1,662,981	862,126
Expenses
Production taxes, transportation and processing	282,193	178,987	93,338
Lease operating	157,105	108,964	104,953
Plant and other midstream services operating	95,522	61,459	41,500
Purchased natural gas	178,937	77,126	32,734
Depletion, depreciation and amortization	466,348	344,905	361,831
Accretion of asset retirement obligations	2,421	2,068	1,948
Full-cost ceiling impairment	0	0	684,743
General and administrative	116,229	96,396	62,578
Total expenses	1,298,755	869,905	1,383,625
Operating income (loss)	1,759,270	793,076	(521,499)
Other income (expense)
Net loss on asset sales and impairment	(1,311)	(331)	(2,832)
Interest expense	(67,164)	(74,687)	(76,692)
Other (expense) income	(5,121)	(2,712)	1,864
Total other expense	(73,596)	(77,730)	(77,660)
Income (loss) before income taxes	1,685,674	715,346	(599,159)
Income tax provision (benefit)
Current	54,877	0	0
Deferred	344,480	74,710	(45,599)
Total income tax provision (benefit)	399,357	74,710	(45,599)
Net income (loss)	1,286,317	640,636	(553,560)
Net income attributable to non-controlling interest in subsidiaries	(72,111)	(55,668)	(39,645)
Net income (loss) attributable to Matador Resources Company shareholders	$ 1,214,206	$ 584,968	$ (593,205)
Earnings (loss) per common share attributable to Matador Resources Company shareholders
Basic (usd per share)	$ 10.28	$ 5	$ (5.11)
Diluted (usd per share)	$ 10.11	$ 4.91	$ (5.11)
Weighted average common shares outstanding
Basic (in shares)	118,122	116,999	116,068
Diluted (in shares)	120,131	119,163	116,068
Oil and natural gas revenues
Revenues
Revenues	$ 2,905,738	$ 1,700,542	$ 744,461
Third-party midstream services revenues
Revenues
Revenues	90,606	75,499	64,932
Sales of purchased natural gas
Revenues
Revenues	$ 200,355	$ 86,034	$ 41,742

Consolidated Statements of Chan

Consolidated Statements of Changes in Shareholders' Equity - USD ($)	Total	Common stock	Additional paid-in capital	(Accumulated deficit) retained earnings	Treasury stock	Parent	Noncontrolling Interest
Beginning Balance at Dec. 31, 2019	$ 1,969,452,000	$ 1,166,000	$ 1,981,014,000	$ (148,500,000)	$ (26,000)	$ 1,833,654,000	$ 135,798,000
Beginning Balance, shares (in shares) at Dec. 31, 2019		116,644,000			1,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Issuance of common stock pursuant to employee stock compensation plan (in shares)		244,000
Issuance of common stock pursuant to employee stock compensation plan	0	$ 2,000	(2,000)			0
Issuance of Class A common stock to Board member and advisors (in shares)		85,000
Issuance of Class A common stock to Board member and advisors	0	$ 1,000	(1,000)			0
Stock options expense related to equity based awards	17,452,000		17,452,000			17,452,000
Stock options exercised (in shares)		0
Stock options exercised, net of options forfeited in net share settlements	(24,000)	$ 0	(24,000)			(24,000)
Liability-Based Stock Option Awards Settled, (in shares)		22,000
Liability-Based Stock Option Awards Settled	297,000		297,000			297,000
Restricted stock forfeited (in shares)					149,000
Restricted stock forfeited	(1,489,000)				$ (1,489,000)	(1,489,000)
Contributions related to formation of San Mateo I (see Note 6)	11,613,000		11,613,000			11,613,000
Contributions from non-controlling interest owners of less-than-wholly-owned subsidiaries	114,854,000		18,232,000			18,232,000	96,622,000
Distributions to non-controlling interest owners of less-than wholly-owned subsidiaries	(45,570,000)						(45,570,000)
Cancellation of treasury stock (in shares)		(148,000)			(148,000)
Cancellation of treasury stock	0	$ 0	(1,512,000)		$ 1,512,000	0
Net (loss) income	(553,560,000)			(593,205,000)		(593,205,000)	39,645,000
Ending Balance, shares (in shares) at Dec. 31, 2020		116,847,000			2,000
Ending Balance at Dec. 31, 2020	1,513,025,000	$ 1,169,000	2,027,069,000	(741,705,000)	$ (3,000)	1,286,530,000	226,495,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends declared	(14,581,000)			(14,581,000)		(14,581,000)
Issuance of common stock pursuant to employee stock compensation plan (in shares)		768,000
Issuance of common stock pursuant to employee stock compensation plan	0	$ 7,000	(7,000)				0
Stock Issued During Period, Shares, Issued for Services (in shares)		81,000
Stock Issued During Period, Value, Issued for Services	0	$ 1,000	(1,000)
Stock options expense related to equity based awards	12,113,000		12,113,000			12,113,000
Stock options exercised (in shares)		312,000
APIC, Share-based Payment Arrangement, Recognition and Exercise	(4,255,000)	$ 3,000	(4,258,000)			(4,255,000)
Restricted stock forfeited (in shares)					156,000
Restricted stock forfeited	(2,621,000)				$ (2,621,000)	(2,621,000)
Contributions related to formation of San Mateo I (see Note 6)	45,056,000		45,056,000			45,056,000
Distributions to non-controlling interest owners of less-than wholly-owned subsidiaries	(61,985,000)						(61,985,000)
Cancellation of treasury stock (in shares)		(146,000)			(146,000)
Cancellation of treasury stock		$ (1,000)	(2,380,000)		$ 2,381,000
Net (loss) income	$ 640,636,000			584,968,000		584,968,000	55,668,000
Ending Balance, shares (in shares) at Dec. 31, 2021	117,850,233	117,862,000			12,000
Ending Balance at Dec. 31, 2021	$ 2,127,388,000	$ 1,179,000	2,077,592,000	(171,318,000)	$ (243,000)	1,907,210,000	220,178,000
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Dividends declared	(35,246,000)			(35,246,000)		(35,246,000)
Issuance of common stock pursuant to employee stock compensation plan (in shares)		1,001,000
Issuance of common stock pursuant to employee stock compensation plan	(11,534,000)	$ 10,000	(11,544,000)			(11,534,000)
Issuance of Class A common stock to Board member and advisors (in shares)		25,000
Issuance of Class A common stock to Board member and advisors	0	$ 0	0
Stock options expense related to equity based awards	$ 20,224,000		20,224,000			20,224,000
Stock options exercised (in shares)	445,000	157,000
APIC, Share-based Payment Arrangement, Recognition and Exercise	$ (4,005,000)	$ 2,000	(4,007,000)			(4,005,000)
Restricted stock forfeited (in shares)					85,000
Restricted stock forfeited	(2,376,000)				$ (2,376,000)	(2,376,000)
Contributions related to formation of San Mateo I (see Note 6)	22,318,000		22,318,000			22,318,000
Distributions to non-controlling interest owners of less-than wholly-owned subsidiaries	(85,995,000)						(85,995,000)
Cancellation of treasury stock (in shares)		(92,000)			(92,000)
Cancellation of treasury stock	0	$ 1,000	(2,584,000)		$ 2,585,000
Net (loss) income	$ 1,286,317,000			1,214,206,000		1,214,206,000	72,111,000
Ending Balance, shares (in shares) at Dec. 31, 2022	118,948,624	118,953,000			5,000
Ending Balance at Dec. 31, 2022	$ 3,317,091,000	$ 1,190,000	$ 2,101,999,000	$ 1,007,642,000	$ (34,000)	$ 3,110,797,000	$ 206,294,000

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Operating activities
Net income (loss)	$ 1,286,317	$ 640,636	$ (553,560)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Unrealized (gain) loss on derivatives	(18,809)	(21,011)	32,008
Depletion, depreciation and amortization	466,348	344,905	361,831
Accretion of asset retirement obligations	2,421	2,068	1,948
Full-cost ceiling impairment	0	0	684,743
Stock-based compensation expense	15,123	9,039	13,625
Net deferred income tax provision (benefit)	344,480	74,710	(45,599)
Amortization of debt issuance cost and other debt related costs	(517)	3,659	2,832
Net loss on asset sales and impairment	1,311	331	2,832
Changes in operating assets and liabilities
Accounts receivable	(205,426)	(98,456)	53,001
Lease and well equipment inventory	(2,847)	(1,537)	(655)
Prepaid expenses	(22,952)	(11,786)	(3,010)
Other assets	175	56	1,681
Accounts payable, accrued liabilities and other current liabilities	63,455	76,891	(43,844)
Royalties payable	23,339	28,310	(19,144)
Advances from joint interest owners	34,283	7,018	(10,646)
Other long-term liabilities	(7,962)	(1,478)	(461)
Net cash provided by operating activities	1,978,739	1,053,355	477,582
Investing activities
Drilling, completion and equipping capital expenditures	(771,830)	(431,136)	(471,087)
Acquisition of oil and natural gas properties	(155,074)	(238,609)	(72,809)
Midstream capital expenditures	(80,051)	(63,359)	(234,359)
Payments to Acquire Businesses, Net of Cash Acquired	(75,816)	0	0
Expenditures for other property and equipment	(1,213)	(376)	(2,200)
Proceeds from sale of assets	46,507	4,215	4,789
Net cash used in investing activities	(1,037,477)	(729,265)	(775,666)
Financing activities
Purchase of senior unsecured notes	(344,302)	0	0
Repayments of borrowings under Credit Agreement	(300,000)	(600,000)	(35,000)
Borrowings under Credit Agreement	200,000	260,000	220,000
Repayments of borrowings under San Mateo Credit Facility	(150,000)	(84,000)	0
Borrowings under San Mateo Credit Facility	230,000	135,000	46,000
Cost to enter into or amend credit facilities	(3,725)	(4,108)	(660)
Dividends paid	(35,246)	(14,581)	0
Contributions related to formation of San Mateo	28,250	48,626	14,700
Contributions from non-controlling interest owners of less-than-wholly-owned subsidiaries	0	0	119,700
Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries	(85,995)	(61,985)	(45,570)
Taxes paid related to net share settlement of stock-based compensation	(19,242)	(8,211)	(1,556)
Other	(592)	706	6,725
Net cash (used in) provided by financing activities	(480,852)	(328,553)	324,339
Increase (decrease) in cash and restricted cash	460,410	(4,463)	26,255
Cash and restricted cash at beginning of period	86,920	91,383	65,128
Cash and restricted cash at end of period	$ 547,330	$ 86,920	$ 91,383

Consolidated Statements of Ch_2

Consolidated Statements of Changes in Shareholders' Equity (Parenthetical) - USD ($)	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Stockholders' Equity [Abstract]
Contribution related to formation of San Mateo, I, tax	$ 5,900,000	$ 3,600,000	$ 3,100,000
Contributions from non-controlling interest owners of less-than-wholly-owned subsidiaries, tax			4,800,000
Common stock, dividends (in usd per share)	$ 0.30	$ 0.125
Issuance of common stock pursuant to employee stock compensation plan	$ (11,534,000)	$ 0	$ 0

Nature of Operations

Nature of Operations	12 Months Ended
Nature of Operations	Dec. 31, 2022
Organization, Consolidation and Presentation of Financial Statements [Abstract]
NATURE OF OPERATIONS	NATURE OF OPERATIONS Matador Resources Company, a Texas corporation (“Matador” and, collectively with its subsidiaries, the “Company”), is an independent energy company engaged in the exploration, development, production and acquisition of oil and natural gas resources in the United States, with an emphasis on oil and natural gas shale and other unconventional plays. The Company’s current operations are focused primarily on the oil and liquids-rich portion of the Wolfcamp and Bone Spring plays in the Delaware Basin in Southeast New Mexico and West Texas. The Company also operates in the Eagle Ford shale play in South Texas and the Haynesville shale and Cotton Valley plays in Northwest Louisiana. Additionally, the Company conducts midstream operations primarily through its midstream joint venture, San Mateo Midstream, LLC (“San Mateo”), and Pronto Midstream, LLC (“Pronto”) in support of the Company’s exploration, development and production operations and provides natural gas processing, oil transportation services, oil, natural gas and produced water gathering services and produced water disposal services to third parties.

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
Summary of Significant Accounting Policies	Dec. 31, 2022
Accounting Policies [Abstract]
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES	Basis of Presentation The consolidated financial statements include the accounts of Matador and its wholly-owned and majority-owned subsidiaries. These consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States of America (“U.S. GAAP”). Accordingly, the Company consolidates certain subsidiaries and joint ventures that are less-than-wholly-owned and are not involved in oil and natural gas exploration, including San Mateo, and the net income and equity attributable to the non-controlling interest in these subsidiaries have been reported separately as required by Accounting Standards Codification (“ASC”), Consolidation (Topic 810) . The Company proportionately consolidates certain joint ventures that are less-than-wholly-owned and are involved in oil and natural gas exploration. All intercompany balances and transactions have been eliminated in consolidation. Use of Estimates The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. These estimates and assumptions may also affect disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company’s consolidated financial statements are based on a number of significant estimates, including oil and natural gas revenues, accrued assets and liabilities, stock-based compensation, valuation of derivative instruments, deferred tax assets and liabilities, purchase price allocations and oil and natural gas reserves. The estimates of oil and natural gas reserves quantities and future net cash flows are the basis for the calculations of depletion and impairment of oil and natural gas properties, as well as estimates of asset retirement obligations and certain tax accruals. The Company’s oil and natural gas reserves estimates, which are inherently imprecise and based upon many factors that are beyond the Company’s control, including oil and natural gas prices, are prepared by the Company’s engineering staff in accordance with guidelines established by the Securities and Exchange Commission (“SEC”) and then audited for their reasonableness and conformance with SEC guidelines by Netherland, Sewell & Associates, Inc., independent reservoir engineers. While the Company believes its estimates are reasonable, changes in facts and assumptions or the discovery of new information may result in revised estimates. Actual results could differ from these estimates. Restricted Cash Restricted cash represents a portion of the cash associated with the Company’s less-than-wholly-owned subsidiaries, primarily San Mateo. By contractual agreement, the cash in the accounts held by the Company’s less-than-wholly-owned subsidiaries is not to be commingled with other Company cash and is to be used only to fund the capital expenditures and operations of these less-than-wholly-owned subsidiaries. Accounts Receivable The Company sells its operated oil, natural gas and natural gas liquid (“NGL”) production to various purchasers (see “—Revenues” below). In addition, the Company may participate with industry partners in the drilling, completion and operation of oil and natural gas wells. Substantially all of the Company’s accounts receivable are due from purchasers of oil, natural gas and NGLs, participants in oil and natural gas wells for which the Company serves as the operator, customers of San Mateo and Pronto or the Company’s derivative counterparties. Accounts receivable are typically due within 30 to 60 days of the production date and 30 days of the billing date and are stated at amounts due from purchasers and industry partners. Amounts are considered past due if they have been outstanding for 60 days or more. No interest is typically charged on past due amounts. The Company reviews its need for an allowance for doubtful accounts on a periodic basis and determines the allowance, if any, by considering the length of time past due, previous loss history, future net revenues associated with the debtor’s ownership interest in oil and natural gas properties operated by the Company and the debtor’s ability to pay its obligations, among other things. The Company has no allowance for doubtful accounts related to its accounts receivable for any reporting period presented. For the year ended December 31, 2022, three significant purchasers accounted for 70% of the Company’s total oil, natural gas and NGL revenues: Exxon Mobil Corporation (34%), Plains Marketing, L.P. (27%) and BP America Production Company (9%). For the year ended December 31, 2021, three significant purchasers accounted for 72% of the Company’s total oil, natural gas and NGL revenues: Exxon Mobil Corporation (33%), Plains Marketing, L.P. (29%) and BP America Production Company (10%). For the year ended December 31, 2020, two significant purchasers accounted for 65% of the Company’s total oil, natural gas and NGL revenues: Plains Marketing, L.P. (57%) and Exxon Mobil Corporation (8%). If the Company lost one or more of these significant purchasers and were unable to sell its production to other purchasers on terms it considers acceptable, it could materially and adversely affect the Company’s business, financial condition, results of operations and cash flows. At December 31, 2022, 2021 and 2020, approximately 29%, 39% and 35%, respectively, of the Company’s accounts receivable, including joint interest billings, related to these purchasers. Lease and Well Equipment Inventory Lease and well equipment inventory is stated at the lower of cost or net realizable value and consists entirely of materials or equipment scheduled for use in future well or midstream operations. Oil and Natural Gas Properties The Company uses the full-cost method of accounting for its investments in oil and natural gas properties. Under this method, all costs associated with the acquisition, exploration and development of oil and natural gas properties and reserves, including unproved and unevaluated property costs, are capitalized as incurred and accumulated in a single cost center representing the Company’s activities, which are undertaken exclusively in the United States. Such costs include lease acquisition costs, geological and geophysical expenditures, lease rentals on undeveloped properties, costs of drilling both productive and non-productive wells, capitalized interest on qualifying projects and general and administrative expenses directly related to acquisition, exploration and development activities, but do not include any costs related to production, selling or general corporate administrative activities. The Company capitalized $47.8 million, $38.4 million and $30.0 million of its general and administrative costs into oil and natural gas properties in 2022, 2021 and 2020, respectively. The Company capitalized $10.1 million, $4.8 million and $5.0 million of its interest expense into oil and natural gas properties for the years ended December 31, 2022, 2021 and 2020, respectively. Capitalized costs of oil and natural gas properties are amortized using the unit-of-production method based upon production and estimates of proved reserves quantities. For the years ended December 31, 2022, 2021 and 2020, the Company recorded depletion expense of $428.9 million, $310.1 million and $334.8 million, respectively. Unproved and unevaluated property costs are excluded from the amortization base used to determine depletion. Unproved and unevaluated properties are assessed for possible impairment on a periodic basis based upon changes in operating or economic conditions. This assessment includes consideration of the following factors, among others: the assignment of proved reserves, geological and geophysical evaluations, intent to drill, remaining lease term and drilling activity and results. Upon impairment, the costs of the unproved and unevaluated properties are immediately included in the amortization base. Exploratory dry holes are included in the amortization base immediately upon determination that the well is not productive. Sales of oil and natural gas properties are accounted for as adjustments to net capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between net capitalized costs and proved reserves of oil and natural gas. All costs related to production activities and maintenance and repairs are expensed as incurred. Significant workovers that increase the properties’ reserves are capitalized. Ceiling Test The net capitalized costs of oil and natural gas properties are limited to the lower of unamortized costs less related deferred income taxes or the cost center “ceiling.” The cost center ceiling is defined as the sum of: (a) the present value, discounted at 10%, of future net revenues of proved oil and natural gas reserves, reduced by the estimated costs of developing these reserves, plus (b) unproved and unevaluated property costs not being amortized, plus (c) the lower of cost or estimated fair value of unproved and unevaluated properties included in the costs being amortized, if any, less (d) any income tax effects related to the properties involved. Any excess of the Company’s net capitalized costs above the cost center ceiling as described above is charged to operations as a full-cost ceiling impairment. The Company’s derivative instruments are not considered in the ceiling test computations as the Company does not designate these instruments as hedge instruments for accounting purposes. The estimated present value of after-tax future net cash flows from proved oil and natural gas reserves is highly dependent upon the quantities of proved reserves, the estimation of which requires substantial judgment. The associated commodity prices and the applicable discount rate used in these estimates are in accordance with guidelines established by the SEC. Under these guidelines, oil and natural gas reserves are estimated using then-current operating and economic conditions, with no provision for price and cost changes in future periods except by contractual arrangements. Future net revenues are calculated using prices that represent the arithmetic averages of the first-day-of-the-month oil and natural gas prices for the previous 12-month period, and a 10% discount factor is used to determine the present value of future net revenues. For the period from January through December 2022, these average oil and natural gas prices were $90.15 per Bbl and $6.36 per MMBtu, respectively. For the period from January through December 2021, these average oil and natural gas prices were $63.04 per Bbl and $3.60 per MMBtu, respectively. For the period from January through December 2020, these average oil and natural gas prices were $36.04 per Bbl and $1.99 per MMBtu, respectively. In estimating the present value of after-tax future net cash flows from proved oil and natural gas reserves, the average oil prices were further adjusted by property for quality, transportation and marketing fees and regional price differentials, and the average natural gas prices were further adjusted by property for energy content, transportation and marketing fees and regional price differentials. During the years ended December 31, 2022 and 2021, the Company’s full-cost ceiling exceeded the net capitalized costs less related deferred income taxes. As a result, the Company recorded no impairment to its net capitalized costs during the years ended December 31, 2022 and 2021. For the year ended December 31, 2020, the Company’s net capitalized costs less related deferred income taxes exceeded the full-cost ceiling. As a result, the Company recorded an impairment charge of $684.7 million, exclusive of tax effect, to its consolidated statement of operations for the year ended December 31, 2020 with the related deferred income tax benefit recorded net of a valuation allowance (see Note 8). As a non-cash item, the full-cost ceiling impairment impacts the accumulated depletion and the net carrying value of the Company’s assets on its consolidated balance sheets, as well as the corresponding shareholders’ equity, but it has no impact on the Company’s net cash flows as reported. Changes in oil and natural gas production rates, oil and natural gas prices, reserves estimates, future development costs and other factors will determine the Company’s actual ceiling test computation and impairment analyses in future periods. Midstream Properties and Other Property and Equipment Midstream properties and other property and equipment are recorded at historical cost and include midstream equipment and facilities, including the Company’s pipelines, processing facilities and produced water disposal systems, and corporate assets, including furniture, fixtures, equipment, land and leasehold improvements. Midstream equipment and facilities are depreciated over a 30-year useful life using the straight-line, mid-month convention method. Leasehold improvements are depreciated over the lesser of their useful lives or the term of the lease. Software, furniture, fixtures and other equipment are depreciated over their useful life ( five The Company evaluates midstream properties and other property and equipment for potential impairment whenever events or changes in circumstances indicate that their carrying value may not be recoverable. The carrying amount of a long-lived asset is not recoverable when it exceeds the undiscounted sum of the future cash flows expected to result from the use and eventual disposition of the asset. Expected future cash flows represent management’s estimates based on reasonable and supportable assumptions. Gains and losses associated with the disposition of midstream properties and other property and equipment are recognized as a component of other income (expense) in the consolidated statements of operations. Asset Retirement Obligations The Company recognizes the fair value of an asset retirement obligation in the period in which it is incurred if a reasonable estimate of fair value can be made. The asset retirement obligation is recorded as a liability at its estimated present value, with an offsetting increase recognized in oil and natural gas properties, midstream properties or other property and equipment on the consolidated balance sheets. Periodic accretion of the discounted value of the estimated liability is recorded as an expense in the consolidated statements of operations. Derivative Financial Instruments From time to time, the Company uses derivative financial instruments to mitigate its exposure to commodity price risk associated with oil, natural gas and NGL prices. The Company’s derivative financial instruments are recorded on the consolidated balance sheets as either an asset or a liability measured at fair value. The Company has elected not to apply hedge accounting for its existing derivative financial instruments, and as a result, the Company recognizes the change in derivative fair value between reporting periods currently in its consolidated statements of operations. The fair value of the Company’s derivative financial instruments is determined using industry-standard models that consider various inputs including: (i) quoted forward prices for commodities, (ii) time value of money and (iii) current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Realized gains and losses from the settlement of derivative financial instruments and unrealized gains and unrealized losses from valuation changes in the remaining unsettled derivative financial instruments are reported as a component of revenues in the consolidated statements of operations. See Note 12 for additional information about the Company’s derivative instruments. Revenues The Company enters into contracts with customers to sell its oil and natural gas production. Revenue from these contracts is recognized when the Company’s performance obligations under these contracts are satisfied, which generally occurs with the transfer of control of the oil and natural gas to the purchaser. Control is generally considered transferred when the following criteria are met: (i) transfer of physical custody, (ii) transfer of title, (iii) transfer of risk of loss and (iv) relinquishment of any repurchase rights or other similar rights. Given the nature of the products sold, revenue is recognized at a point in time based on the amount of consideration the Company expects to receive in accordance with the price specified in the contract. Consideration under oil and natural gas marketing contracts is typically received from the purchaser one The majority of the Company’s oil marketing contracts transfer physical custody and title at or near the wellhead or a central delivery point, which is generally when control of the oil has been transferred to the purchaser. The majority of the oil produced is sold under contracts using market-based pricing, which price is then adjusted for differentials based upon delivery location and oil quality. To the extent the differentials are incurred at or after the transfer of control of the oil, the differentials are included in oil revenues on the statements of operations, as they represent part of the transaction price of the contract. If the differentials, or other related costs, are incurred prior to the transfer of control of the oil, those costs are included in production taxes, transportation and processing expenses on the Company’s consolidated statements of operations, as they represent payment for services performed outside of the contract with the customer. The Company’s natural gas is sold at the lease location, at the inlet or outlet of a natural gas processing plant or at an interconnect near a marketing hub following transportation from a processing plant. The majority of the Company’s natural gas is sold under fee-based contracts. When the natural gas is sold at the lease, the purchaser gathers the natural gas via pipeline to natural gas processing plants where, if necessary, NGLs are extracted. The NGLs and remaining residue gas are then sold by the purchaser, or if the Company elects to take in-kind the natural gas or the NGLs, the Company sells the natural gas or the NGLs to a third party. Under the fee-based contracts, the Company receives NGL and residue gas value, less the fee component, or is invoiced the fee component. To the extent control of the natural gas transfers upstream of the gathering and processing activities, revenue is recognized as the net amount received from the purchaser. To the extent that control transfers downstream of those services, revenue is recognized on a gross basis, and the related costs are included in production taxes, transportation and processing expenses on the Company’s consolidated statements of operations. The Company recognizes midstream services revenues at the time services have been rendered and the price is fixed and determinable. Third-party midstream services revenues are those revenues from midstream operations related to third parties, including working interest owners in the Company’s operated wells. All midstream services revenues related to the Company’s working interest are eliminated in consolidation. Since the Company has a right to payment from its customers in amounts that correspond directly to the value that the customer receives from the performance completed on each contract, the Company applies the practical expedient in Accounting Standards Update 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASC 606”) that allows recognition of revenue in the amount for which there is a right to invoice the customer without estimating a transaction price for each contract and allocating that transaction price to the performance obligations within each contract. The Company periodically enters into natural gas purchase transactions with third parties whereby the Company (i) purchases the third party’s natural gas and subsequently sells the natural gas to other purchasers or (ii) processes the third party’s natural gas at Pronto’s Marlan cryogenic natural gas processing plant in Eddy County, New Mexico or San Mateo’s Black River cryogenic natural gas processing plant in Eddy County, New Mexico (the “Black River Processing Plant”) and then purchases, and subsequently sells, the residue gas and NGLs to other purchasers. Revenues and expenses from these transactions are presented on a gross basis on the Company’s consolidated statements of operations as the Company acts as a principal in the transactions by assuming the risk and rewards of ownership, including credit risk, of the natural gas purchased and by assuming the responsibility to deliver and process the natural gas volumes to be sold. From time to time, the Company, as an owner of mineral interests, may enter into or extend a lease to a third-party lessee to develop the oil and natural gas attributable to certain of its mineral interests in return for a specified payment or lease bonus. In those instances, revenue is recognized in the period when the lease is signed and the Company has no further obligation to the lessee. The Company records these payments as “Lease bonus - mineral acreage” revenues on its consolidated statements of operations. The following table summarizes the Company’s total revenues and revenues from contracts with customers on a disaggregated basis for the years ended December 31, 2022, 2021 and 2020 (in thousands). Year Ended December 31, 2022 2021 2020 Revenues from contracts with customers $ 3,196,699 $ 1,862,075 $ 851,135 Lease bonus - mineral acreage — — 4,062 Realized (loss) gain on derivatives (157,483) (220,105) 38,937 Unrealized gain (loss) on derivatives 18,809 21,011 (32,008) Total revenues $ 3,058,025 $ 1,662,981 $ 862,126 Year Ended December 31, 2022 2021 2020 Oil revenues $ 2,113,606 $ 1,205,608 $ 595,507 Natural gas revenues 792,132 494,934 148,954 Third-party midstream services revenues 90,606 75,499 64,932 Sales of purchased natural gas 200,355 86,034 41,742 Total revenues from contracts with customers $ 3,196,699 $ 1,862,075 $ 851,135 The Company does not disclose the value of unsatisfied performance obligations under its contracts with customers as it applies the practical expedient in accordance with ASC 606. The expedient, as described in ASC 606-10-50-14(a), applies to variable consideration that is recognized as control of the product is transferred to the customer. Since each unit of product represents a separate performance obligation, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required. Stock-Based Compensation The Company may grant equity-based and liability-based common stock, stock options, restricted stock, restricted stock units, performance stock units and other awards permitted under any long-term incentive plan of the Company then in effect to members of its Board of Directors and certain employees, contractors and advisors. All equity-based awards are measured at fair value on the date of grant and are recognized on a straight-line basis over the awards’ vesting periods as either a component of general and administrative expenses in the consolidated statements of operations or capitalized in accordance with the Company’s policy on capitalizing general and administrative expenses for employees involved in acquisition, exploration and development activities. Awards that are expected to be settled in cash are liability-based awards, which are measured at fair value at each reporting date and are recognized over the awards’ vesting periods either as a component of general and administrative expenses in the consolidated statements of operations or capitalized in accordance with the Company’s policy on capitalizing general and administrative expenses for employees involved in acquisition, exploration and development activities. The Company uses the Black Scholes Merton option pricing model to measure the fair value of stock options and the Monte Carlo simulation method to measure the fair value of performance units. The closing price of Matador’s common stock on the grant date is used to measure the fair value of restricted stock and restricted stock unit awards granted under the 2012 Long-Term Incentive Plan (as subsequently amended and restated, the “2012 Incentive Plan”), while the closing price of Matador’s common stock on the trading day prior to the grant date is used to measure the fair value of restricted stock and restricted stock unit awards granted under the 2019 Long-Term Incentive Plan (the “2019 Incentive Plan”). The Company’s consolidated statements of operations for the years ended December 31, 2022, 2021 and 2020 include an equity-based compensation (non-cash) expense of $15.1 million, $9.0 million and $13.6 million, respectively. This equity-based compensation expense includes common stock issuances and restricted stock units expense totaling $1.0 million, $0.9 million and $1.0 million for the years ended December 31, 2022, 2021 and 2020, respectively, paid to independent members of the Board of Directors and advisors as compensation for their services to the Company. The Company’s consolidated statements of operations for the years ended December 31, 2022, 2021 and 2020 also include expenses of $31.9 million, $20.4 million and $4.0 million, respectively, related to liability-based restricted stock awards expected to be settled in cash. Income Taxes The Company accounts for income taxes using the asset and liability approach for financial accounting and reporting. The Company evaluates the probability of realizing the future benefits of its deferred tax assets and records a valuation allowance for the portion of any deferred tax assets when it is more likely than not that the benefit from the deferred tax asset will not be realized. The Company recognizes the tax benefit of an uncertain tax position only if it is more likely than not that the tax position will be sustained upon examination by the taxing authorities based on the technical merits of the position. For tax positions meeting the more likely than not threshold, the amount recognized in the financial statements is the benefit that has a greater than 50% likelihood of being realized upon ultimate settlement with the relevant tax authority. At December 31, 2022, 2021 and 2020, the Company had not established any reserves for, nor recorded any unrecognized tax benefits related to, uncertain tax positions. When necessary, the Company would include interest assessed by taxing authorities in “Interest expense” and penalties related to income taxes in “Other expense” on its consolidated statements of operations. The Company did not record any interest or penalties related to income taxes for the years ended December 31, 2022, 2021 and 2020. Allocation of Purchase Price in Business Combinations As part of the Company’s business strategy, it periodically pursues the acquisition of midstream assets and oil and natural gas properties. The purchase price in a business combination is allocated to the assets acquired and liabilities assumed based on their fair values as of the acquisition date, which may occur many months after the announcement date. Therefore, while the consideration to be paid may be fixed, the fair value of the assets acquired and liabilities assumed is subject to change during the period between the announcement date and the acquisition date. The most significant estimates in the allocation typically relate to the value assigned to proved oil and natural gas reserves and unproved and unevaluated properties. As the allocation of the purchase price is subject to significant estimates and subjective judgments, the accuracy of this assessment is inherently uncertain. Earnings Per Common Share The Company reports basic earnings attributable to Matador Resources Company shareholders per common share, which excludes the effect of potentially dilutive securities, and diluted earnings attributable to Matador Resources Company shareholders per common share, which includes the effect of all potentially dilutive securities, unless their impact is anti-dilutive. The following are reconciliations of the numerators and denominators used to compute the Company’s basic and diluted earnings per common share as reported for the years ended December 31, 2022, 2021 and 2020 (in thousands, except per share data). Year Ended December 31, 2022 2021 2020 Net income (loss) attributable to Matador Resources Company shareholders — numerator $ 1,214,206 $ 584,968 $ (593,205) Weighted average common shares outstanding — denominator Basic 118,122 116,999 116,068 Dilutive effect of options and restricted stock units 2,009 2,164 — Diluted weighted average common shares outstanding 120,131 119,163 116,068 Earnings (loss) per common share attributable to Matador Resources Company shareholders Basic $ 10.28 $ 5.00 $ (5.11) Diluted $ 10.11 $ 4.91 $ (5.11) A total of 2.5 million options to purchase shares of Matador’s common stock were excluded from the diluted weighted average common shares outstanding for the year ended December 31, 2020 because their effects were anti-dilutive. Additionally, 0.7 million restricted shares, which are participating securities, were excluded from the calculations above for the year ended December 31, 2020 as the security holders do not have the obligation to share in the losses of the Company. Credit Risk The Company’s cash is held in financial institutions and at times these amounts exceed the insurance limits of the Federal Deposit Insurance Corporation. Management believes, however, that the Company’s counterparty risks are minimal based on the reputation and history of the institutions selected. The Company uses derivative financial instruments to mitigate its exposure to oil, natural gas and NGL price volatility. These transactions expose the Company to potential credit risk from its counterparties. The Company manages counterparty credit risk through established internal derivatives policies that are reviewed on an ongoing basis. Additionally, the Company’s commodity derivative contract at December 31, 2022 was with PNC Bank, which is a lender under the Company’s reserves-based revolving credit agreement. Accounts receivable constitute the principal component of additional credit risk to which the Company may be exposed. The Company attempts to minimize credit risk exposure to counterparties by monitoring the financial condition and payment history of its purchasers and joint interest partners.

Property and Equipment

Property and Equipment	12 Months Ended
Property and Equipment	Dec. 31, 2022
Property, Plant and Equipment [Abstract]
PROPERTY AND EQUIPMENT	The following table presents a summary of the Company’s property and equipment balances as of December 31, 2022 and 2021 (in thousands). December 31, 2022 2021 Oil and natural gas properties Evaluated (subject to amortization) $ 6,862,455 $ 6,007,325 Unproved and unevaluated (not subject to amortization) 977,502 964,714 Total oil and natural gas properties 7,839,957 6,972,039 Accumulated depletion (4,362,292) (3,933,355) Net oil and natural gas properties 3,477,665 3,038,684 Midstream properties Midstream equipment and facilities 1,057,668 900,979 Accumulated depreciation (126,706) (92,574) Net midstream properties 930,962 808,405 Other property and equipment Furniture, fixtures and other equipment 13,257 10,923 Software 8,225 8,225 Leasehold improvements 11,365 10,975 Total other property and equipment 32,847 30,123 Accumulated depreciation (23,277) (20,527) Net other property and equipment 9,570 9,596 Net property and equipment $ 4,418,197 $ 3,856,685 The following table provides a breakdown of the Company’s unproved and unevaluated property costs not subject to amortization as of December 31, 2022 and the year in which these costs were incurred (in thousands). Description 2022 2021 2020 2019 2018 and prior Total Costs incurred for Property acquisition $ 97,748 $ 110,077 $ 40,355 $ 40,140 $ 606,740 $ 895,060 Exploration wells 32,364 942 354 802 36 34,498 Development wells 42,543 1,641 1,245 2,506 9 47,944 Total $ 172,655 $ 112,660 $ 41,954 $ 43,448 $ 606,785 $ 977,502 Property acquisition costs are costs incurred to purchase, lease or otherwise acquire oil and natural gas properties, but may also include broker and legal expenses, geological and geophysical expenses and capitalized internal costs associated with developing oil and natural gas prospects on these properties. Property acquisition costs are transferred into the amortization base on an ongoing basis as these properties are evaluated and proved reserves are established or impairment is determined. Unproved and unevaluated properties are assessed for possible impairment on a periodic basis based upon changes in operating or economic conditions. Property acquisition costs incurred that remain in unproved and unevaluated property at December 31, 2022 are related to the Company’s leasehold and mineral acquisitions in the Delaware Basin in Southeast New Mexico and West Texas. These costs are associated with acreage for which proved reserves have yet to be assigned. A significant portion of these costs are associated with properties that are held by production or have automatic lease renewal options. As the Company drills wells and assigns proved reserves to these properties or determines that certain portions of this acreage, if any, cannot be assigned proved reserves, portions of these costs are transferred to the amortization base. Costs excluded from amortization also include those costs associated with exploration and development wells in progress or awaiting completion at year-end. These costs are transferred into the amortization base on an ongoing basis as these wells are completed and proved reserves are established or confirmed. These costs totaled $82.4 million at December 31, 2022. Of this total, $34.5 million was associated with exploration wells and $47.9 million was associated with development wells. The

Leases

Leases	12 Months Ended
Leases	Dec. 31, 2022
Leases [Abstract]
Leases	LEASES The Company determines if an arrangement is a lease at inception of the contract. If an arrangement is a lease, the present value of the related lease payments is recorded as a liability, and an equal amount is capitalized as a right of use asset on the Company’s consolidated balance sheets. The Company elected to include payments for non-lease components associated with certain leases when determining the present value of the lease payments. Right of use 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. The Company’s estimated incremental borrowing rate, determined at the lease commencement date using the Company’s average secured borrowing rate, is used to calculate present value. The weighted average estimated incremental borrowing rates used for the year ended December 31, 2022 were 3.68% and 4.20% for operating leases and financing leases, respectively. For these purposes, the lease term includes options to extend the lease when it is reasonably certain that the Company will exercise such option. Leases with terms of 12 months or less at inception are not recorded on the consolidated balance sheets unless there is a significant cost to terminate the lease, including the cost of removal of the leased asset. As the Company is the responsible party under these arrangements, the Company records the resulting assets and liabilities on a gross basis in its consolidated balance sheets. The following table presents supplemental consolidated statement of operations information related to lease expenses, on a gross basis, for the years ended December 31, 2022 and 2021, respectively (in thousands). Lease payments represent gross payments to vendors, which, for certain of the Company’s operating assets, are partially offset by amounts received from other working interest owners in the Company’s operated wells. Year Ended December 31, 2022 2021 Operating leases Lease operating $ 15,970 $ 11,393 Plant and other midstream services 285 36 General and administrative 3,266 3,645 Total operating leases (1) 19,521 15,074 Short-term leases Lease operating 17,437 11,234 Plant and other midstream services 4,359 4,037 General and administrative 34 37 Total short-term leases (2)(3) 21,830 15,308 Financing leases Depreciation of assets 571 566 Interest on lease liabilities 143 138 Total financing leases 714 704 Total lease expense $ 42,065 $ 31,086 _____________________ (1) Does not include gross payments related to drilling rig leases of $58.7 million and $31.9 million for the years ended December 31, 2022 and 2021, respectively, that were capitalized and recorded in “Oil and natural gas properties, full-cost method” in the consolidated balance sheets at December 31, 2022 and 2021, respectively. (2) These costs are related to leases that are not recorded as right of use assets or lease liabilities in the consolidated balance sheets as they are short-term leases. (3) Does not include gross payments related to short-term drilling rig leases and other equipment rentals of $101.5 million and $61.7 million for the years ended December 31, 2022 and 2021, respectively, that were capitalized and recorded in “Oil and natural gas properties, full-cost method” in the consolidated balance sheets at December 31, 2022 and 2021, respectively. The following table presents supplemental consolidated balance sheet information related to leases as of December 31, 2022 and 2021, respectively (in thousands). December 31, 2022 2021 Operating leases Other long-term assets $ 58,798 $ 29,519 Other current liabilities $ (43,921) $ (19,649) Other long-term liabilities (19,532) (15,340) Total operating lease liabilities $ (63,453) $ (34,989) Financing leases Other property and equipment, at cost $ 7,425 $ 5,914 Accumulated depreciation (4,470) (3,485) Net property and equipment $ 2,955 $ 2,429 Other current liabilities $ (685) $ (378) Other long-term liabilities (630) (45) Total financing lease liabilities $ (1,315) $ (423) The following table presents supplemental consolidated cash flow information related to lease payments for the years ended December 31, 2022 and 2021, respectively (in thousands). Year Ended December 31, 2022 2021 Cash paid related to lease liabilities Operating cash payments for operating leases $ 19,290 $ 14,430 Investing cash payments for operating leases $ 58,693 $ 31,967 Financing cash payments for financing leases $ 620 $ 629 Right of use assets obtained in exchange for lease obligations entered into during the period Operating leases $ 80,254 $ 18,454 Financing leases $ 1,511 $ 2,241 The following table presents the maturities of lease liabilities at December 31, 2022 (in years). Weighted-Average Remaining Lease Term December 31, 2022 Operating leases 1.8 Financing leases 2.4 The following table presents a schedule of future minimum lease payments required under all lease agreements as of December 31, 2022 (in thousands). December 31, 2022 Operating Leases Financing Leases 2023 $ 43,921 $ 685 2024 12,443 541 2025 6,218 309 2026 2,708 — 2027 572 — Thereafter — — Total lease payments 65,862 1,535 Less imputed interest (2,409) (220) Total lease obligations 63,453 1,315 Less current obligations (43,921) (685) Long-term lease obligations $ 19,532 $ 630
Leases	LEASES The Company determines if an arrangement is a lease at inception of the contract. If an arrangement is a lease, the present value of the related lease payments is recorded as a liability, and an equal amount is capitalized as a right of use asset on the Company’s consolidated balance sheets. The Company elected to include payments for non-lease components associated with certain leases when determining the present value of the lease payments. Right of use 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. The Company’s estimated incremental borrowing rate, determined at the lease commencement date using the Company’s average secured borrowing rate, is used to calculate present value. The weighted average estimated incremental borrowing rates used for the year ended December 31, 2022 were 3.68% and 4.20% for operating leases and financing leases, respectively. For these purposes, the lease term includes options to extend the lease when it is reasonably certain that the Company will exercise such option. Leases with terms of 12 months or less at inception are not recorded on the consolidated balance sheets unless there is a significant cost to terminate the lease, including the cost of removal of the leased asset. As the Company is the responsible party under these arrangements, the Company records the resulting assets and liabilities on a gross basis in its consolidated balance sheets. The following table presents supplemental consolidated statement of operations information related to lease expenses, on a gross basis, for the years ended December 31, 2022 and 2021, respectively (in thousands). Lease payments represent gross payments to vendors, which, for certain of the Company’s operating assets, are partially offset by amounts received from other working interest owners in the Company’s operated wells. Year Ended December 31, 2022 2021 Operating leases Lease operating $ 15,970 $ 11,393 Plant and other midstream services 285 36 General and administrative 3,266 3,645 Total operating leases (1) 19,521 15,074 Short-term leases Lease operating 17,437 11,234 Plant and other midstream services 4,359 4,037 General and administrative 34 37 Total short-term leases (2)(3) 21,830 15,308 Financing leases Depreciation of assets 571 566 Interest on lease liabilities 143 138 Total financing leases 714 704 Total lease expense $ 42,065 $ 31,086 _____________________ (1) Does not include gross payments related to drilling rig leases of $58.7 million and $31.9 million for the years ended December 31, 2022 and 2021, respectively, that were capitalized and recorded in “Oil and natural gas properties, full-cost method” in the consolidated balance sheets at December 31, 2022 and 2021, respectively. (2) These costs are related to leases that are not recorded as right of use assets or lease liabilities in the consolidated balance sheets as they are short-term leases. (3) Does not include gross payments related to short-term drilling rig leases and other equipment rentals of $101.5 million and $61.7 million for the years ended December 31, 2022 and 2021, respectively, that were capitalized and recorded in “Oil and natural gas properties, full-cost method” in the consolidated balance sheets at December 31, 2022 and 2021, respectively. The following table presents supplemental consolidated balance sheet information related to leases as of December 31, 2022 and 2021, respectively (in thousands). December 31, 2022 2021 Operating leases Other long-term assets $ 58,798 $ 29,519 Other current liabilities $ (43,921) $ (19,649) Other long-term liabilities (19,532) (15,340) Total operating lease liabilities $ (63,453) $ (34,989) Financing leases Other property and equipment, at cost $ 7,425 $ 5,914 Accumulated depreciation (4,470) (3,485) Net property and equipment $ 2,955 $ 2,429 Other current liabilities $ (685) $ (378) Other long-term liabilities (630) (45) Total financing lease liabilities $ (1,315) $ (423) The following table presents supplemental consolidated cash flow information related to lease payments for the years ended December 31, 2022 and 2021, respectively (in thousands). Year Ended December 31, 2022 2021 Cash paid related to lease liabilities Operating cash payments for operating leases $ 19,290 $ 14,430 Investing cash payments for operating leases $ 58,693 $ 31,967 Financing cash payments for financing leases $ 620 $ 629 Right of use assets obtained in exchange for lease obligations entered into during the period Operating leases $ 80,254 $ 18,454 Financing leases $ 1,511 $ 2,241 The following table presents the maturities of lease liabilities at December 31, 2022 (in years). Weighted-Average Remaining Lease Term December 31, 2022 Operating leases 1.8 Financing leases 2.4 The following table presents a schedule of future minimum lease payments required under all lease agreements as of December 31, 2022 (in thousands). December 31, 2022 Operating Leases Financing Leases 2023 $ 43,921 $ 685 2024 12,443 541 2025 6,218 309 2026 2,708 — 2027 572 — Thereafter — — Total lease payments 65,862 1,535 Less imputed interest (2,409) (220) Total lease obligations 63,453 1,315 Less current obligations (43,921) (685) Long-term lease obligations $ 19,532 $ 630

Asset Retirement Obligations

Asset Retirement Obligations	12 Months Ended
Asset Retirement Obligations	Dec. 31, 2022
Asset Retirement Obligation Disclosure [Abstract]
ASSET RETIREMENT OBLIGATIONS	ASSET RETIREMENT OBLIGATIONS The Company’s asset retirement obligations primarily relate to future costs associated with plugging and abandonment of its oil, natural gas and salt water disposal wells, removal of pipelines, equipment and facilities from leased acreage and returning such land to its original condition. The amounts recognized are based on numerous estimates and assumptions, including future retirement costs, future recoverable quantities of oil and natural gas, future inflation rates and the Company’s credit-adjusted risk-free interest rate. Revisions to the liability can occur due to changes in these estimates and assumptions or if federal or state regulators enact new plugging and abandonment requirements. At the time of the actual plugging and abandonment of its oil and natural gas wells, the Company includes any gain or loss associated with the operation in the amortization base to the extent the actual costs are different from the estimated liability. The following table summarizes the changes in the Company’s asset retirement obligations for the years ended December 31, 2022 and 2021 (in thousands). Year Ended December 31, 2022 2021 Beginning asset retirement obligations $ 41,959 $ 38,542 Liabilities incurred during period 4,069 2,294 Liabilities settled during period (1,198) (151) Revisions in estimated cash flows 10,794 86 Divestitures during the period (4,304) (880) Accretion expense 2,421 2,068 Ending asset retirement obligations 53,741 41,959 Less: current asset retirement obligations (1) (756) (270) Long-term asset retirement obligations $ 52,985 $ 41,689 __________________ (1) Included in “Accrued liabilities” in the Company’s consolidated balance sheets at December 31, 2022 and 2021.

Business Combinations and Dives

Business Combinations and Divestitures	12 Months Ended
Business Combinations and Divestitures	Dec. 31, 2022
Business Combinations [Abstract]
BUSINESS COMBINATIONS AND DIVESTITURES	Business Combinations On December 14, 2021, the Company completed an acquisition of assets from a private operator. This acquisition was accounted for as a business combination in accordance with ASC Topic 805, which requires the assets acquired and liabilities assumed to be recorded at fair value as of the respective acquisition date. The Company obtained certain oil and natural gas producing properties and undeveloped acreage located in Lea and Eddy Counties, New Mexico, strategically located primarily within the Company’s existing acreage in its Ranger and Arrowhead asset areas. As consideration for the business combination, the Company paid approximately $161.7 million in cash, subject to certain customary post-closing working capital adjustments, including adjusting for production, revenues, operating expenses and capital expenditures from August 1, 2021 to closing. In addition, the Company increased the purchase price by $5.0 million for each quarter during 2022 in which the average oil price, as defined in the purchase and sale agreement, was greater than $75.00 per barrel. The Company recorded this contingent consideration at fair value on the date of the business combination and recorded the change in the fair value in future periods as “Other income (expense)” in its consolidated statements of operations. The change in the fair value of the contingent consideration included in “Other expense” during the years ended December 31, 2022 and 2021 was $11.8 million and $1.5 million, respectively. During the year ended December 31, 2022, the Company paid $15.0 million in cash related to this contingent consideration. The remaining payment of $5.0 million was made in the first quarter of 2023. The Company used the Monte Carlo simulation method to measure the fair value of the contingent consideration, which has unobservable inputs and is thus classified at Level 3 in the fair value hierarchy (see Note 13 for discussion of the fair value hierarchy). The allocation of the consideration given related to this business combination was as follows (in thousands), which the Company considered to be final as of September 30, 2022. Consideration given Allocation Cash $161,680 Working capital adjustments (4,444) Fair value of contingent consideration at December 14, 2021 6,718 Total consideration given $163,954 Allocation of purchase price Oil and natural gas properties Evaluated $139,312 Unproved and unevaluated 32,260 Accrued liabilities (360) Advances from joint interest owners (6,865) Asset retirement obligations (393) Net assets acquired $163,954 On June 30, 2022, the Company acquired a cryogenic gas processing plant, three compressor stations and approximately 45 miles of natural gas gathering pipelines in Lea and Eddy Counties, New Mexico as part of the acquisition (the “Pronto Acquisition”) of a wholly-owned subsidiary of Summit Midstream Partners, LP that was subsequently renamed Pronto. This acquisition was also accounted for as a business combination in accordance with ASC Topic 805. In addition, the Company assumed certain takeaway capacity on a Federal Energy Regulatory Commission regulated natural gas pipeline. As consideration for the business combination, the Company paid approximately $77.8 million in cash, subject to certain customary post-closing purchase price adjustments. The pro forma impact of this business combination to revenues and net income for 2022 would not be material to the Company’s 2022 revenues and net income as reported. The allocation of the consideration given related to this business combination was as follows (in thousands), which the Company considered to be final as of December 31, 2022. Consideration given Allocation Total cash consideration given $ 77,828 Allocation of purchase price Cash acquired $ 2,012 Property, plant & equipment 74,100 Accounts receivable 6,093 Other assets 296 Accrued liabilities (4,673) Net assets acquired $ 77,828 Joint Ventures At December 31, 2022, the Company owned 51% of San Mateo, a midstream joint venture with a subsidiary of Five Point Energy LLC (“Five Point”) in portions of Eddy County, New Mexico and Loving County, Texas. At December 31, 2022, Five Point owned the remaining 49% of San Mateo. The midstream assets include (i) the Black River Processing Plant, (ii) 15 salt water disposal wells and associated commercial salt water disposal facilities and (iii) approximately 415 miles of oil gathering and transportation pipelines, natural gas gathering pipelines and produced water pipelines. The Company operates San Mateo, and San Mateo is consolidated in the Company’s financial statements, with Five Point’s interest being accounted for as a non-controlling interest. As part of the joint venture agreements with Five Point, the Company had the potential to earn two different sets of performance incentives. These performance incentives are recorded as additional contributions related to the formation of San Mateo as they are received. Beginning in 2017, the Company had the potential to earn up to $73.5 million in performance incentives related to the Company’s performance in its Rustler Breaks asset area in Eddy County and its Wolf asset area in Loving County over a five-year period, which in October 2020 was extended by an additional year to January 31, 2023. At February 21, 2023, the Company had earned all of the potential $73.5 million in performance incentives. Five Point had paid $14.7 million in performance incentives in each of the first quarters of 2018, 2019, 2020 and 2021 and the remaining $14.7 million in performance incentives is expected to be paid during the first quarter of 2023. Beginning in 2019, the Company had the potential to earn up to $150.0 million in additional deferred performance incentives in its Stebbins area and surrounding leaseholds in the southern portion of its Arrowhead asset area (the “Greater Stebbins Area”) and Stateline asset area through mid-2024, of which the Company has earned $62.2 million, plus additional performance incentives for securing volumes from third-party customers. During the years ended December 31, 2022 and 2021, Five Point paid $28.3 million and $33.9 million in these additional performance incentives. Both of these performance incentives are recorded when received, net of the $5.9 million and $3.6 million deferred tax impact to Matador for the years ended December 31, 2022 and 2021, respectively, in “Additional paid-in-capital” in the Company’s consolidated balance sheets. The Company dedicated to San Mateo its current and certain future leasehold interests in the Rustler Breaks and Wolf asset areas and acreage in the Greater Stebbins Area and Stateline asset area pursuant to 15-year, fixed-fee oil transportation, oil, natural gas and produced water gathering and produced water disposal agreements. In addition, the Company dedicated to San Mateo its current and certain future leasehold interests in the Rustler Breaks asset area and acreage in the Greater Stebbins Area and the Stateline asset area pursuant to 15-year, fixed-fee natural gas processing agreements (see Note 14). During the years ended December 31, 2022, 2021 and 2020, San Mateo distributed $89.5 million, $64.5 million and $47.4 million respectively, to the Company and $86.0 million, $62.0 million and $45.6 million, respectively, to Five Point. During the years ended December 31, 2022 and 2021, neither the Company nor Five Point contributed cash to San Mateo. During the year ended December 31, 2020, the Company contributed $75.0 million and Five Point contributed $119.7 million of cash to San Mateo, of which $23.1 million was paid to carry Matador’s proportionate interest in San Mateo Midstream II, LLC (“San Mateo II”). Five Point agreed to carry a portion of Matador’s proportionate interest as part of the formation agreement for San Mateo II. The amount that Five Point paid to carry Matador’s proportionate interest in San Mateo was recorded in “Additional paid-in capital” in the Company’s consolidated balance sheets at December 31, 2020, net of the $4.8 million deferred tax impact to Matador related to this equity contribution. San Mateo II was merged with and into San Mateo effective October 1, 2020. Divestitures During 2022 and 2021, the Company converted approximately $46.5 million and $4.2 million, respectively, of non-core assets to cash. These properties were primarily located in South Texas and Northwest Louisiana.

Debt

Debt	12 Months Ended
Debt	Dec. 31, 2022
Debt Disclosure [Abstract]
DEBT	DEBT At December 31, 2022, the Company had (i) $699.2 million of outstanding senior notes due 2026, (ii) no borrowings outstanding under its reserves-based revolving credit facility and (iii) approximately $45.6 million in outstanding letters of credit issued pursuant to its revolving credit facility. During the first quarter of 2022, the Company’s approximately $7.5 million unsecured U.S. Small Business Administration loan, which was issued through Iberiabank in April 2020 as part of the Paycheck Protection Program, was forgiven in full under the terms of the loan agreement and recorded as a gain on the extinguishment of debt within “Other expense” on the unaudited consolidated statement of operations. During the year ended December 31, 2022, the Company repurchased an aggregate principal amount of $350.8 million of its Notes for $344.3 million. At December 31, 2022, San Mateo had $465.0 million in borrowings outstanding under its revolving credit facility and approximately $9.0 million in outstanding letters of credit issued pursuant to its revolving credit facility. Credit Agreements MRC Energy Company On November 18, 2021, the Company entered into its Fourth Amended and Restated Credit Agreement with the lenders party thereto, led by Royal Bank of Canada (“RBC”) as administrative agent (the “Credit Agreement”). MRC Energy Company (“MRC”), a subsidiary of Matador that directly or indirectly holds the ownership interests in the Company’s other operating subsidiaries, other than its less-than-wholly-owned subsidiaries, is the borrower under the Credit Agreement. Borrowings are secured by mortgages on at least 85% of MRC’s and the Restricted Subsidiaries’ (as defined in the Credit Agreement) proved oil and natural gas properties and by the equity interests of certain of MRC’s wholly-owned subsidiaries, which are also guarantors. San Mateo and its subsidiaries and Pronto are not guarantors of the Credit Agreement. In addition, all obligations under the Credit Agreement are guaranteed by Matador, the parent corporation. Various commodity hedging agreements with certain of the lenders under the Credit Agreement (or affiliates thereof) are also secured by the collateral of and guaranteed by certain eligible subsidiaries of MRC. The Credit Agreement matures on October 31, 2026 or, if earlier, the date that is 180 days prior to the earliest stated redemption date of any senior notes of the Company with an outstanding principal balance in excess of $25.0 million. The borrowing base under the Credit Agreement is determined semi-annually as of May 1 and November 1 by the lenders based primarily on the estimated value of the Company’s proved oil and natural gas reserves at December 31 and June 30 of each year, respectively. The Company and the lenders may each request an unscheduled redetermination of the borrowing base once between scheduled redetermination dates. In April 2022, the lenders completed their review of the Company’s proved oil and natural gas reserves, and, as a result, the borrowing base was increased from $1.35 billion to $2.00 billion, the borrowing commitment was increased from $700.0 million to $775.0 million and the maximum facility amount remained $1.50 billion. In addition, the terms of the Credit Agreement were amended to increase the sublimit for issuances of letters of credit under the Credit Agreement from $50 million to $100 million and replace the London Interbank Offered Rate (“LIBOR”) interest rate benchmark with a secured overnight financing rate administered by the Federal Reserve Bank of New York (“Adjusted Term SOFR”) (as defined in the Credit Agreement) interest rate benchmark. This April 2022 redetermination constituted the regularly scheduled May 1 redetermination. In November 2022, the lenders completed their review of the Company’s proved oil and natural gas reserves, and, as a result, the borrowing base was increased from $2.00 billion to $2.25 billion. The Company elected to keep the borrowing commitment at $775.0 million, and the maximum facility amount remained $1.50 billion. Borrowings under the Credit Agreement are limited to the lowest of the borrowing base, the maximum facility amount and the elected borrowing commitment (subject to compliance with the covenants noted below). In the event of an increase in the elected commitment, the Company is required to pay a fee to the lenders equal to a percentage of the amount of the increase, which is determined based on market conditions at the time of the increase. If, upon a redetermination of the borrowing base, the borrowing base were to be less than the outstanding borrowings under the Credit Agreement at such time, the Company would be required to provide additional collateral satisfactory in nature and value to the lenders to increase the borrowing base to an amount sufficient to cover such excess or to repay the deficit in equal installments over a period of six months. Total deferred loan costs were $3.2 million at December 31, 2022, and these costs are being amortized over the term of the Credit Agreement. At December 31, 2022, the Company had no borrowings outstanding under the Credit Agreement and approximately $45.6 million in outstanding letters of credit issued pursuant to the Credit Agreement. If the Company were to borrow funds under the Credit Agreement, the applicable margin that would be added to Adjusted Term SOFR would have been 1.75% at December 31, 2022. After giving effect to the amendment to the Credit Agreement, the applicable interest rate margin for borrowings under the Credit Agreement ranges from 1.75% to 2.75% per annum for borrowings bearing interest with reference to the Adjusted Term SOFR and from 0.75% to 1.75% per annum for borrowings bearing interest with reference to the Alternate Base Rate (as defined in the Credit Agreement), in each case depending on the level of borrowings under the Credit Agreement. In addition, the Adjusted Term SOFR includes a credit spread adjustment of 0.10% per annum for all interest periods. The interest period for Adjusted Term SOFR borrowings may be one, three or six months as designated by MRC. If MRC has outstanding borrowings under the Credit Agreement and interest rates increase, so will MRC’s interest costs, which may have a material adverse effect on the Company’s results of operations and financial condition. A commitment fee of 0.375% to 0.50% per annum, depending on the level of borrowings under the Credit Agreement, is also paid quarterly in arrears. The Company includes this commitment fee, any amortization of deferred financing costs (including origination, borrowing base increase and amendment fees) and annual agency fees, if any, as interest expense and in its interest rate calculations and related disclosures. The Credit Agreement requires the Company to maintain (i) a current ratio, which is defined as (x) total consolidated current assets plus the unused availability under the Credit Agreement divided by (y) total consolidated current liabilities less current maturities under the Credit Agreement, of not less than 1.0 to 1.0 at the end of each fiscal quarter and (ii) a debt to EBITDA ratio, which is defined as debt outstanding (net of up to $75 million of unrestricted cash and cash equivalents) divided by a rolling four quarter EBITDA calculation, of 3.50 to 1.0 or less at the end of each fiscal quarter. Subject to certain exceptions, the Credit Agreement contains various covenants that limit MRC’s and its Restricted Subsidiaries’ (as defined in the Credit Agreement) ability to take certain actions, including, but not limited to, the following: • incur indebtedness or grant liens on any of its assets; • enter into commodity hedging agreements or interest rate agreements; • declare or pay dividends, distributions or redemptions; • merge or consolidate; • make any loans or investments; • engage in transactions with affiliates; • engage in certain asset dispositions, including a sale of all or substantially all of MRC’s assets; and • take certain actions with respect to the Company’s senior unsecured notes. If an event of default exists under the Credit Agreement, the lenders will be able to terminate their commitments, accelerate the maturity of the borrowings and exercise other rights and remedies. Events of default include, but are not limited to, the following events: • failure to pay any principal on the outstanding borrowings when due or any interest on the outstanding borrowings, any reimbursement obligation under any letter of credit or any fees or other amounts within certain grace periods; • failure to perform or otherwise comply with the covenants and obligations in the Credit Agreement or other loan documents, subject, in certain instances, to certain grace periods; • bankruptcy or insolvency events involving the Company or any of the Restricted Subsidiaries; and • a change of control, as defined in the Credit Agreement. The Company believes that it was in compliance with the terms of the Credit Agreement at December 31, 2022. San Mateo Midstream, LLC On December 19, 2018, San Mateo entered into a credit facility with the lenders party thereto, currently led by Truist Bank as administrative agent (the “San Mateo Credit Facility”). In December 2022, the lenders under the San Mateo Credit Facility extended the maturity of the facility from December 19, 2023 to December 9, 2026 and increased the lender commitments from $450.0 million to $485.0 million. In addition, the lenders agreed to refresh the San Mateo Credit Facility’s accordion feature, which could expand lender commitments to up to $735.0 million. The San Mateo Credit Facility is non-recourse with respect to Matador and its wholly-owned subsidiaries, but is guaranteed by San Mateo’s subsidiaries and secured by substantially all of San Mateo’s assets, including real property. Total deferred loan costs were $3.9 million at December 31, 2022, and these costs are being amortized over the term of the San Mateo Credit Facility. San Mateo’s effective interest rate under the San Mateo Credit Facility was 6.7% at December 31, 2022. At December 31, 2022, San Mateo had $465.0 million in borrowings outstanding under the San Mateo Credit Facility and $9.0 million in outstanding letters of credit issued pursuant to the San Mateo Credit Facility. Between December 31, 2022 and February 21, 2023, San Mateo repaid $30.0 million of borrowings outstanding under the San Mateo Credit Facility. Borrowings under the San Mateo Credit Facility may be in the form of a base rate loan or an Adjusted Term SOFR loan. If San Mateo borrows funds as a base rate loan, such borrowings will bear interest at a rate equal to the greatest of (i) the prime rate for such day, (ii) the Federal Funds Effective Rate (as defined in the San Mateo Credit Facility) on such day, plus 0.50%, and (iii) the Adjusted Term SOFR Rate (as defined in the San Mateo Credit Facility) for a one month tenor plus 1.0%, plus, in each case, an amount ranging from 1.25% to 2.25% per annum depending on San Mateo’s Consolidated Total Leverage Ratio (as defined in the San Mateo Credit Facility). If San Mateo borrows funds as an Adjusted Term SOFR loan, such borrowings will bear interest at a rate equal to (x) the Adjusted Term SOFR Rate for the chosen interest period plus (y) an amount ranging from 2.25% to 3.25% per annum depending on San Mateo’s Consolidated Total Leverage Ratio. If San Mateo has outstanding borrowings under the San Mateo Credit Facility and interest rates increase, so will San Mateo’s interest costs, which may have a material adverse effect on San Mateo’s results of operations and financial condition. A commitment fee of 0.30% to 0.50% per annum, depending on San Mateo’s Consolidated Total Leverage Ratio, is also paid quarterly in arrears. The Company includes this commitment fee, any amortization of deferred financing costs (including origination and amendment fees) and annual agency fees, if any, as interest expense and in its interest rate calculations and related disclosures. The San Mateo Credit Facility requires San Mateo to maintain a debt to EBITDA ratio, which is defined as total consolidated funded indebtedness outstanding (as defined in the San Mateo Credit Facility) divided by a rolling four quarter EBITDA calculation, of 5.00 or less, subject to certain exceptions. The San Mateo Credit Facility also requires San Mateo to maintain an interest coverage ratio, which is defined as a rolling four quarter EBITDA calculation divided by San Mateo’s consolidated interest expense for such period, of 2.50 or more. The San Mateo Credit Facility also restricts the ability of San Mateo to distribute cash to its members if San Mateo’s liquidity is less than 10% of the lender commitments under the San Mateo Credit Facility. Subject to certain exceptions, the San Mateo Credit Facility contains various covenants that limit San Mateo’s and its restricted subsidiaries’ ability to take certain actions, including, but not limited to, the following: • incur indebtedness or grant liens on any of San Mateo’s assets; • enter into hedging agreements; • declare or pay dividends, distributions or redemptions; • merge or consolidate; • make any loans or investments; • engage in transactions with affiliates; • engage in certain asset dispositions, including a sale of all or substantially all of San Mateo’s assets; and • issue equity interests in San Mateo or its restricted subsidiaries. If an event of default exists under the San Mateo Credit Facility, the lenders will be able to terminate their commitments, accelerate the maturity of the borrowings and exercise other rights and remedies. Events of default include, but are not limited to, the following events: • failure to pay any principal or interest on the outstanding borrowings or any reimbursement obligation under any letter of credit when due or any fees or other amounts within certain grace periods; • failure to perform or otherwise comply with the covenants and obligations in the San Mateo Credit Facility or other loan documents, subject, in certain instances, to certain grace periods; • bankruptcy or insolvency events involving San Mateo or its subsidiaries; and • a change of control, as defined in the San Mateo Credit Facility. The Company believes that San Mateo was in compliance with the terms of the San Mateo Credit Facility at December 31, 2022. Senior Unsecured Notes At December 31, 2022, the Company had $699.2 million of outstanding 5.875% senior notes due 2026 that were registered under the Securities Act and mature September 15, 2026 (the “Notes”). Interest is payable on the Notes semi-annually in arrears on each March 15 and September 15. The Notes are jointly and severally guaranteed on a senior unsecured basis by certain subsidiaries of the Company (the “Guarantors”). San Mateo and its subsidiaries and Pronto are not Restricted Subsidiaries (as defined in the Indenture) or Guarantors of the Notes. During the year ended December 31, 2022, the Company repurchased an aggregate principal amount of $350.8 million of its Notes for $344.3 million. The Company may redeem all or a part of the Notes at any time or from time to time at the following redemption prices (expressed as percentages of principal amount) plus accrued and unpaid interest, if any, to the applicable redemption date, if redeemed during the twelve-month period beginning on September 15 of the years indicated below: Year Redemption Price 2022 102.938% 2023 101.469% 2024 and thereafter 100.000% Subject to certain exceptions, the Indenture contains various covenants that limit the Company’s and its Restricted Subsidiaries’ ability to take certain actions, including, but not limited to, the following: • incur additional indebtedness; • sell assets; • pay dividends or make certain investments; • create liens that secure indebtedness; • enter into transactions with affiliates; and • merge or consolidate with another company. In the case of an event of default arising from certain events of bankruptcy or insolvency with respect to Matador, any Restricted Subsidiary (as defined in the Indenture) that is a Significant Subsidiary (as defined in the Indenture) or any group of Restricted Subsidiaries that, taken together, would constitute a Significant Subsidiary, all outstanding Notes will become due and payable immediately without further action or notice. If any other event of default occurs and is continuing, the trustee or the holders of at least 25% in principal amount of the then outstanding Notes may declare all the Notes to be due and payable immediately. Events of default include, but are not limited to, the following events: • default for 30 days in the payment when due of interest on the Notes; • default in the payment when due of the principal of, or premium, if any, on the Notes; • failure by the Company to comply with its obligations to offer to purchase or purchase Notes pursuant to the change of control or asset sale covenants of the Indenture or to comply with the covenant relating to mergers; • failure by the Company for 180 days after notice to comply with its reporting obligations under the Indenture; • failure by the Company for 60 days after notice to comply with any of the other agreements in the Indenture; • payment defaults and accelerations with respect to other indebtedness of the Company and its Restricted Subsidiaries in the aggregate principal amount of $50.0 million or more; • failure by the Company or any Restricted Subsidiary to pay certain final judgments aggregating in excess of $50.0 million within 60 days; • any subsidiary guarantee by a Guarantor ceases to be in full force and effect, is declared null and void in a judicial proceeding or is denied or disaffirmed by its maker; and • certain events of bankruptcy or insolvency with respect to the Company or any Restricted Subsidiary that is a Significant Subsidiary or any group of Restricted Subsidiaries that, taken together, would constitute a Significant Subsidiary. Debt Maturities

Income Taxes

Income Taxes	12 Months Ended
Income Taxes	Dec. 31, 2022
Income Tax Disclosure [Abstract]
INCOME TAXES	Deferred tax assets and liabilities are the result of temporary differences between the financial statement carrying values and the tax bases of assets and liabilities. The Company’s net deferred tax position as of December 31, 2022 and 2021 is as follows (in thousands). December 31, 2022 2021 Deferred tax assets Net operating loss carryforwards $ 12,874 $ 129,651 Unrealized loss on derivatives — 3,729 Percentage depletion carryover 8 1,770 Compensation 14,184 9,838 Lease liabilities 12,585 4,866 Other 1,926 9,410 Total deferred tax assets 41,577 159,264 Valuation allowance on deferred tax assets (11,322) (10,599) Total deferred tax assets, net of valuation allowance 30,255 148,665 Deferred tax liabilities Unrealized gain on derivatives (995) — Property and equipment (368,283) (179,153) Less than wholly-owned subsidiaries (63,388) (39,900) Lease right of use assets (12,585) (4,866) Other (13,355) (2,684) Total deferred tax liabilities (458,606) (226,603) Net deferred tax liabilities $ (428,351) $ (77,938) At December 31, 2020, the Company’s deferred tax assets exceeded its deferred tax liabilities due to the deferred tax assets generated by impairment charges recorded in 2020. As a result, the Company established a valuation allowance against most of the deferred tax assets beginning in the third quarter of 2020. Due to a variety of factors, including the Company’s significant net income in 2021, the Company’s federal valuation allowance was reversed as of September 30, 2021 as the deferred tax assets were determined to be more likely than not to be utilized. As a portion of the Company’s state net operating loss carryforwards are not expected to be utilized before expiration, a valuation allowance will continue to be recognized until the state deferred tax assets are more likely than not to be utilized. The current income tax provision and the deferred income tax provision for the years ended December 31, 2022, 2021 and 2020 were comprised of the following (in thousands). Year Ended December 31, 2022 2021 2020 Current income tax provision Federal income tax $ 31,335 $ — $ — State income tax 23,542 — — Net current income tax provision $ 54,877 $ — $ — Deferred income tax provision (benefit) Federal income tax $ 302,486 $ 44,883 $ (25,675) State income tax 41,994 29,827 (19,924) Net deferred income tax provision (benefit) $ 344,480 $ 74,710 $ (45,599) Reconciliations of the tax expense (benefit) computed at the statutory federal rate to the Company’s total income tax provision (benefit) for the years ended December 31, 2022, 2021 and 2020 is as follows (in thousands). Year Ended December 31, 2022 2021 2020 Federal tax expense (benefit) at statutory rate (1) $ 353,992 $ 150,223 $ (125,823) State income tax expense (benefit) 59,870 26,646 (20,607) Permanent differences (15,227) (2,078) (3,114) Change in federal valuation allowance — (103,262) 103,262 Change in state valuation allowance 722 3,181 683 Total income tax provision (benefit) $ 399,357 $ 74,710 $ (45,599) __________________ (1) The statutory federal tax rate was 21% for the years ended December 31, 2022, 2021 and 2020. The Company files a United States federal income tax return and several state tax returns, a number of which remain open for examination. The earliest tax year open for examination for the federal, the State of New Mexico and the State of Louisiana tax returns is 2019. The earliest tax year open for examination for the State of Texas tax return is 2018.

Stock-Based Compensation

Stock-Based Compensation	12 Months Ended
Stock-Based Compensation	Dec. 31, 2022
Share-Based Payment Arrangement [Abstract]
STOCK-BASED COMPENSATION	STOCK-BASED COMPENSATION In 2012, the Company’s Board of Directors (the “Board”) adopted and shareholders approved the 2012 Incentive Plan. The 2012 Incentive Plan provided for a maximum of 8,700,000 shares of common stock in the aggregate that could be issued pursuant to options, restricted stock, stock appreciation rights, restricted stock units or other performance award grants. In 2019, the Board adopted and shareholders approved the 2019 Incentive Plan. In April 2022, the Board adopted, subject to shareholder approval, the first amendment to the 2019 Long-Term Incentive Plan, authorizing an additional 3,725,000 shares of common stock for issuance to employees, directors, contractors or advisors of the Company. In June 2022, the Company’s shareholders approved such amendment. As of December 31, 2022, the 2019 Incentive Plan provided for a maximum of 4,174,443 shares of common stock in the aggregate that may be issued pursuant to grants of options, restricted stock, stock appreciation rights, restricted stock units or other performance award grants. The persons eligible to receive awards under the 2019 Incentive Plan include employees, directors, contractors or advisors of the Company. The primary purpose of the 2019 Incentive Plan is to attract and retain key employees, directors, contractors or advisors of the Company. With the adoption of the 2019 Incentive Plan, the Company does not expect to make any future awards under the 2012 Incentive Plan, but the 2012 Incentive Plan will remain in place until all awards outstanding under that plan have been settled. The 2012 Incentive Plan and 2019 Incentive Plan are administered by the independent members of the Board, who, upon recommendation of the Strategic Planning and Compensation Committee of the Board, determine the number of options, restricted shares or other awards to be granted, the effective dates, the terms of the grants and the vesting periods. The Company typically uses newly issued shares of common stock to satisfy option exercises or restricted share grants. During the years ended December 31, 2022, 2021 and 2020, the Company granted both equity-based and liability-based awards under the 2019 Incentive Plan. The fair value of equity-based awards is fixed at the grant date, while the fair value of liability-based awards is remeasured at each reporting period. In April 2022, the Board adopted, subject to shareholder approval, an Employee Stock Purchase Plan (the “ESPP”). The purpose of the ESPP is to encourage and enable the Company’s eligible employees to acquire an interest in the Company through the ownership of common stock. In June 2022, the Company’s shareholders approved and authorized a maximum of 4.0 million shares of common stock to be purchased under the ESPP. At December 31, 2022, the Company had 3,977,456 remaining shares available for issuance under the ESPP. Stock Options Under the 2012 Incentive Plan and the 2019 Incentive Plan, stock option awards have been granted and are outstanding to purchase the Company’s common stock at an exercise price equal to the fair market value on the date of grant, a typical vesting period of three five six Summarized information about stock options outstanding at December 31, 2022 under the 2012 Incentive Plan and the 2019 Incentive Plan (collectively, the “LTIPs”) is as follows. Number of options (in thousands) Weighted Options outstanding at December 31, 2021 603 $ 22.92 Options granted — $ — Options exercised (445) $ 24.35 Options forfeited (8) $ 14.80 Options expired — $ — Options outstanding at December 31, 2022 150 $ 19.11 Options outstanding at December 31, 2022 Options exercisable at December 31, 2022 Range of exercise prices Shares outstanding (in thousands) Weighted Weighted Shares exercisable (in thousands) Weighted $14.48 - $14.80 103 2.66 $ 14.80 103 $ 14.80 $26.86 - $29.68 47 0.74 $ 28.60 47 $ 28.60 At December 31, 2022, the aggregate intrinsic value for both outstanding and exercisable options was $5.7 million, based on the closing price of Matador’s common stock on the appropriate date under the LTIPs. The remaining weighted average contractual term of exercisable options at December 31, 2022 was 2.06 years. The total intrinsic value of options exercised during the years ended December 31, 2022, 2021 and 2020 was $14.4 million, $15.8 million and $0.3 million, respectively. At December 31, 2022, the Company did not have any unvested stock options or unrecognized compensation expense associated with unvested stock options. The fair value of options vested during 2022, 2021 and 2020 was $0.8 million, $3.0 million and $6.7 million, respectively. Service-Based Restricted Stock, Restricted Stock Units and Common Stock The Company has granted stock, restricted stock and restricted stock unit awards to employees, consultants, outside directors and advisors of the Company under the LTIPs. The stock and restricted stock are issued upon grant, with the restrictions, if any, being removed upon vesting. The equity-based restricted stock units are issued upon vesting, unless the recipient makes an election to defer issuance for a set term after vesting. Liability-based restricted stock units are settled in cash upon vesting. Restricted stock and restricted stock units granted in 2022, 2021 and 2020 were service-based awards, which will settle in cash or equity, and vest over a one-year to three-year period. Performance-based restricted stock units granted in 2022 and 2021 vest in an amount between zero and 200% of the target units granted based on the Company’s relative total shareholder return over the three-year periods ending December 31, 2024 and 2023, respectively, as compared to a designated peer group, and will be settled in equity. Equity-Based A summary of the non-vested equity-based restricted stock and restricted stock units as of December 31, 2022 is presented below (in thousands, except fair value). Restricted Stock Restricted Stock Units Service Based Service Based Performance Based Non-vested restricted stock and Shares Weighted Shares Weighted Shares Weighted Non-vested at December 31, 2021 589 $ 24.59 33 $ 33.39 963 $ 20.26 Granted 236 $ 45.58 16 $ 66.16 230 $ 65.49 Vested (1) (126) $ 24.07 (33) $ 33.39 (597) $ 1.74 Forfeited (41) $ 19.12 — $ — — $ — Non-vested at December 31, 2022 658 $ 24.59 16 $ 66.16 596 $ 56.31 __________________ (1) On December 31, 2022, 597,414 of the performance-based awards that were granted in 2020 vested. The vested units earned 175% for each vested award representing 1,045,472 aggregate shares of common stock, which were issued on December 31, 2022. Liability-Based A summary of the non-vested liability-based restricted stock units as of December 31, 2022 is presented below (in thousands). Non-vested Shares Non-vested at December 31, 2021 1,102 Granted 226 Vested (587) Forfeited (19) Non-vested at December 31, 2022 722 During the years ended December 31, 2022, 2021 and 2020, the Company settled 587,251, 487,252 and 226,363 liability-based awards, respectively, for $30.8 million, $12.4 million and $2.4 million in cash, respectively. At December 31, 2022, the aggregate intrinsic value for the restricted stock and restricted stock units outstanding was $114.1 million, of which $41.3 million is expected to be settled in cash as calculated based on the maximum number of shares of restricted stock units vesting, based on the closing price of Matador’s common stock on the appropriate date under the LTIPs. At December 31, 2022, the total remaining unrecognized compensation expense related to unvested restricted stock and restricted stock units was approximately $56.1 million, of which $23.4 million is expected to be settled in cash, based on the closing price of Matador’s common stock on the appropriate date under the LTIPs. The weighted average remaining requisite service period (vesting period) of all non-vested restricted stock and restricted stock units was 1.7 years. The fair value of restricted stock and restricted stock units vested during 2022, 2021 and 2020 was $99.6 million, $51.9 million and $8.4 million, respectively. Summary During the years ended December 31, 2022, 2021 and 2020, the total expense attributable to stock options was $0.5 million, $1.0 million and $3.4 million, respectively. During the years ended December 31, 2022, 2021 and 2020, the total expense attributable to restricted stock and restricted stock units was $51.6 million, $36.3 million and $17.7 million, respectively. During the years ended December 31, 2022, 2021 and 2020, the Company capitalized $5.0 million, $7.2 million and $3.6 million, respectively, related to stock-based compensation and expensed the remaining $47.1 million, $30.0 million and $17.6 million, respectively. The total tax benefit recognized for all stock-based compensation was $11.0 million, $7.9 million and $4.5 million for the years ended December 31, 2022, 2021 and 2020, respectively.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
Employee Benefit Plans	Dec. 31, 2022
Retirement Benefits [Abstract]
EMPLOYEE BENEFIT PLANS	EMPLOYEE BENEFIT PLANS 401(k) Plan All full-time Company employees are eligible to join the Company’s defined contribution retirement plan the first day of the calendar month immediately following their date of employment. Each employee may contribute up to the maximum allowable under the Internal Revenue Code. Each year, the Company makes a contribution to the plan that equals 3% of the employee’s annual compensation, up to the maximum allowable under the Internal Revenue Code, referred to as the Employer’s Safe Harbor Non-Elective Contribution, which totaled $1.8 million, $1.6 million and $1.4 million in 2022, 2021 and 2020, respectively. In addition, each year, the Company may make a discretionary matching contribution, as well as additional contributions. The Company’s discretionary matching contributions totaled $2.3 million, $2.1 million and $1.8 million in 2022, 2021 and 2020, respectively. The Company made no additional contributions in any reporting period presented.

Equity

Equity	12 Months Ended
Equity	Dec. 31, 2022
Stockholders' Equity Note [Abstract]
EQUITY	EQUITY Common Stock Dividend In February 2022 and April 2022, the Board declared quarterly cash dividends of $0.05 per share of common stock, each of which totaled $5.9 million and were paid on March 14, 2022 and June 3, 2022, respectively. In June 2022, the Board amended the Company’s dividend policy to increase the quarterly dividend to $0.10 per share of common stock. In July 2022 and October 2022, the Board declared quarterly cash dividends of $0.10 per share of common stock, each of which totaled $11.7 million and were paid on September 1, 2022 and December 1, 2022, respectively. In December 2022, the Board amended the Company’s dividend policy to increase the quarterly dividend to $0.15 per share of common stock for future dividend payments. On February 15, 2023, the Board declared a quarterly cash dividend of $0.15 per share of common stock payable on March 9, 2023 to shareholders of record as of February 27, 2023. The Board declared a quarterly cash dividend of $0.025 per share of common stock in each of the first three quarters of 2021 and, in the fourth quarter of 2021, the Board declared a quarterly cash dividend of $0.05 per share of common stock. Total cash dividends declared and paid totaled $35.2 million and $14.6 million, respectively, during the years December 31, 2022 and 2021. There were no cash dividends declared or paid prior to 2021. Treasury Stock On October 20, 2022, October 21, 2021 and October 22, 2020, Matador’s Board of Directors canceled all of the shares of treasury stock outstanding as of September 30, 2022, 2021 and 2020, respectively. These shares were restored to the status of authorized but unissued shares of common stock of the Company. The shares of treasury stock outstanding at December 31, 2022, 2021 and 2020 represent forfeitures of non-vested restricted stock awards and forfeitures of fully vested restricted stock awards due to net share settlements with employees. Preferred Stock The Company’s Amended and Restated Certificate of Formation authorizes 2,000,000 shares of preferred stock. Before any such shares are issued, the Board of Directors shall fix and determine the designations, preferences, limitations and relative rights, including voting rights of the shares of each such series.

Derivative Financial Instrument

Derivative Financial Instruments	12 Months Ended
Derivative Financial Instruments	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
DERIVATIVE FINANCIAL INSTRUMENTS	DERIVATIVE FINANCIAL INSTRUMENTS From time to time, the Company uses derivative financial instruments to mitigate its exposure to commodity price risk associated with oil, natural gas and NGL prices. The Company records derivative financial instruments on its consolidated balance sheets as either assets or liabilities measured at fair value. The Company has elected not to apply hedge accounting for its existing derivative financial instruments. As a result, the Company recognizes the change in derivative fair value between reporting periods currently in its consolidated statements of operations as an unrealized gain or loss. The fair value of the Company’s derivative financial instruments is determined using industry-standard models that consider various inputs including: (i) quoted forward prices for commodities, (ii) time value of money and (iii) current market and contractual prices for the underlying instruments, as well as other relevant economic measures. The Company has evaluated and considered the credit standings of its counterparties in determining the fair value of its derivative financial instruments. At December 31, 2022, the Company had one costless collar open and in place to mitigate its exposure to natural gas price volatility, with a specific term (calculation period), notional quantity (volume hedged) and price floor and ceiling. At December 31, 2022, the contract was set to expire during the first quarter of 2023. The Company had no open contracts associated with oil or NGL prices at December 31, 2022. The following is a summary of the Company’s open costless collar contract at December 31, 2022. Notional Quantity (MMBtu) Weighted Average Price Floor ($/MMBtu) Weighted Average Price Ceiling ($/MMBtu) Fair Value of Asset (Liability) (thousands) Commodity Calculation Period Natural Gas 01/01/2023 - 03/31/2023 2,400,000 $ 6.00 $ 14.00 3,931 Total open costless collar contracts $ 3,931 Between December 31, 2022 and February 21, 2023, the Company entered into a Waha-Henry Hub basis swap contract for natural gas. The basis swap contract included approximately 16,700,000 MMBtu for February 2023 to December 2023 with a fixed price of ($1.85) per MMBtu. The Company’s derivative financial instruments are subject to master netting arrangements, and the Company’s counterparties allow for cross-commodity master netting provided the settlement dates for the commodities are the same. The Company does not present different types of commodities with the same counterparty on a net basis in its consolidated balance sheets. The following table presents the gross asset and liability fair values of the Company’s commodity price derivative financial instruments and the location of these balances in the consolidated balance sheets as of December 31, 2022 and December 31, 2021 (in thousands). Derivative Instruments Gross amounts recognized Gross amounts netted in the consolidated balance sheets Net amounts presented in the consolidated balance sheets December 31, 2022 Current assets $ 3,931 $ — $ 3,931 Current liabilities — — — Total $ 3,931 $ — $ 3,931 December 31, 2021 Current assets $ 215,145 $ (213,174) $ 1,971 Current liabilities (230,023) 213,174 (16,849) Total $ (14,878) $ — $ (14,878) The following table summarizes the location and aggregate gain (loss) of all derivative financial instruments recorded in the consolidated statements of operations for the periods presented (in thousands). Year Ended December 31, Type of Instrument Location in Statements of Operations 2022 2021 2020 Derivative Instrument Oil Revenues: Realized (loss) gain on derivatives $ (75,806) $ (194,058) $ 38,937 Natural Gas Revenues: Realized loss on derivatives (81,677) (26,047) — Realized (loss) gain on derivatives (157,483) (220,105) 38,937 Oil Revenues: Unrealized gain (loss) on derivatives 14,727 26,857 (37,703) Natural Gas Revenues: Unrealized gain (loss) on derivatives 4,082 (5,846) 5,695 Unrealized gain (loss) on derivatives 18,809 21,011 (32,008) Total $ (138,674) $ (199,094) $ 6,929

Fair Value Measurements

Fair Value Measurements	12 Months Ended
Fair Value Measurements	Dec. 31, 2022
Fair Value Disclosures [Abstract]
FAIR VALUE MEASUREMENTS	The Company measures and reports certain financial and non-financial assets and liabilities on a fair value basis. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). Fair value measurements are classified and disclosed in one of the following categories. Level 1 Unadjusted quoted prices for identical, unrestricted assets or liabilities in active markets. Level 2 Quoted prices in markets that are not active, or inputs that are observable, either directly or indirectly, for substantially the full term of the asset or liability. This category includes those derivative instruments that are valued with industry standard models that consider various inputs, including: (i) quoted forward prices for commodities, (ii) time value of money and (iii) current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these inputs are observable in the marketplace throughout the full term of the derivative instrument and can be derived from observable data or supported by observable levels at which transactions are executed in the marketplace. Level 3 Unobservable inputs that are not corroborated by market data that reflect a company’s own market assumptions. Financial and non-financial assets and liabilities are classified based on the lowest level of input that is significant to the fair value measurement. The 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 following tables summarize the valuation of the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis in accordance with the classifications provided above as of December 31, 2022 and 2021 (in thousands). Fair Value Measurements at Description Level 1 Level 2 Level 3 Total Assets (Liabilities) Natural gas derivatives $ — $ 3,931 $ — $ 3,931 Total $ — $ 3,931 $ — $ 3,931 Fair Value Measurements at Description Level 1 Level 2 Level 3 Total Assets (Liabilities) Oil derivatives and basis swaps $ — $ (14,727) $ — $ (14,727) Natural gas derivatives — (151) — (151) Contingent consideration related to business combination — — (8,203) $ (8,203) Total $ — $ (14,878) $ (8,203) $ (23,081) Additional disclosures related to derivative financial instruments are provided in Note 12. Other Fair Value Measurements At December 31, 2022 and 2021, the carrying values reported on the consolidated balance sheets for accounts receivable, prepaid expenses and other current assets, accounts payable, accrued liabilities, royalties payable, amounts due to affiliates, advances from joint interest owners and other current liabilities approximated their fair values due to their short-term maturities. At December 31, 2022 and 2021, the carrying value of borrowings under the Credit Agreement and the San Mateo Credit Facility approximated their fair value as both are subject to short-term floating interest rates that reflect market rates available to the Company at the time and are classified at Level 2 in the fair value hierarchy. At December 31, 2022 and 2021, the fair value of the Notes was $675.7 million and $1.08 billion, respectively, based on quoted market prices, which represent Level 1 inputs in the fair value hierarchy. Certain assets and liabilities are measured at fair value on a nonrecurring basis, including assets and liabilities acquired in a business combination, lease and well equipment inventory when the market value is determined to be lower than the cost of

Commitments and Contingencies

Commitments and Contingencies	12 Months Ended
Commitments and Contingencies	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
COMMITMENTS AND CONTINGENCIES	Processing, Transportation and Produced Water Disposal Commitments Firm Commitments From time to time, the Company enters into agreements with third parties whereby the Company commits to deliver anticipated natural gas and oil production and produced water from certain portions of its acreage for gathering, transportation, processing, fractionation, sales and disposal. The Company paid approximately $48.3 million and $48.7 million for deliveries under these agreements during the years ended December 31, 2022 and 2021, respectively. Certain of these agreements contain minimum volume commitments. If the Company does not meet the minimum volume commitments under these agreements, it will be required to pay certain deficiency fees. If the Company ceased operations in the areas subject to these agreements at December 31, 2022, the total deficiencies required to be paid by the Company under these agreements would be approximately $541.1 million. San Mateo Commitments The Company dedicated to San Mateo its current and certain future leasehold interests in the Rustler Breaks and Wolf asset areas and acreage in the Greater Stebbins Area and the Stateline asset area pursuant to 15-year, fixed-fee oil transportation, oil, natural gas and produced water gathering and produced water disposal agreements. In addition, the Company dedicated to San Mateo its current and certain future leasehold interests in the Rustler Breaks asset area and acreage in the Greater Stebbins Area and Stateline asset area pursuant to 15-year, fixed-fee natural gas processing agreements (collectively with the transportation, gathering and produced water disposal agreements, the “Operational Agreements”). San Mateo provides the Company with firm service under each of the Operational Agreements in exchange for certain minimum volume commitments. The remaining minimum contractual obligation under the Operational Agreements at December 31, 2022 was approximately $292.0 million. Other Commitments The Company does not own or operate its own drilling rigs, but instead enters into contracts with third parties for such drilling rigs. These contracts establish daily rates for the drilling rigs and the term of the Company’s commitment for the drilling services to be provided. The Company would incur a termination obligation if the Company elected to terminate a contract and if the drilling contractor were unable to secure replacement work for the contracted drilling rigs at the same daily rates being charged to the Company prior to the end of their respective contract terms. The Company’s undiscounted minimum outstanding aggregate termination obligations under its drilling rig contracts were approximately $17.7 million at December 31, 2022. At December 31, 2022, the Company had outstanding commitments to participate in the drilling and completion of various non-operated wells. If all of these wells are drilled and completed as proposed, the Company’s undiscounted minimum outstanding aggregate commitments for its participation in these non-operated wells were approximately $26.0 million at December 31, 2022. The Company expects these costs to be incurred within the next year. At December 31, 2022, the Company had outstanding commitments of $29.8 million to purchase 12 compressors to be utilized in San Mateo and Pronto operations. The Company expects these costs to be incurred within the next year. Legal Proceedings The Company is a party to several legal proceedings encountered in the ordinary course of its business. While the ultimate outcome and impact to the Company cannot be predicted with certainty, in the opinion of management, it is remote that these legal proceedings will have a material adverse impact on the Company’s financial condition, results of operations or cash flows.

Supplemental Disclosures

Supplemental Disclosures	12 Months Ended
Supplemental Disclosures	Dec. 31, 2022
Supplemental Disclosures [Abstract]
SUPPLEMENTAL DISCLOSURES	Accrued Liabilities The following table summarizes the Company’s current accrued liabilities at December 31, 2022 and 2021 (in thousands). December 31, 2022 2021 Accrued evaluated and unproved and unevaluated property costs $ 112,766 $ 128,598 Accrued midstream properties costs 11,623 7,799 Accrued lease operating expenses 46,975 32,182 Accrued interest on debt 10,461 18,232 Accrued asset retirement obligations 756 270 Accrued partners’ share of joint interest charges 42,199 17,460 Accrued payable related to purchased natural gas 11,158 11,284 Other 25,372 37,458 Total accrued liabilities $ 261,310 $ 253,283 Supplemental Cash Flow Information The following table provides supplemental disclosures of cash flow information for the years ended December 31, 2022, 2021 and 2020 (in thousands). Year Ended December 31, 2022 2021 2020 Cash paid for income taxes $ 63,500 $ — $ — Cash paid for interest expense, net of amounts capitalized $ 72,561 $ 74,843 $ 76,880 Increase (decrease) in asset retirement obligations related to mineral properties $ 9,111 $ 1,091 $ (208) Increase in asset retirement obligations related to midstream properties $ 251 $ 257 $ 690 (Decrease) increase in liabilities for drilling, completion and equipping capital expenditures $ (13,304) $ 80,255 $ (26,126) (Decrease) increase in liabilities for acquisition of oil and natural gas properties $ (2,531) $ 2,981 $ (2,346) Increase (decrease) in liabilities for midstream capital expenditures $ 3,824 $ (4,478) $ (33,609) Stock-based compensation expense recognized as liability $ 31,906 $ 24,494 $ 3,702 Transfer of inventory from (to) oil and natural gas properties $ 148 $ (398) $ 608 The following table provides a reconciliation of cash and restricted cash recorded in the consolidated balance sheets to cash and restricted cash as presented on the consolidated statements of cash flows (in thousands). Year Ended December 31, 2022 2021 2020 Cash $ 505,179 $ 48,135 $ 57,916 Restricted cash 42,151 38,785 33,467 Total cash and restricted cash $ 547,330 $ 86,920 $ 91,383

Segment Reporting

Segment Reporting	12 Months Ended
Segment Reporting	Dec. 31, 2022
Segment Reporting [Abstract]
Segment Reporting	The Company operates in two business segments: (i) exploration and production and (ii) midstream. The exploration and production segment is engaged in the exploration, development, production and acquisition of oil and natural gas resources in the United States and is currently focused primarily on the oil and liquids-rich portion of the Wolfcamp and Bone Spring plays in the Delaware Basin in Southeast New Mexico and West Texas. The Company also operates in the Eagle Ford shale play in South Texas and the Haynesville shale and Cotton Valley plays in Northwest Louisiana. The midstream segment conducts midstream operations in support of the Company’s exploration, development and production operations and provides natural gas processing, oil transportation services, oil, natural gas and produced water gathering services and produced water disposal services to third parties. Substantially all of the Company’s midstream operations in the Rustler Breaks, Wolf and Stateline asset areas and the Greater Stebbins Area in the Delaware Basin, which comprise most of the Company’s midstream operations, are conducted through San Mateo (see Note 6). In addition, on June 30, 2022, an indirect wholly-owned subsidiary of the Company acquired a cryogenic gas processing plant, three compressor stations and approximately 45 miles of natural gas gathering pipelines in Lea and Eddy Counties, New Mexico as part of the Pronto Acquisition. Neither San Mateo nor Pronto is a guarantor of the Notes. The following tables present selected financial information for the periods presented regarding the Company’s business segments on a stand-alone basis, corporate expenses that are not allocated to a segment and the consolidation and elimination entries necessary to arrive at the financial information for the Company on a consolidated basis (in thousands). On a consolidated basis, midstream services revenues consist primarily of those revenues from midstream operations related to third parties, including working interest owners in the Company’s operated wells. All midstream services revenues associated with Company-owned production are eliminated in consolidation. In evaluating the operating results of the exploration and production and midstream segments, the Company does not allocate certain expenses to the individual segments, including general and administrative expenses. Such expenses are reflected in the column labeled “Corporate.” Exploration and Production Consolidations and Eliminations Consolidated Company Midstream Corporate Year Ended December 31, 2022 Oil and natural gas revenues $ 2,897,336 $ 8,402 $ — $ — $ 2,905,738 Midstream services revenues — 298,184 — (207,578) 90,606 Sales of purchased natural gas 116,772 83,583 — — 200,355 Realized loss on derivatives (157,483) — — — (157,483) Unrealized gain on derivatives 18,809 — — — 18,809 Expenses (1) 1,177,104 227,556 101,673 (207,578) 1,298,755 Operating income (2) $ 1,698,330 $ 162,613 $ (101,673) $ — $ 1,759,270 Total assets (3) $ 4,022,609 $ 1,016,580 $ 515,316 $ — $ 5,554,505 Capital expenditures (4) $ 903,518 $ 158,544 $ 1,213 $ — $ 1,063,275 _____________________ (1) Includes depletion, depreciation and amortization expenses of $429.7 million and $34.7 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $2.0 million. (2) Includes $72.1 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment. (3) Excludes intercompany receivables and investments in subsidiaries. (4) Includes $131.0 million attributable to land and seismic acquisition expenditures related to the exploration and production segment, $75.8 million in midstream acquisition expenditures and $39.6 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment. Exploration and Production Consolidations and Eliminations Consolidated Company Midstream Corporate Year Ended December 31, 2021 Oil and natural gas revenues $ 1,695,032 $ 5,510 $ — $ — $ 1,700,542 Midstream services revenues — 228,817 — (153,318) 75,499 Sales of purchased natural gas 47,398 38,636 — — 86,034 Realized loss on derivatives (220,105) — — — (220,105) Unrealized gain on derivatives 21,011 — — — 21,011 Expenses (1) 794,880 142,444 85,899 (153,318) 869,905 Operating (loss) income (2) $ 748,456 $ 130,519 $ (85,899) $ — $ 793,076 Total assets (3) $ 3,324,681 $ 879,672 $ 57,800 $ — $ 4,262,153 Capital expenditures (4) $ 778,191 $ 59,361 $ 376 $ — $ 837,928 _____________________ (1) Includes depletion, depreciation and amortization expenses of $310.9 million and $31.5 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $2.6 million. (2) Includes $55.7 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment. (3) Excludes intercompany receivables and investments in subsidiaries. (4) Includes $263.5 million attributable to land and seismic acquisition expenditures related to the exploration and production segment and $28.5 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment. Exploration and Production Consolidations and Eliminations Consolidated Company Midstream Corporate Year Ended December 31, 2020 Oil and natural gas revenues $ 741,092 $ 3,369 $ — $ — $ 744,461 Midstream services revenues — 166,194 — (101,262) 64,932 Sales of purchased natural gas 20,736 21,006 — — 41,742 Lease bonus - mineral acreage 4,062 — — — 4,062 Realized gain on derivatives 38,937 — — — 38,937 Unrealized loss on derivatives (32,008) — — — (32,008) Expenses (1) 1,334,378 97,599 52,910 (101,262) 1,383,625 Operating income (loss) (2) $ (561,559) $ 92,970 $ (52,910) $ — $ (521,499) Total assets (3) $ 2,782,819 $ 836,509 $ 67,952 $ — $ 3,687,280 Capital expenditures (4) $ 518,198 $ 201,440 $ 2,200 $ — $ 721,838 _____________________ (1) Includes depletion, depreciation and amortization expenses of $335.8 million and $23.3 million for the exploration and production and midstream segments, respectively. Includes full-cost ceiling impairment of $684.7 million for the exploration and production segment. Also includes corporate depletion, depreciation and amortization expenses of $2.7 million. (2) Includes $39.6 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment. (3) Excludes intercompany receivables and investments in subsidiaries. (4) Includes $70.5 million attributable to land and seismic acquisition expenditures related to the exploration and production segment and $112.1 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment.

Subsequent Events

Subsequent Events	12 Months Ended
Subsequent Events	Dec. 31, 2022
Subsequent Events [Abstract]
Subsequent Events	On January 24, 2023, a wholly-owned subsidiary of the Company entered into a definitive agreement to acquire Advance Energy Partners Holdings, LLC (“Advance”) from affiliates of EnCap Investments L.P., including certain oil and natural gas producing properties and undeveloped acreage located primarily in Lea County, New Mexico and Ward County, Texas (the “Advance Acquisition”). The consideration for the Advance Acquisition is expected to consist of $1.6 billion in cash, subject to customary closing adjustments, including for working capital and title and environmental defects, plus additional cash consideration of $7.5 million for each month during 2023 in which the average price of crude oil (as defined in the securities purchase agreement) exceeds $85 per barrel. The consummation of the Advance Acquisition is subject to customary closing conditions and is expected to close in the second quarter of 2023 with an effective date of January 1, 2023.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	12 Months Ended
Summary of Significant Accounting Policies (Policies)	Dec. 31, 2022
Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The consolidated financial statements include the accounts of Matador and its wholly-owned and majority-owned subsidiaries. These consolidated financial statements have been prepared in accordance with generally accepted accounting principles in the United States of America (“U.S. GAAP”). Accordingly, the Company consolidates certain subsidiaries and joint ventures that are less-than-wholly-owned and are not involved in oil and natural gas exploration, including San Mateo, and the net income and equity attributable to the non-controlling interest in these subsidiaries have been reported separately as required by Accounting Standards Codification (“ASC”), Consolidation (Topic 810) . The Company proportionately consolidates certain joint ventures that are less-than-wholly-owned and are involved in oil and natural gas exploration. All intercompany balances and transactions have been eliminated in consolidation.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. These estimates and assumptions may also affect disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. The Company’s consolidated financial statements are based on a number of significant estimates, including oil and natural gas revenues, accrued assets and liabilities, stock-based compensation, valuation of derivative instruments, deferred tax assets and liabilities, purchase price allocations and oil and natural gas reserves. The estimates of oil and natural gas reserves quantities and future net cash flows are the basis for the calculations of depletion and impairment of oil and natural gas properties, as well as estimates of asset retirement obligations and certain tax accruals. The Company’s oil and natural gas reserves estimates, which are inherently imprecise and based upon many factors that are beyond the Company’s control, including oil and natural gas prices, are prepared by the Company’s engineering staff in accordance with guidelines established by the Securities and Exchange Commission (“SEC”) and then audited for their reasonableness and conformance with SEC guidelines by Netherland, Sewell & Associates, Inc., independent reservoir engineers. While the Company believes its estimates are reasonable, changes in facts and assumptions or the discovery of new information may result in revised estimates. Actual results could differ from these estimates.
Restricted Cash	Restricted Cash Restricted cash represents a portion of the cash associated with the Company’s less-than-wholly-owned subsidiaries, primarily San Mateo. By contractual agreement, the cash in the accounts held by the Company’s less-than-wholly-owned subsidiaries is not to be commingled with other Company cash and is to be used only to fund the capital expenditures and operations of these less-than-wholly-owned subsidiaries.
Accounts Receivable	Accounts Receivable The Company sells its operated oil, natural gas and natural gas liquid (“NGL”) production to various purchasers (see “—Revenues” below). In addition, the Company may participate with industry partners in the drilling, completion and operation of oil and natural gas wells. Substantially all of the Company’s accounts receivable are due from purchasers of oil, natural gas and NGLs, participants in oil and natural gas wells for which the Company serves as the operator, customers of San Mateo and Pronto or the Company’s derivative counterparties. Accounts receivable are typically due within 30 to 60 days of the production date and 30 days of the billing date and are stated at amounts due from purchasers and industry partners. Amounts are considered past due if they have been outstanding for 60 days or more. No interest is typically charged on past due amounts.
Lease and Well Equipment Inventory	Lease and Well Equipment Inventory Lease and well equipment inventory is stated at the lower of cost or net realizable value and consists entirely of materials or equipment scheduled for use in future well or midstream operations.
Property and Equipment	Oil and Natural Gas Properties The Company uses the full-cost method of accounting for its investments in oil and natural gas properties. Under this method, all costs associated with the acquisition, exploration and development of oil and natural gas properties and reserves, including unproved and unevaluated property costs, are capitalized as incurred and accumulated in a single cost center representing the Company’s activities, which are undertaken exclusively in the United States. Such costs include lease acquisition costs, geological and geophysical expenditures, lease rentals on undeveloped properties, costs of drilling both productive and non-productive wells, capitalized interest on qualifying projects and general and administrative expenses directly related to acquisition, exploration and development activities, but do not include any costs related to production, selling or general corporate administrative activities. The Company capitalized $47.8 million, $38.4 million and $30.0 million of its general and administrative costs into oil and natural gas properties in 2022, 2021 and 2020, respectively. The Company capitalized $10.1 million, $4.8 million and $5.0 million of its interest expense into oil and natural gas properties for the years ended December 31, 2022, 2021 and 2020, respectively. Capitalized costs of oil and natural gas properties are amortized using the unit-of-production method based upon production and estimates of proved reserves quantities. For the years ended December 31, 2022, 2021 and 2020, the Company recorded depletion expense of $428.9 million, $310.1 million and $334.8 million, respectively. Unproved and unevaluated property costs are excluded from the amortization base used to determine depletion. Unproved and unevaluated properties are assessed for possible impairment on a periodic basis based upon changes in operating or economic conditions. This assessment includes consideration of the following factors, among others: the assignment of proved reserves, geological and geophysical evaluations, intent to drill, remaining lease term and drilling activity and results. Upon impairment, the costs of the unproved and unevaluated properties are immediately included in the amortization base. Exploratory dry holes are included in the amortization base immediately upon determination that the well is not productive. Sales of oil and natural gas properties are accounted for as adjustments to net capitalized costs with no gain or loss recognized, unless such adjustments would significantly alter the relationship between net capitalized costs and proved reserves of oil and natural gas. All costs related to production activities and maintenance and repairs are expensed as incurred. Significant workovers that increase the properties’ reserves are capitalized. Ceiling Test The net capitalized costs of oil and natural gas properties are limited to the lower of unamortized costs less related deferred income taxes or the cost center “ceiling.” The cost center ceiling is defined as the sum of: (a) the present value, discounted at 10%, of future net revenues of proved oil and natural gas reserves, reduced by the estimated costs of developing these reserves, plus (b) unproved and unevaluated property costs not being amortized, plus (c) the lower of cost or estimated fair value of unproved and unevaluated properties included in the costs being amortized, if any, less (d) any income tax effects related to the properties involved. Any excess of the Company’s net capitalized costs above the cost center ceiling as described above is charged to operations as a full-cost ceiling impairment. The Company’s derivative instruments are not considered in the ceiling test computations as the Company does not designate these instruments as hedge instruments for accounting purposes. The estimated present value of after-tax future net cash flows from proved oil and natural gas reserves is highly dependent upon the quantities of proved reserves, the estimation of which requires substantial judgment. The associated commodity prices and the applicable discount rate used in these estimates are in accordance with guidelines established by the SEC. Under these guidelines, oil and natural gas reserves are estimated using then-current operating and economic conditions, with no provision for price and cost changes in future periods except by contractual arrangements. Future net revenues are calculated using prices that represent the arithmetic averages of the first-day-of-the-month oil and natural gas prices for the previous 12-month period, and a 10% discount factor is used to determine the present value of future net revenues. For the period from January through December 2022, these average oil and natural gas prices were $90.15 per Bbl and $6.36 per MMBtu, respectively. For the period from January through December 2021, these average oil and natural gas prices were $63.04 per Bbl and $3.60 per MMBtu, respectively. For the period from January through December 2020, these average oil and natural gas prices were $36.04 per Bbl and $1.99 per MMBtu, respectively. In estimating the present value of after-tax future net cash flows from proved oil and natural gas reserves, the average oil prices were further adjusted by property for quality, transportation and marketing fees and regional price differentials, and the average natural gas prices were further adjusted by property for energy content, transportation and marketing fees and regional price differentials. During the years ended December 31, 2022 and 2021, the Company’s full-cost ceiling exceeded the net capitalized costs less related deferred income taxes. As a result, the Company recorded no impairment to its net capitalized costs during the years ended December 31, 2022 and 2021. For the year ended December 31, 2020, the Company’s net capitalized costs less related deferred income taxes exceeded the full-cost ceiling. As a result, the Company recorded an impairment charge of $684.7 million, exclusive of tax effect, to its consolidated statement of operations for the year ended December 31, 2020 with the related deferred income tax benefit recorded net of a valuation allowance (see Note 8). As a non-cash item, the full-cost ceiling impairment impacts the accumulated depletion and the net carrying value of the Company’s assets on its consolidated balance sheets, as well as the corresponding shareholders’ equity, but it has no impact on the Company’s net cash flows as reported. Changes in oil and natural gas production rates, oil and natural gas prices, reserves estimates, future development costs and other factors will determine the Company’s actual ceiling test computation and impairment analyses in future periods. Midstream Properties and Other Property and Equipment Midstream properties and other property and equipment are recorded at historical cost and include midstream equipment and facilities, including the Company’s pipelines, processing facilities and produced water disposal systems, and corporate assets, including furniture, fixtures, equipment, land and leasehold improvements. Midstream equipment and facilities are depreciated over a 30-year useful life using the straight-line, mid-month convention method. Leasehold improvements are depreciated over the lesser of their useful lives or the term of the lease. Software, furniture, fixtures and other equipment are depreciated over their useful life ( five The Company evaluates midstream properties and other property and equipment for potential impairment whenever events or changes in circumstances indicate that their carrying value may not be recoverable. The carrying amount of a long-lived asset is not recoverable when it exceeds the undiscounted sum of the future cash flows expected to result from the use and eventual disposition of the asset. Expected future cash flows represent management’s estimates based on reasonable and supportable assumptions.
Asset Retirement Obligations	Asset Retirement ObligationsThe Company recognizes the fair value of an asset retirement obligation in the period in which it is incurred if a reasonable estimate of fair value can be made. The asset retirement obligation is recorded as a liability at its estimated present value, with an offsetting increase recognized in oil and natural gas properties, midstream properties or other property and equipment on the consolidated balance sheets. Periodic accretion of the discounted value of the estimated liability is recorded as an expense in the consolidated statements of operations.
Derivative Financial Instruments	Derivative Financial InstrumentsFrom time to time, the Company uses derivative financial instruments to mitigate its exposure to commodity price risk associated with oil, natural gas and NGL prices. The Company’s derivative financial instruments are recorded on the consolidated balance sheets as either an asset or a liability measured at fair value. The Company has elected not to apply hedge accounting for its existing derivative financial instruments, and as a result, the Company recognizes the change in derivative fair value between reporting periods currently in its consolidated statements of operations. The fair value of the Company’s derivative financial instruments is determined using industry-standard models that consider various inputs including: (i) quoted forward prices for commodities, (ii) time value of money and (iii) current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Realized gains and losses from the settlement of derivative financial instruments and unrealized gains and unrealized losses from valuation changes in the remaining unsettled derivative financial instruments are reported as a component of revenues in the consolidated statements of operations. See Note 12 for additional information about the Company’s derivative instruments.
Revenues	Revenues The Company enters into contracts with customers to sell its oil and natural gas production. Revenue from these contracts is recognized when the Company’s performance obligations under these contracts are satisfied, which generally occurs with the transfer of control of the oil and natural gas to the purchaser. Control is generally considered transferred when the following criteria are met: (i) transfer of physical custody, (ii) transfer of title, (iii) transfer of risk of loss and (iv) relinquishment of any repurchase rights or other similar rights. Given the nature of the products sold, revenue is recognized at a point in time based on the amount of consideration the Company expects to receive in accordance with the price specified in the contract. Consideration under oil and natural gas marketing contracts is typically received from the purchaser one The majority of the Company’s oil marketing contracts transfer physical custody and title at or near the wellhead or a central delivery point, which is generally when control of the oil has been transferred to the purchaser. The majority of the oil produced is sold under contracts using market-based pricing, which price is then adjusted for differentials based upon delivery location and oil quality. To the extent the differentials are incurred at or after the transfer of control of the oil, the differentials are included in oil revenues on the statements of operations, as they represent part of the transaction price of the contract. If the differentials, or other related costs, are incurred prior to the transfer of control of the oil, those costs are included in production taxes, transportation and processing expenses on the Company’s consolidated statements of operations, as they represent payment for services performed outside of the contract with the customer. The Company’s natural gas is sold at the lease location, at the inlet or outlet of a natural gas processing plant or at an interconnect near a marketing hub following transportation from a processing plant. The majority of the Company’s natural gas is sold under fee-based contracts. When the natural gas is sold at the lease, the purchaser gathers the natural gas via pipeline to natural gas processing plants where, if necessary, NGLs are extracted. The NGLs and remaining residue gas are then sold by the purchaser, or if the Company elects to take in-kind the natural gas or the NGLs, the Company sells the natural gas or the NGLs to a third party. Under the fee-based contracts, the Company receives NGL and residue gas value, less the fee component, or is invoiced the fee component. To the extent control of the natural gas transfers upstream of the gathering and processing activities, revenue is recognized as the net amount received from the purchaser. To the extent that control transfers downstream of those services, revenue is recognized on a gross basis, and the related costs are included in production taxes, transportation and processing expenses on the Company’s consolidated statements of operations. The Company recognizes midstream services revenues at the time services have been rendered and the price is fixed and determinable. Third-party midstream services revenues are those revenues from midstream operations related to third parties, including working interest owners in the Company’s operated wells. All midstream services revenues related to the Company’s working interest are eliminated in consolidation. Since the Company has a right to payment from its customers in amounts that correspond directly to the value that the customer receives from the performance completed on each contract, the Company applies the practical expedient in Accounting Standards Update 2014-09, Revenue from Contracts with Customers (Topic 606) (“ASC 606”) that allows recognition of revenue in the amount for which there is a right to invoice the customer without estimating a transaction price for each contract and allocating that transaction price to the performance obligations within each contract. The Company periodically enters into natural gas purchase transactions with third parties whereby the Company (i) purchases the third party’s natural gas and subsequently sells the natural gas to other purchasers or (ii) processes the third party’s natural gas at Pronto’s Marlan cryogenic natural gas processing plant in Eddy County, New Mexico or San Mateo’s Black River cryogenic natural gas processing plant in Eddy County, New Mexico (the “Black River Processing Plant”) and then purchases, and subsequently sells, the residue gas and NGLs to other purchasers. Revenues and expenses from these transactions are presented on a gross basis on the Company’s consolidated statements of operations as the Company acts as a principal in the transactions by assuming the risk and rewards of ownership, including credit risk, of the natural gas purchased and by assuming the responsibility to deliver and process the natural gas volumes to be sold. From time to time, the Company, as an owner of mineral interests, may enter into or extend a lease to a third-party lessee to develop the oil and natural gas attributable to certain of its mineral interests in return for a specified payment or lease bonus. In those instances, revenue is recognized in the period when the lease is signed and the Company has no further obligation to the lessee. The Company records these payments as “Lease bonus - mineral acreage” revenues on its consolidated statements of operations. The following table summarizes the Company’s total revenues and revenues from contracts with customers on a disaggregated basis for the years ended December 31, 2022, 2021 and 2020 (in thousands). Year Ended December 31, 2022 2021 2020 Revenues from contracts with customers $ 3,196,699 $ 1,862,075 $ 851,135 Lease bonus - mineral acreage — — 4,062 Realized (loss) gain on derivatives (157,483) (220,105) 38,937 Unrealized gain (loss) on derivatives 18,809 21,011 (32,008) Total revenues $ 3,058,025 $ 1,662,981 $ 862,126 Year Ended December 31, 2022 2021 2020 Oil revenues $ 2,113,606 $ 1,205,608 $ 595,507 Natural gas revenues 792,132 494,934 148,954 Third-party midstream services revenues 90,606 75,499 64,932 Sales of purchased natural gas 200,355 86,034 41,742 Total revenues from contracts with customers $ 3,196,699 $ 1,862,075 $ 851,135 The Company does not disclose the value of unsatisfied performance obligations under its contracts with customers as it applies the practical expedient in accordance with ASC 606. The expedient, as described in ASC 606-10-50-14(a), applies to variable consideration that is recognized as control of the product is transferred to the customer. Since each unit of product represents a separate performance obligation, future volumes are wholly unsatisfied and disclosure of the transaction price allocated to remaining performance obligations is not required.
Stock-Based Compensation	Stock-Based Compensation The Company may grant equity-based and liability-based common stock, stock options, restricted stock, restricted stock units, performance stock units and other awards permitted under any long-term incentive plan of the Company then in effect to members of its Board of Directors and certain employees, contractors and advisors. All equity-based awards are measured at
Income Taxes	Income Taxes The Company accounts for income taxes using the asset and liability approach for financial accounting and reporting. The Company evaluates the probability of realizing the future benefits of its deferred tax assets and records a valuation allowance for the portion of any deferred tax assets when it is more likely than not that the benefit from the deferred tax asset will not be realized. The Company recognizes the tax benefit of an uncertain tax position only if it is more likely than not that the tax position will be sustained upon examination by the taxing authorities based on the technical merits of the position. For tax positions meeting the more likely than not threshold, the amount recognized in the financial statements is the benefit that has a greater than 50% likelihood of being realized upon ultimate settlement with the relevant tax authority. At December 31, 2022, 2021 and 2020, the Company had not established any reserves for, nor recorded any unrecognized tax benefits related to, uncertain tax positions. When necessary, the Company would include interest assessed by taxing authorities in “Interest expense” and penalties related to income taxes in “Other expense” on its consolidated statements of operations. The Company did not record any interest or penalties related to income taxes for the years ended December 31, 2022, 2021 and 2020.
Earnings Per Common Share	Earnings Per Common Share The Company reports basic earnings attributable to Matador Resources Company shareholders per common share, which excludes the effect of potentially dilutive securities, and diluted earnings attributable to Matador Resources Company shareholders per common share, which includes the effect of all potentially dilutive securities, unless their impact is anti-dilutive. The following are reconciliations of the numerators and denominators used to compute the Company’s basic and diluted earnings per common share as reported for the years ended December 31, 2022, 2021 and 2020 (in thousands, except per share data). Year Ended December 31, 2022 2021 2020 Net income (loss) attributable to Matador Resources Company shareholders — numerator $ 1,214,206 $ 584,968 $ (593,205) Weighted average common shares outstanding — denominator Basic 118,122 116,999 116,068 Dilutive effect of options and restricted stock units 2,009 2,164 — Diluted weighted average common shares outstanding 120,131 119,163 116,068 Earnings (loss) per common share attributable to Matador Resources Company shareholders Basic $ 10.28 $ 5.00 $ (5.11) Diluted $ 10.11 $ 4.91 $ (5.11) A total of 2.5 million options to purchase shares of Matador’s common stock were excluded from the diluted weighted average common shares outstanding for the year ended December 31, 2020 because their effects were anti-dilutive. Additionally, 0.7 million restricted shares, which are participating securities, were excluded from the calculations above for the year ended December 31, 2020 as the security holders do not have the obligation to share in the losses of the Company.
Credit Risk	Credit Risk The Company’s cash is held in financial institutions and at times these amounts exceed the insurance limits of the Federal Deposit Insurance Corporation. Management believes, however, that the Company’s counterparty risks are minimal based on the reputation and history of the institutions selected. The Company uses derivative financial instruments to mitigate its exposure to oil, natural gas and NGL price volatility. These transactions expose the Company to potential credit risk from its counterparties. The Company manages counterparty credit risk through established internal derivatives policies that are reviewed on an ongoing basis. Additionally, the Company’s commodity derivative contract at December 31, 2022 was with PNC Bank, which is a lender under the Company’s reserves-based revolving credit agreement. Accounts receivable constitute the principal component of additional credit risk to which the Company may be exposed. The Company attempts to minimize credit risk exposure to counterparties by monitoring the financial condition and payment history of its purchasers and joint interest partners.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	12 Months Ended
Summary of Significant Accounting Policies (Tables)	Dec. 31, 2022
Accounting Policies [Abstract]
Disaggregation of Revenue	Year Ended December 31, 2022 2021 2020 Revenues from contracts with customers $ 3,196,699 $ 1,862,075 $ 851,135 Lease bonus - mineral acreage — — 4,062 Realized (loss) gain on derivatives (157,483) (220,105) 38,937 Unrealized gain (loss) on derivatives 18,809 21,011 (32,008) Total revenues $ 3,058,025 $ 1,662,981 $ 862,126 Year Ended December 31, 2022 2021 2020 Oil revenues $ 2,113,606 $ 1,205,608 $ 595,507 Natural gas revenues 792,132 494,934 148,954 Third-party midstream services revenues 90,606 75,499 64,932 Sales of purchased natural gas 200,355 86,034 41,742 Total revenues from contracts with customers $ 3,196,699 $ 1,862,075 $ 851,135
Reconciliations of basic and diluted distributed and undistributed earnings (loss) per common share	The following are reconciliations of the numerators and denominators used to compute the Company’s basic and diluted earnings per common share as reported for the years ended December 31, 2022, 2021 and 2020 (in thousands, except per share data). Year Ended December 31, 2022 2021 2020 Net income (loss) attributable to Matador Resources Company shareholders — numerator $ 1,214,206 $ 584,968 $ (593,205) Weighted average common shares outstanding — denominator Basic 118,122 116,999 116,068 Dilutive effect of options and restricted stock units 2,009 2,164 — Diluted weighted average common shares outstanding 120,131 119,163 116,068 Earnings (loss) per common share attributable to Matador Resources Company shareholders Basic $ 10.28 $ 5.00 $ (5.11) Diluted $ 10.11 $ 4.91 $ (5.11)

Property and Equipment (Tables)

Property and Equipment (Tables)	12 Months Ended
Property and Equipment (Tables)	Dec. 31, 2022
Property, Plant and Equipment [Abstract]
Summary of the Company's property and equipment	The following table presents a summary of the Company’s property and equipment balances as of December 31, 2022 and 2021 (in thousands). December 31, 2022 2021 Oil and natural gas properties Evaluated (subject to amortization) $ 6,862,455 $ 6,007,325 Unproved and unevaluated (not subject to amortization) 977,502 964,714 Total oil and natural gas properties 7,839,957 6,972,039 Accumulated depletion (4,362,292) (3,933,355) Net oil and natural gas properties 3,477,665 3,038,684 Midstream properties Midstream equipment and facilities 1,057,668 900,979 Accumulated depreciation (126,706) (92,574) Net midstream properties 930,962 808,405 Other property and equipment Furniture, fixtures and other equipment 13,257 10,923 Software 8,225 8,225 Leasehold improvements 11,365 10,975 Total other property and equipment 32,847 30,123 Accumulated depreciation (23,277) (20,527) Net other property and equipment 9,570 9,596 Net property and equipment $ 4,418,197 $ 3,856,685
Breakdown of the Company's unproved and unevaluated property costs not subject to amortization	The following table provides a breakdown of the Company’s unproved and unevaluated property costs not subject to amortization as of December 31, 2022 and the year in which these costs were incurred (in thousands). Description 2022 2021 2020 2019 2018 and prior Total Costs incurred for Property acquisition $ 97,748 $ 110,077 $ 40,355 $ 40,140 $ 606,740 $ 895,060 Exploration wells 32,364 942 354 802 36 34,498 Development wells 42,543 1,641 1,245 2,506 9 47,944 Total $ 172,655 $ 112,660 $ 41,954 $ 43,448 $ 606,785 $ 977,502

Leases (Tables)

Leases (Tables)	12 Months Ended
Leases (Tables)	Dec. 31, 2022
Leases [Abstract]
Lease, Cost	The following table presents supplemental consolidated statement of operations information related to lease expenses, on a gross basis, for the years ended December 31, 2022 and 2021, respectively (in thousands). Lease payments represent gross payments to vendors, which, for certain of the Company’s operating assets, are partially offset by amounts received from other working interest owners in the Company’s operated wells. Year Ended December 31, 2022 2021 Operating leases Lease operating $ 15,970 $ 11,393 Plant and other midstream services 285 36 General and administrative 3,266 3,645 Total operating leases (1) 19,521 15,074 Short-term leases Lease operating 17,437 11,234 Plant and other midstream services 4,359 4,037 General and administrative 34 37 Total short-term leases (2)(3) 21,830 15,308 Financing leases Depreciation of assets 571 566 Interest on lease liabilities 143 138 Total financing leases 714 704 Total lease expense $ 42,065 $ 31,086 _____________________ (1) Does not include gross payments related to drilling rig leases of $58.7 million and $31.9 million for the years ended December 31, 2022 and 2021, respectively, that were capitalized and recorded in “Oil and natural gas properties, full-cost method” in the consolidated balance sheets at December 31, 2022 and 2021, respectively. (2) These costs are related to leases that are not recorded as right of use assets or lease liabilities in the consolidated balance sheets as they are short-term leases. (3) Does not include gross payments related to short-term drilling rig leases and other equipment rentals of $101.5 million and $61.7 million for the years ended December 31, 2022 and 2021, respectively, that were capitalized and recorded in “Oil and natural gas properties, full-cost method” in the consolidated balance sheets at December 31, 2022 and 2021, respectively. The following table presents supplemental consolidated cash flow information related to lease payments for the years ended December 31, 2022 and 2021, respectively (in thousands). Year Ended December 31, 2022 2021 Cash paid related to lease liabilities Operating cash payments for operating leases $ 19,290 $ 14,430 Investing cash payments for operating leases $ 58,693 $ 31,967 Financing cash payments for financing leases $ 620 $ 629 Right of use assets obtained in exchange for lease obligations entered into during the period Operating leases $ 80,254 $ 18,454 Financing leases $ 1,511 $ 2,241
Assets And Liabilities, Lessee	The following table presents supplemental consolidated balance sheet information related to leases as of December 31, 2022 and 2021, respectively (in thousands). December 31, 2022 2021 Operating leases Other long-term assets $ 58,798 $ 29,519 Other current liabilities $ (43,921) $ (19,649) Other long-term liabilities (19,532) (15,340) Total operating lease liabilities $ (63,453) $ (34,989) Financing leases Other property and equipment, at cost $ 7,425 $ 5,914 Accumulated depreciation (4,470) (3,485) Net property and equipment $ 2,955 $ 2,429 Other current liabilities $ (685) $ (378) Other long-term liabilities (630) (45) Total financing lease liabilities $ (1,315) $ (423)
Lessee, Lease Terms	The following table presents the maturities of lease liabilities at December 31, 2022 (in years). Weighted-Average Remaining Lease Term December 31, 2022 Operating leases 1.8 Financing leases 2.4
Finance Lease, Liability, Maturity	The following table presents a schedule of future minimum lease payments required under all lease agreements as of December 31, 2022 (in thousands). December 31, 2022 Operating Leases Financing Leases 2023 $ 43,921 $ 685 2024 12,443 541 2025 6,218 309 2026 2,708 — 2027 572 — Thereafter — — Total lease payments 65,862 1,535 Less imputed interest (2,409) (220) Total lease obligations 63,453 1,315 Less current obligations (43,921) (685) Long-term lease obligations $ 19,532 $ 630
Lessee, Operating Lease, Liability, Maturity	The following table presents a schedule of future minimum lease payments required under all lease agreements as of December 31, 2022 (in thousands). December 31, 2022 Operating Leases Financing Leases 2023 $ 43,921 $ 685 2024 12,443 541 2025 6,218 309 2026 2,708 — 2027 572 — Thereafter — — Total lease payments 65,862 1,535 Less imputed interest (2,409) (220) Total lease obligations 63,453 1,315 Less current obligations (43,921) (685) Long-term lease obligations $ 19,532 $ 630

Asset Retirement Obligations (T

Asset Retirement Obligations (Tables)	12 Months Ended
Asset Retirement Obligations (Tables)	Dec. 31, 2022
Asset Retirement Obligation Disclosure [Abstract]
Schedule of changes in Company's asset retirement obligations	The following table summarizes the changes in the Company’s asset retirement obligations for the years ended December 31, 2022 and 2021 (in thousands). Year Ended December 31, 2022 2021 Beginning asset retirement obligations $ 41,959 $ 38,542 Liabilities incurred during period 4,069 2,294 Liabilities settled during period (1,198) (151) Revisions in estimated cash flows 10,794 86 Divestitures during the period (4,304) (880) Accretion expense 2,421 2,068 Ending asset retirement obligations 53,741 41,959 Less: current asset retirement obligations (1) (756) (270) Long-term asset retirement obligations $ 52,985 $ 41,689 __________________ (1) Included in “Accrued liabilities” in the Company’s consolidated balance sheets at December 31, 2022 and 2021.

Business Combinations and Asset

Business Combinations and Asset Acquisitions (Tables)	12 Months Ended
Business Combinations and Asset Acquisitions (Tables)	Dec. 31, 2022
Business Combination and Asset Acquisition [Abstract]
Schedule of Recognized Identified Assets Acquired and Liabilities Assumed	The allocation of the consideration given related to this business combination was as follows (in thousands), which the Company considered to be final as of September 30, 2022. Consideration given Allocation Cash $161,680 Working capital adjustments (4,444) Fair value of contingent consideration at December 14, 2021 6,718 Total consideration given $163,954 Allocation of purchase price Oil and natural gas properties Evaluated $139,312 Unproved and unevaluated 32,260 Accrued liabilities (360) Advances from joint interest owners (6,865) Asset retirement obligations (393) Net assets acquired $163,954 On June 30, 2022, the Company acquired a cryogenic gas processing plant, three compressor stations and approximately 45 miles of natural gas gathering pipelines in Lea and Eddy Counties, New Mexico as part of the acquisition (the “Pronto Acquisition”) of a wholly-owned subsidiary of Summit Midstream Partners, LP that was subsequently renamed Pronto. This acquisition was also accounted for as a business combination in accordance with ASC Topic 805. In addition, the Company assumed certain takeaway capacity on a Federal Energy Regulatory Commission regulated natural gas pipeline. As consideration for the business combination, the Company paid approximately $77.8 million in cash, subject to certain customary post-closing purchase price adjustments. The pro forma impact of this business combination to revenues and net income for 2022 would not be material to the Company’s 2022 revenues and net income as reported. The allocation of the consideration given related to this business combination was as follows (in thousands), which the Company considered to be final as of December 31, 2022. Consideration given Allocation Total cash consideration given $ 77,828 Allocation of purchase price Cash acquired $ 2,012 Property, plant & equipment 74,100 Accounts receivable 6,093 Other assets 296 Accrued liabilities (4,673) Net assets acquired $ 77,828

Debt (Tables)

Debt (Tables)	12 Months Ended
Debt (Tables)	Dec. 31, 2022
Debt Disclosure [Abstract]
Debt Instrument Redemption	The Company may redeem all or a part of the Notes at any time or from time to time at the following redemption prices (expressed as percentages of principal amount) plus accrued and unpaid interest, if any, to the applicable redemption date, if redeemed during the twelve-month period beginning on September 15 of the years indicated below: Year Redemption Price 2022 102.938% 2023 101.469% 2024 and thereafter 100.000%

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Summary of net deferred tax position	The Company’s net deferred tax position as of December 31, 2022 and 2021 is as follows (in thousands). December 31, 2022 2021 Deferred tax assets Net operating loss carryforwards $ 12,874 $ 129,651 Unrealized loss on derivatives — 3,729 Percentage depletion carryover 8 1,770 Compensation 14,184 9,838 Lease liabilities 12,585 4,866 Other 1,926 9,410 Total deferred tax assets 41,577 159,264 Valuation allowance on deferred tax assets (11,322) (10,599) Total deferred tax assets, net of valuation allowance 30,255 148,665 Deferred tax liabilities Unrealized gain on derivatives (995) — Property and equipment (368,283) (179,153) Less than wholly-owned subsidiaries (63,388) (39,900) Lease right of use assets (12,585) (4,866) Other (13,355) (2,684) Total deferred tax liabilities (458,606) (226,603) Net deferred tax liabilities $ (428,351) $ (77,938)
Income tax expense reconciled to the tax computed at the statutory federal rate	The current income tax provision and the deferred income tax provision for the years ended December 31, 2022, 2021 and 2020 were comprised of the following (in thousands). Year Ended December 31, 2022 2021 2020 Current income tax provision Federal income tax $ 31,335 $ — $ — State income tax 23,542 — — Net current income tax provision $ 54,877 $ — $ — Deferred income tax provision (benefit) Federal income tax $ 302,486 $ 44,883 $ (25,675) State income tax 41,994 29,827 (19,924) Net deferred income tax provision (benefit) $ 344,480 $ 74,710 $ (45,599) Reconciliations of the tax expense (benefit) computed at the statutory federal rate to the Company’s total income tax provision (benefit) for the years ended December 31, 2022, 2021 and 2020 is as follows (in thousands). Year Ended December 31, 2022 2021 2020 Federal tax expense (benefit) at statutory rate (1) $ 353,992 $ 150,223 $ (125,823) State income tax expense (benefit) 59,870 26,646 (20,607) Permanent differences (15,227) (2,078) (3,114) Change in federal valuation allowance — (103,262) 103,262 Change in state valuation allowance 722 3,181 683 Total income tax provision (benefit) $ 399,357 $ 74,710 $ (45,599) __________________ (1) The statutory federal tax rate was 21% for the years ended December 31, 2022, 2021 and 2020.

Stock-Based Compensation (Table

Stock-Based Compensation (Tables)	12 Months Ended
Stock-Based Compensation (Tables)	Dec. 31, 2022
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Summarized information about stock options outstanding	Summarized information about stock options outstanding at December 31, 2022 under the 2012 Incentive Plan and the 2019 Incentive Plan (collectively, the “LTIPs”) is as follows. Number of options (in thousands) Weighted Options outstanding at December 31, 2021 603 $ 22.92 Options granted — $ — Options exercised (445) $ 24.35 Options forfeited (8) $ 14.80 Options expired — $ — Options outstanding at December 31, 2022 150 $ 19.11
Summarized information about outstanding and exercisable stock option	Options outstanding at December 31, 2022 Options exercisable at December 31, 2022 Range of exercise prices Shares outstanding (in thousands) Weighted Weighted Shares exercisable (in thousands) Weighted $14.48 - $14.80 103 2.66 $ 14.80 103 $ 14.80 $26.86 - $29.68 47 0.74 $ 28.60 47 $ 28.60
Summary of the non-vested restricted stock and restricted stock units	A summary of the non-vested equity-based restricted stock and restricted stock units as of December 31, 2022 is presented below (in thousands, except fair value). Restricted Stock Restricted Stock Units Service Based Service Based Performance Based Non-vested restricted stock and Shares Weighted Shares Weighted Shares Weighted Non-vested at December 31, 2021 589 $ 24.59 33 $ 33.39 963 $ 20.26 Granted 236 $ 45.58 16 $ 66.16 230 $ 65.49 Vested (1) (126) $ 24.07 (33) $ 33.39 (597) $ 1.74 Forfeited (41) $ 19.12 — $ — — $ — Non-vested at December 31, 2022 658 $ 24.59 16 $ 66.16 596 $ 56.31 __________________ (1) On December 31, 2022, 597,414 of the performance-based awards that were granted in 2020 vested. The vested units earned 175% for each vested award representing 1,045,472 aggregate shares of common stock, which were issued on December 31, 2022.
2012 Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average assumptions used to estimate fair value of stock options granted under the Stock and Incentive Plan	The Company did not grant stock option awards during the years ended December 31, 2022, 2021 and 2020.

Derivative Financial Instrume_2

Derivative Financial Instruments (Tables)	12 Months Ended
Derivative Financial Instruments (Tables)	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Summary of contracts for oil and natural gas	The following is a summary of the Company’s open costless collar contract at December 31, 2022. Notional Quantity (MMBtu) Weighted Average Price Floor ($/MMBtu) Weighted Average Price Ceiling ($/MMBtu) Fair Value of Asset (Liability) (thousands) Commodity Calculation Period Natural Gas 01/01/2023 - 03/31/2023 2,400,000 $ 6.00 $ 14.00 3,931 Total open costless collar contracts $ 3,931
Summary of offsetting assets	The following table presents the gross asset and liability fair values of the Company’s commodity price derivative financial instruments and the location of these balances in the consolidated balance sheets as of December 31, 2022 and December 31, 2021 (in thousands). Derivative Instruments Gross amounts recognized Gross amounts netted in the consolidated balance sheets Net amounts presented in the consolidated balance sheets December 31, 2022 Current assets $ 3,931 $ — $ 3,931 Current liabilities — — — Total $ 3,931 $ — $ 3,931 December 31, 2021 Current assets $ 215,145 $ (213,174) $ 1,971 Current liabilities (230,023) 213,174 (16,849) Total $ (14,878) $ — $ (14,878)
Summary of offsetting liabilities	The following table presents the gross asset and liability fair values of the Company’s commodity price derivative financial instruments and the location of these balances in the consolidated balance sheets as of December 31, 2022 and December 31, 2021 (in thousands). Derivative Instruments Gross amounts recognized Gross amounts netted in the consolidated balance sheets Net amounts presented in the consolidated balance sheets December 31, 2022 Current assets $ 3,931 $ — $ 3,931 Current liabilities — — — Total $ 3,931 $ — $ 3,931 December 31, 2021 Current assets $ 215,145 $ (213,174) $ 1,971 Current liabilities (230,023) 213,174 (16,849) Total $ (14,878) $ — $ (14,878)
Summary of location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations	The following table summarizes the location and aggregate gain (loss) of all derivative financial instruments recorded in the consolidated statements of operations for the periods presented (in thousands). Year Ended December 31, Type of Instrument Location in Statements of Operations 2022 2021 2020 Derivative Instrument Oil Revenues: Realized (loss) gain on derivatives $ (75,806) $ (194,058) $ 38,937 Natural Gas Revenues: Realized loss on derivatives (81,677) (26,047) — Realized (loss) gain on derivatives (157,483) (220,105) 38,937 Oil Revenues: Unrealized gain (loss) on derivatives 14,727 26,857 (37,703) Natural Gas Revenues: Unrealized gain (loss) on derivatives 4,082 (5,846) 5,695 Unrealized gain (loss) on derivatives 18,809 21,011 (32,008) Total $ (138,674) $ (199,094) $ 6,929

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
Fair Value Measurements (Tables)	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Summary of the valuation of the Company's financial assets and liabilities that were accounted for at fair value on a recurring basis	The following tables summarize the valuation of the Company’s financial assets and liabilities that were accounted for at fair value on a recurring basis in accordance with the classifications provided above as of December 31, 2022 and 2021 (in thousands). Fair Value Measurements at Description Level 1 Level 2 Level 3 Total Assets (Liabilities) Natural gas derivatives $ — $ 3,931 $ — $ 3,931 Total $ — $ 3,931 $ — $ 3,931 Fair Value Measurements at Description Level 1 Level 2 Level 3 Total Assets (Liabilities) Oil derivatives and basis swaps $ — $ (14,727) $ — $ (14,727) Natural gas derivatives — (151) — (151) Contingent consideration related to business combination — — (8,203) $ (8,203) Total $ — $ (14,878) $ (8,203) $ (23,081)

Supplemental Disclosures (Table

Supplemental Disclosures (Tables)	12 Months Ended
Supplemental Disclosures (Tables)	Dec. 31, 2022
Supplemental Disclosures [Abstract]
Summary of current accrued liabilities	The following table summarizes the Company’s current accrued liabilities at December 31, 2022 and 2021 (in thousands). December 31, 2022 2021 Accrued evaluated and unproved and unevaluated property costs $ 112,766 $ 128,598 Accrued midstream properties costs 11,623 7,799 Accrued lease operating expenses 46,975 32,182 Accrued interest on debt 10,461 18,232 Accrued asset retirement obligations 756 270 Accrued partners’ share of joint interest charges 42,199 17,460 Accrued payable related to purchased natural gas 11,158 11,284 Other 25,372 37,458 Total accrued liabilities $ 261,310 $ 253,283
Supplemental disclosures of cash flow information	The following table provides supplemental disclosures of cash flow information for the years ended December 31, 2022, 2021 and 2020 (in thousands). Year Ended December 31, 2022 2021 2020 Cash paid for income taxes $ 63,500 $ — $ — Cash paid for interest expense, net of amounts capitalized $ 72,561 $ 74,843 $ 76,880 Increase (decrease) in asset retirement obligations related to mineral properties $ 9,111 $ 1,091 $ (208) Increase in asset retirement obligations related to midstream properties $ 251 $ 257 $ 690 (Decrease) increase in liabilities for drilling, completion and equipping capital expenditures $ (13,304) $ 80,255 $ (26,126) (Decrease) increase in liabilities for acquisition of oil and natural gas properties $ (2,531) $ 2,981 $ (2,346) Increase (decrease) in liabilities for midstream capital expenditures $ 3,824 $ (4,478) $ (33,609) Stock-based compensation expense recognized as liability $ 31,906 $ 24,494 $ 3,702 Transfer of inventory from (to) oil and natural gas properties $ 148 $ (398) $ 608 The following table provides a reconciliation of cash and restricted cash recorded in the consolidated balance sheets to cash and restricted cash as presented on the consolidated statements of cash flows (in thousands). Year Ended December 31, 2022 2021 2020 Cash $ 505,179 $ 48,135 $ 57,916 Restricted cash 42,151 38,785 33,467 Total cash and restricted cash $ 547,330 $ 86,920 $ 91,383

Segment Reporting (Tables)

Segment Reporting (Tables)	12 Months Ended
Segment Reporting (Tables)	Dec. 31, 2022
Segment Reporting [Abstract]
Schedule of Segment Reporting Information, by Segment	The following tables present selected financial information for the periods presented regarding the Company’s business segments on a stand-alone basis, corporate expenses that are not allocated to a segment and the consolidation and elimination entries necessary to arrive at the financial information for the Company on a consolidated basis (in thousands). On a consolidated basis, midstream services revenues consist primarily of those revenues from midstream operations related to third parties, including working interest owners in the Company’s operated wells. All midstream services revenues associated with Company-owned production are eliminated in consolidation. In evaluating the operating results of the exploration and production and midstream segments, the Company does not allocate certain expenses to the individual segments, including general and administrative expenses. Such expenses are reflected in the column labeled “Corporate.” Exploration and Production Consolidations and Eliminations Consolidated Company Midstream Corporate Year Ended December 31, 2022 Oil and natural gas revenues $ 2,897,336 $ 8,402 $ — $ — $ 2,905,738 Midstream services revenues — 298,184 — (207,578) 90,606 Sales of purchased natural gas 116,772 83,583 — — 200,355 Realized loss on derivatives (157,483) — — — (157,483) Unrealized gain on derivatives 18,809 — — — 18,809 Expenses (1) 1,177,104 227,556 101,673 (207,578) 1,298,755 Operating income (2) $ 1,698,330 $ 162,613 $ (101,673) $ — $ 1,759,270 Total assets (3) $ 4,022,609 $ 1,016,580 $ 515,316 $ — $ 5,554,505 Capital expenditures (4) $ 903,518 $ 158,544 $ 1,213 $ — $ 1,063,275 _____________________ (1) Includes depletion, depreciation and amortization expenses of $429.7 million and $34.7 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $2.0 million. (2) Includes $72.1 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment. (3) Excludes intercompany receivables and investments in subsidiaries. (4) Includes $131.0 million attributable to land and seismic acquisition expenditures related to the exploration and production segment, $75.8 million in midstream acquisition expenditures and $39.6 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment. Exploration and Production Consolidations and Eliminations Consolidated Company Midstream Corporate Year Ended December 31, 2021 Oil and natural gas revenues $ 1,695,032 $ 5,510 $ — $ — $ 1,700,542 Midstream services revenues — 228,817 — (153,318) 75,499 Sales of purchased natural gas 47,398 38,636 — — 86,034 Realized loss on derivatives (220,105) — — — (220,105) Unrealized gain on derivatives 21,011 — — — 21,011 Expenses (1) 794,880 142,444 85,899 (153,318) 869,905 Operating (loss) income (2) $ 748,456 $ 130,519 $ (85,899) $ — $ 793,076 Total assets (3) $ 3,324,681 $ 879,672 $ 57,800 $ — $ 4,262,153 Capital expenditures (4) $ 778,191 $ 59,361 $ 376 $ — $ 837,928 _____________________ (1) Includes depletion, depreciation and amortization expenses of $310.9 million and $31.5 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $2.6 million. (2) Includes $55.7 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment. (3) Excludes intercompany receivables and investments in subsidiaries. (4) Includes $263.5 million attributable to land and seismic acquisition expenditures related to the exploration and production segment and $28.5 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment. Exploration and Production Consolidations and Eliminations Consolidated Company Midstream Corporate Year Ended December 31, 2020 Oil and natural gas revenues $ 741,092 $ 3,369 $ — $ — $ 744,461 Midstream services revenues — 166,194 — (101,262) 64,932 Sales of purchased natural gas 20,736 21,006 — — 41,742 Lease bonus - mineral acreage 4,062 — — — 4,062 Realized gain on derivatives 38,937 — — — 38,937 Unrealized loss on derivatives (32,008) — — — (32,008) Expenses (1) 1,334,378 97,599 52,910 (101,262) 1,383,625 Operating income (loss) (2) $ (561,559) $ 92,970 $ (52,910) $ — $ (521,499) Total assets (3) $ 2,782,819 $ 836,509 $ 67,952 $ — $ 3,687,280 Capital expenditures (4) $ 518,198 $ 201,440 $ 2,200 $ — $ 721,838 _____________________ (1) Includes depletion, depreciation and amortization expenses of $335.8 million and $23.3 million for the exploration and production and midstream segments, respectively. Includes full-cost ceiling impairment of $684.7 million for the exploration and production segment. Also includes corporate depletion, depreciation and amortization expenses of $2.7 million. (2) Includes $39.6 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment. (3) Excludes intercompany receivables and investments in subsidiaries. (4) Includes $70.5 million attributable to land and seismic acquisition expenditures related to the exploration and production segment and $112.1 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment.

Summary of Significant Accoun_4

Summary of Significant Accounting Policies Summary of Significant Accounting Policies (Details Textual)	12 Months Ended
	Dec. 31, 2022 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2022 USD ($) purchaser	Dec. 31, 2022 USD ($)	Dec. 31, 2022 USD ($) $ / bbl	Dec. 31, 2022 USD ($) $ / MMBTU	Dec. 31, 2021 USD ($)	Dec. 31, 2021 USD ($) purchaser	Dec. 31, 2021 USD ($)	Dec. 31, 2021 USD ($) $ / bbl	Dec. 31, 2021 USD ($) $ / MMBTU	Dec. 31, 2020 USD ($)	Dec. 31, 2020 purchaser	Dec. 31, 2020	Dec. 31, 2020 $ / bbl	Dec. 31, 2020 $ / MMBTU	Dec. 31, 2020 shares
Property, Plant and Equipment [Line Items]
Billing date	30 days
Outstanding days of account receivable	60 days
Allowance for doubtful accounts	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0
Number of purchasers \| purchaser			3					3					2
Capitalized general and administrative costs		47,800,000					38,400,000					$ 30,000,000
Capitalized interest expense		10,100,000					4,800,000					5,000,000
Depletion		(428,900,000)					(310,100,000)					(334,800,000)
Previous period used for price calculation	12 months
Present value discounted percent of future net revenues of proved oil and natural gas reserves				10%
Average oil and natural gas prices					90.15	6.36				63.04	3.60				36.04	1.99
Impairment charge of net capitalized costs		0					0					684,743,000
Stock-based compensation (non-cash) expense		15,123,000					9,039,000					13,625,000
Common stock and restricted stock unit expense		1,000,000					900,000					1,000,000
Compensation expense, liability-based awards		31,900,000					20,400,000					4,000,000
Minimum
Property, Plant and Equipment [Line Items]
Accounts receivable due period	30 days
Contract term after production	1 month
Maximum
Property, Plant and Equipment [Line Items]
Accounts receivable due period	60 days
Contract term after production	2 months
Plains Marketing, L.P. \| Customer Concentration Risk \| Sales Revenue, Goods, Net
Property, Plant and Equipment [Line Items]
Concentration risk, percentage				27%					29%					57%
Plains Marketing, L.P. \| Customer Concentration Risk \| Accounts Receivable
Property, Plant and Equipment [Line Items]
Concentration risk, percentage				29%
BP America Production Company \| Customer Concentration Risk \| Sales Revenue, Goods, Net
Property, Plant and Equipment [Line Items]
Concentration risk, percentage				9%					10%
BP America Production Company \| Customer Concentration Risk \| Accounts Receivable
Property, Plant and Equipment [Line Items]
Concentration risk, percentage														35%
Exxon Mobil Corporate \| Customer Concentration Risk \| Sales Revenue, Goods, Net
Property, Plant and Equipment [Line Items]
Concentration risk, percentage				34%					33%					8%
Exxon Mobil Corporate \| Customer Concentration Risk \| Accounts Receivable
Property, Plant and Equipment [Line Items]
Concentration risk, percentage									39%
Two Significant Customers \| Customer Concentration Risk \| Sales Revenue, Goods, Net
Property, Plant and Equipment [Line Items]
Concentration risk, percentage									72%					65%
Three Significant Customers \| Customer Concentration Risk \| Sales Revenue, Goods, Net
Property, Plant and Equipment [Line Items]
Concentration risk, percentage				70%
Machinery and Equipment
Property, Plant and Equipment [Line Items]
Capitalized general and administrative costs		$ 2,200,000					$ 1,300,000					1,800,000
Capitalized interest expense												$ 500,000
Useful life using the straight-line	30 years
Machinery and Equipment \| Minimum
Property, Plant and Equipment [Line Items]
Useful life	5 years
Machinery and Equipment \| Maximum
Property, Plant and Equipment [Line Items]
Useful life	30 years
Employee Stock Options
Property, Plant and Equipment [Line Items]
Antidilutive options excluded from calculation (in shares) \| shares																	2,500,000
Restricted Stock
Property, Plant and Equipment [Line Items]
Antidilutive options excluded from calculation (in shares) \| shares																	700,000

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Earnings Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Accounting Policies [Abstract]
Net income (loss) attributable to Matador Resources Company shareholders — numerator	$ 1,214,206	$ 584,968	$ (593,205)
Weighted average common shares outstanding — denominator
Basic (in shares)	118,122	116,999	116,068
Dilutive effect of options and restricted stock units (in shares)	2,009	2,164	0
Diluted weighted average common shares outstanding (in shares)	120,131	119,163	116,068
Earnings (loss) per common share attributable to Matador Resources Company shareholders
Basic (usd per share)	$ 10.28	$ 5	$ (5.11)
Diluted (usd per share)	$ 10.11	$ 4.91	$ (5.11)

Summary of Significant Accoun_6

Summary of Significant Accounting Policies Summary of Significant Accounting Policies - Disaggregated Revenue (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	$ 3,196,699	$ 1,862,075	$ 851,135
Lease bonus - mineral acreage	0	0	4,062
Realized gain on derivatives	(157,483)	(220,105)	38,937
Unrealized gain on derivatives	18,809	21,011	(32,008)
Total revenues	3,058,025	1,662,981	862,126
Oil
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	2,113,606	1,205,608	595,507
Natural gas revenues
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	792,132	494,934	148,954
Third-party midstream services revenues
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	90,606	75,499	64,932
Sales of purchased natural gas
Disaggregation of Revenue [Line Items]
Revenue from contract with customer	$ 200,355	$ 86,034	$ 41,742

Property and Equipment (Details

Property and Equipment (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Oil and natural gas properties
Evaluated (subject to amortization)	$ 6,862,455	$ 6,007,325
Total unproved and unevaluated	977,502	964,714
Total oil and natural gas properties	7,839,957	6,972,039
Accumulated depletion	(4,362,292)	(3,933,355)
Net oil and natural gas properties	3,477,665	3,038,684
Midstream Properties [Abstract]
Midstream properties	1,057,668	900,979
Accumulated depreciation	4,512,275	4,046,456
Other property and equipment
Other property and equipment	32,847	30,123
Accumulated depreciation	(23,277)	(20,527)
Net other property and equipment	9,570	9,596
Net property and equipment	4,418,197	3,856,685
Midstream equipment and facilities
Midstream Properties [Abstract]
Midstream properties	1,057,668	900,979
Accumulated depreciation	126,706	92,574
Net midstream properties	930,962	808,405
Furniture, fixtures and other equipment
Other property and equipment
Other property and equipment	13,257	10,923
Software
Other property and equipment
Other property and equipment	8,225	8,225
Leasehold improvements
Other property and equipment
Other property and equipment	$ 11,365	$ 10,975

Property and Equipment (Detai_2

Property and Equipment (Details 1) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Costs incurred for
Total unproved and unevaluated	$ 977,502	$ 964,714
2022
Costs incurred for
Property acquisition	97,748
Exploration wells	32,364
Development wells	42,543
Total unproved and unevaluated	172,655
2021
Costs incurred for
Property acquisition		110,077
Exploration wells		942
Development wells		1,641
Total unproved and unevaluated		$ 112,660
2020
Costs incurred for
Property acquisition			$ 40,355
Exploration wells			354
Development wells			1,245
Total unproved and unevaluated			41,954
2019
Costs incurred for
Property acquisition			40,140
Exploration wells			802
Development wells			2,506
Total unproved and unevaluated			$ 43,448
2017 and prior
Costs incurred for
Property acquisition				$ 606,740
Exploration wells				36
Development wells				9
Total unproved and unevaluated				$ 606,785
Total
Costs incurred for
Property acquisition	895,060
Exploration wells	34,498
Development wells	47,944
Total unproved and unevaluated	$ 977,502

Property and Equipment (Detai_3

Property and Equipment (Details Textual) $ in Thousands	Dec. 31, 2022 USD ($)
Property, Plant and Equipment [Line Items]
Anticipated amount for wells	$ 82,400
Projects Inception to Date
Property, Plant and Equipment [Line Items]
Exploration costs	34,498
Development wells	$ 47,944

Leases - Narrative (Details)

Leases - Narrative (Details)	Dec. 31, 2022
Leases [Abstract]
Incremental borrowing rate, operating leases	3.68%
Incremental borrowing rate, finance leases	4.20%

Leases - Components of Lease Ex

Leases - Components of Lease Expense (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Lessee, Lease, Description [Line Items]
Operating leases	$ 19,521	$ 15,074
Short-term leases	21,830	15,308
Financing leases
Depreciation of assets	571	566
Interest on lease liabilities	143	138
Total financing leases	714	704
Total lease expense	42,065	31,086
Lease operating
Lessee, Lease, Description [Line Items]
Operating leases	15,970	11,393
Short-term leases	17,437	11,234
Plant and other midstream services
Lessee, Lease, Description [Line Items]
Operating leases	285	36
Short-term leases	4,359	4,037
General and administrative
Lessee, Lease, Description [Line Items]
Operating leases	3,266	3,645
Short-term leases	34	37
Drilling Rig Leases
Financing leases
Gross payments	58,700	31,900
Drilling Rig Leases And Other Equipment Rentals
Financing leases
Gross payments	$ 101,500	$ 61,700

Leases - Balance Sheet Informat

Leases - Balance Sheet Information (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Operating leases
Right-of-use asset	$ 58,798	$ 29,519
Other current liabilities	$ (43,921)	$ (19,649)
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	Other Liabilities, Current	Other Liabilities, Current
Other long-term liabilities	$ (19,532)	$ (15,340)
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Total operating lease liabilities	$ (63,453)	$ (34,989)
Financing leases
Other property and equipment, at cost	7,425	5,914
Accumulated depreciation	$ (4,470)	$ (3,485)
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Property, Plant and Equipment, Net	Property, Plant and Equipment, Net
Net property and equipment	$ 2,955	$ 2,429
Finance Lease, Liability, Current, Statement of Financial Position [Extensible List]	Other Liabilities, Current	Other Liabilities, Current
Other current liabilities	$ (685)	$ (378)
Finance Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	Other Liabilities, Noncurrent	Other Liabilities, Noncurrent
Other long-term liabilities	$ (630)	$ (45)
Total financing lease liabilities	$ (1,315)	$ (423)
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	Other Assets, Noncurrent	Other Assets, Noncurrent

Leases - Cash Flow Information

Leases - Cash Flow Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Cash paid related to lease liabilities
Operating cash payments for operating leases	$ 19,290	$ 14,430
Investing cash payments for operating leases	58,693	31,967
Financing cash payments for financing leases	620	629
Right of use assets obtained in exchange for lease obligations entered into during the period
Operating leases	80,254	18,454
Financing leases	$ 1,511	$ 2,241

Leases - Lease Terms (Details)

Leases - Lease Terms (Details)	Dec. 31, 2022
Weighted-Average Remaining Lease Term
Operating leases	1 year 9 months 18 days
Financing leases	2 years 4 months 24 days

Leases - Lease Payment Maturity

Leases - Lease Payment Maturity Schedule (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Operating Leases
2021	$ 43,921
2022	12,443
2024	2,708
2025	572
Thereafter	0
Total lease payments	65,862
Less imputed interest	(2,409)
Lease liability	63,453	$ 34,989
Less current obligations	(43,921)	(19,649)
Long-term lease obligations	19,532	15,340
Financing Leases
2021	685
2022	541
2023	309
2024	0
2025	0
Thereafter	0
Total lease payments	1,535
Less imputed interest	(220)
Total lease obligations	1,315	423
Less current obligations	(685)	(378)
Long-term lease obligations	630	$ 45
2022	$ 6,218

Leases Leases - Maturities of O

Leases Leases - Maturities of Office Leases (Details) $ in Thousands	Dec. 31, 2022 USD ($)
Leases [Abstract]
2021	$ 43,921
2022	12,443
2022	6,218
2024	2,708
2025	572
Thereafter	0
Total lease payments	$ 65,862

Asset Retirement Obligations (D

Asset Retirement Obligations (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Changes in the Company's asset retirement obligations
Beginning asset retirement obligations	$ 41,959	$ 38,542
Liabilities incurred during period	4,069	2,294
Liabilities settled during period	(1,198)	(151)
Revisions in estimated cash flows	10,794	86
Divestitures during the period	(4,304)	(880)
Accretion expense	2,421	2,068
Ending asset retirement obligations	53,741	41,959
Less: current asset retirement obligations	(756)	(270)
Long-term asset retirement obligations	$ 52,985	$ 41,689

Business Combinations and Div_2

Business Combinations and Divestitures (Details) $ in Thousands					12 Months Ended									46 Months Ended	48 Months Ended
	Jun. 30, 2022 USD ($) compressorStation mi	Dec. 14, 2021 USD ($) $ / bbl	Feb. 25, 2019 USD ($)	Feb. 17, 2017 USD ($)	Dec. 31, 2022 USD ($) compressorStation well mi	Dec. 31, 2022 USD ($) compressorStation well mi $ / bbl	Dec. 31, 2022 USD ($) compressorStation well mi $ / MMBTU	Dec. 31, 2021 USD ($)	Dec. 31, 2021 USD ($) $ / bbl	Dec. 31, 2021 USD ($) $ / MMBTU	Dec. 31, 2020 USD ($)	Dec. 31, 2020 USD ($) $ / bbl	Dec. 31, 2020 USD ($) $ / MMBTU	Dec. 31, 2022 USD ($) compressorStation well mi	Feb. 23, 2021 USD ($)	Sep. 30, 2022 USD ($)
Business Acquisition [Line Items]
Oil and Gas, average sale price						90.15	6.36		63.04	3.60		36.04	1.99
Compressor stations \| compressorStation					12	12	12							12
Deferred tax impact					$ 5,900	$ 5,900	$ 5,900	$ 3,600	$ 3,600	$ 3,600				$ 5,900
Distributions to noncontrolling interest holders					85,995			61,985			$ 45,570
Additional paid-in capital					2,101,999	2,101,999	2,101,999	2,077,592	$ 2,077,592	$ 2,077,592				2,101,999
Proceeds from divestiture of businesses					46,500			4,200
Properties in Lea and Eddy, NM
Business Acquisition [Line Items]
Consideration transferred		$ 161,700
Purchase price increase (decrease) due to average oil price		5,000			15,000
Increase (decrease) for contract acquired in business combination					11,800			1,500
Contingent consideration related to business combination					5,000	$ 5,000	$ 5,000							$ 5,000
Working capital adjustments																$ (4,444)
Fair value of contingent consideration at December 14, 2021		$ 6,718
Properties in Lea and Eddy, NM \| Minimum
Business Acquisition [Line Items]
Oil and Gas, average sale price \| $ / bbl		75
Summit Midstream
Business Acquisition [Line Items]
Consideration transferred	$ 77,828
Compressor stations \| compressorStation	3
Oil and gas pipeline \| mi	45
San Mateo Midstream
Business Acquisition [Line Items]
Proceeds from joint venture					$ 89,500			64,500			47,400
Corporate Joint Venture \| San Mateo Midstream
Business Acquisition [Line Items]
Oil and gas pipeline \| mi					415	415	415							415
Subsidiary ownership percentage				51%
Number of wells contributed to joint venture \| well					15	15	15							15
Deferred performance incentives			$ 150,000	$ 73,500
Deferred performance incentives, term				5 years
Remaining performance incentives available to be earned, up to				$ 14,700
Five Point
Business Acquisition [Line Items]
Proceeds from joint venture					$ 28,300			$ 33,900
Five Point \| Corporate Joint Venture \| San Mateo Midstream
Business Acquisition [Line Items]
Subsidiary ownership percentage					49%	49%	49%							49%
Earnings from equity method investments														$ 62,200
Payments for deferred performance incentives															$ 14,700
Rustler Breaks and Wolf Asset Area \| Corporate Joint Venture \| San Mateo Midstream
Business Acquisition [Line Items]
Contractual obligation, term				15 years
Rustler Breaks Asset Area \| Corporate Joint Venture \| San Mateo Midstream
Business Acquisition [Line Items]
Contractual obligation, term				15 years
San Mateo Midstream \| Five Point \| Corporate Joint Venture
Business Acquisition [Line Items]
Contributions to joint venture											119,700
Additional paid-in capital											23,100	$ 23,100	$ 23,100
Tax impact of equity contribution											4,800
San Mateo Midstream \| Matador Resources Company \| Corporate Joint Venture
Business Acquisition [Line Items]
Contributions to joint venture											$ 75,000

Business Combinations and Div_3

Business Combinations and Divestitures - Allocation Schedule (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Sep. 30, 2022	Dec. 31, 2021	Dec. 14, 2021
Business Acquisition [Line Items]
Evaluated (subject to amortization)	$ 6,862,455		$ 6,007,325
Total unproved and unevaluated	977,502		964,714
Advances from joint interest owners	(52,357)		$ (18,074)
Properties in Lea and Eddy, NM
Business Acquisition [Line Items]
Cash				$ 161,680
Working capital adjustments		$ (4,444)
Fair value of contingent consideration at December 14, 2021				$ 6,718
Total consideration given		163,954
Evaluated (subject to amortization)		139,312
Total unproved and unevaluated		32,260
Contingent consideration related to business combination		(360)
Advances from joint interest owners		(6,865)
Asset retirement obligations		$ (393)
Summit Midstream
Business Acquisition [Line Items]
Cash	2,012
Property, plant & equipment	74,100
Accounts receivable	6,093
Other assets	296
Accrued liabilities	(4,673)
Net assets acquired	$ 77,828

Debt Credit Agreements (Details

Debt Credit Agreements (Details Textual) (Details) - USD ($)		1 Months Ended	2 Months Ended	12 Months Ended
	Dec. 19, 2018	Apr. 30, 2022	Feb. 23, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Nov. 30, 2022	Apr. 29, 2022	Nov. 18, 2021	Jun. 30, 2021	Oct. 30, 2020
Debt Instrument [Line Items]
Borrowings under credit agreement				$ 0	$ 100,000,000
Secured debt, percentage of mortgages used as security				85%
Repay deficit in agreement, period				6 months
Deferred loan costs				$ 3,200,000
Repayment of borrowings				300,000,000	600,000,000	$ 35,000,000
Third Amended Credit Agreement
Debt Instrument [Line Items]
EBITDA ratio, debt outstanding, cash and cash equivalents limit				$ 75,000,000
Debt to EBITDA ratio covenant				3.50
Third Amended Credit Agreement \| Minimum
Debt Instrument [Line Items]
Commitment fee percentage				0.375%
Third Amended Credit Agreement \| Maximum
Debt Instrument [Line Items]
Commitment fee percentage				0.50%
San Mateo Credit Facility
Debt Instrument [Line Items]
Effective interest rate				6.70%
Eurodollar \| Third Amended Credit Agreement \| Minimum
Debt Instrument [Line Items]
Additional interest rate				1.75%
Eurodollar \| Third Amended Credit Agreement \| Maximum
Debt Instrument [Line Items]
Additional interest rate				2.75%
Base Rate Loan \| Third Amended Credit Agreement \| Maximum
Debt Instrument [Line Items]
Additional interest rate				1.75%
Unsecured Debt \| SBA Loan, CARES Act [Member]
Debt Instrument [Line Items]
Long-term debt				$ 7,500,000
Unsecured Debt \| Senior Notes Due 2026
Debt Instrument [Line Items]
Debt instrument, repurchased par value				350,800,000
Debt instrument, repurchased fair value				344,300,000
Revolving Credit Facility
Debt Instrument [Line Items]
Senior secured revolving credit maximum facility		$ 775,000,000
Revolving Credit Facility \| Third Amended Credit Agreement
Debt Instrument [Line Items]
Senior secured revolving credit maximum facility		775,000,000						$ 700,000,000
Increase in borrowing capacity		2,000,000,000					$ 2,250,000,000	$ 1,350,000,000
Line of credit, maximum facility amount		$ 1,500,000,000
Maximum borrowing capacity, amended											$ 1,500,000,000
Line of Credit \| Fourth Amended Credit Agreement
Debt Instrument [Line Items]
Long-term line of credit									$ 25,000,000
Line of Credit \| San Mateo Credit Facility
Debt Instrument [Line Items]
Outstanding letters of credit				9,000,000
Long-term line of credit				465,000,000
Repayment of borrowings			$ 30,000,000
Accordian feature, increase limit	$ 735,000,000			485,000,000						$ 450,000,000
Deferred loan costs				3,900,000
Line of Credit \| San Mateo Credit Facility \| Minimum
Debt Instrument [Line Items]
Commitment fee percentage	0.30%
Line of Credit \| San Mateo Credit Facility \| Maximum
Debt Instrument [Line Items]
Commitment fee percentage	0.50%
Letter of Credit \| Credit Agreement
Debt Instrument [Line Items]
Outstanding letters of credit				$ 45,600,000
Additional interest rate				1.75%
Base Rate Loan \| Minimum
Debt Instrument [Line Items]
Additional interest rate				0.75%
Federal Funds Effective Rate \| Line of Credit \| San Mateo Credit Facility
Debt Instrument [Line Items]
Basis spread on variable rate	0.50%
Adjusted LIBO Rate \| Line of Credit \| San Mateo Credit Facility
Debt Instrument [Line Items]
Basis spread on variable rate	1%
Adjusted LIBO Rate \| Line of Credit \| San Mateo Credit Facility \| Minimum
Debt Instrument [Line Items]
Additional interest rate	1.25%
Adjusted LIBO Rate \| Line of Credit \| San Mateo Credit Facility \| Maximum
Debt Instrument [Line Items]
Additional interest rate	2.25%
Statutory Reserve Rate \| Line of Credit \| San Mateo Credit Facility \| Minimum
Debt Instrument [Line Items]
Additional interest rate	2.25%
Statutory Reserve Rate \| Line of Credit \| San Mateo Credit Facility \| Maximum
Debt Instrument [Line Items]
Additional interest rate	3.25%
Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate \| Third Amended Credit Agreement
Debt Instrument [Line Items]
Debt instrument interest rate		0.10%
Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate \| Revolving Credit Facility \| Third Amended Credit Agreement
Debt Instrument [Line Items]
Senior secured revolving credit maximum facility		$ 100,000,000			$ 50,000,000
The Bank Of Nova Scotia \| San Mateo Credit Facility
Debt Instrument [Line Items]
Debt to EBITDA ratio covenant	5
Interest coverage ratio	2.50

Debt Senior Unsecured Notes (De

Debt Senior Unsecured Notes (Details Textual) (Details) - USD ($)	Oct. 04, 2018	Dec. 31, 2022	Apr. 30, 2022	Apr. 29, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Borrowings under Credit Agreement		$ 0			$ 100,000,000
Revolving Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity			$ 775,000,000
Third Amended Credit Agreement \| Revolving Credit Facility
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity			775,000,000	$ 700,000,000
Third Amended Credit Agreement \| Revolving Credit Facility \| Secured Overnight Financing Rate (SOFR) Overnight Index Swap Rate
Debt Instrument [Line Items]
Line of Credit Facility, Maximum Borrowing Capacity			$ 100,000,000		$ 50,000,000
Unsecured Debt \| Senior Notes
Debt Instrument [Line Items]
Long-term debt		$ 699,200,000
Unsecured Debt \| 2026 Notes Offering
Debt Instrument [Line Items]
Stated interest rate		5.875%
Unsecured Debt \| Additional 2026 Notes \| Debt Instrument, Redemption, Period One
Debt Instrument [Line Items]
Threshold percentage of principle	25%
Default period	30 days
Period after notice to comply	180 days
Period after notice to comply with other agreements	60 days
Maximum aggregate payment defaults and accelerations	$ 50,000,000
Maximum outstanding judgments	$ 50,000,000
Maximum outstanding judgements, payment period	60 days

Debt Debt Redemption (Details)

Debt Debt Redemption (Details) - Unsecured Debt - Senior Notes Due 2026	Oct. 04, 2018
2022
Debt Instrument [Line Items]
Redemption Price	102.938%
2023
Debt Instrument [Line Items]
Redemption Price	101.469%
2024 and thereafter
Debt Instrument [Line Items]
Redemption Price	100%

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Deferred tax assets
Net operating loss carryforwards	$ 12,874	$ 129,651
Unrealized loss on derivatives	0	3,729
Percentage depletion carryover	8	1,770
Compensation	14,184	9,838
Lease liabilities	12,585	4,866
Other	1,926	9,410
Total deferred tax assets	41,577	159,264
Valuation allowance on deferred tax assets	(11,322)	(10,599)
Total deferred tax assets, net of valuation allowance	30,255	148,665
Deferred tax liabilities
Unrealized gain on derivatives	995	0
Property and equipment	(368,283)	(179,153)
Less than wholly-owned subsidiaries	(63,388)	(39,900)
Lease right of use assets	(12,585)	(4,866)
Other	(13,355)	(2,684)
Total deferred tax liabilities	(458,606)	(226,603)
Net deferred tax liabilities	$ (428,351)	$ (77,938)

Income Taxes (Details 1)

Income Taxes (Details 1) - USD ($) $ in Thousands	12 Months Ended
Income Taxes (Details 1) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Current income tax provision
Federal income tax	$ 31,335	$ 0	$ 0
State income tax	23,542	0	0
Net current income tax provision	54,877	0	0
Deferred income tax provision (benefit)
Federal income tax	302,486	44,883	(25,675)
State income tax	41,994	29,827	(19,924)
Net deferred income tax provision (benefit)	344,480	74,710	(45,599)
Deferred income tax provision (benefit)
Federal tax (benefit) expense at statutory rate	353,992	150,223	(125,823)
State income tax expense (benefit)	59,870	26,646	(20,607)
Permanent differences	(15,227)	(2,078)	(3,114)
Change in federal valuation allowance	0	(103,262)	103,262
Change in state valuation allowance	722	3,181	683
Net deferred income tax provision (benefit)	344,480	74,710	(45,599)
Net current income tax provision	54,877	0	0
Total income tax provision (benefit)	$ 399,357	$ 74,710	$ (45,599)

Stock-Based Compensation (Detai

Stock-Based Compensation (Details 1) shares in Thousands	12 Months Ended
Stock-Based Compensation (Details 1) shares in Thousands	Dec. 31, 2022 $ / shares shares
Number of options (in thousands)
Options outstanding at beginning of period (in shares) \| shares	603
Options granted (in shares) \| shares	0
Options exercised (in shares) \| shares	(445)
Options forfeited (in shares) \| shares	(8)
Options expired (in shares) \| shares	0
Options outstanding at end of period (in shares) \| shares	150
Weighted average exercise price
Weighted average exercise price, Options outstanding Beginning Balance (usd per share) \| $ / shares	$ 22.92
Weighted average exercise price, Options granted (usd per share) \| $ / shares	0
Weighted average exercise price, Options exercised (usd per share) \| $ / shares	24.35
Weighted average exercise price, Options forfeited (usd per share) \| $ / shares	14.80
Weighted average exercise price, Options expired (usd per share) \| $ / shares	0
Weighted average exercise price, Options outstanding Ending Balance (usd per share) \| $ / shares	$ 19.11

Stock-Based Compensation (Det_2

Stock-Based Compensation (Details 2) shares in Thousands	12 Months Ended
Stock-Based Compensation (Details 2) shares in Thousands	Dec. 31, 2022 $ / shares shares
$14.48 - $14.80
Summarized information about outstanding and exercisable stock option
Range of exercise prices, lower limit (in usd per share)	$ 14.48
Range of exercise prices, upper limit (in usd per share)	$ 14.80
Shares outstanding (in shares) \| shares	103
Weighted average remaining contractual price	2 years 7 months 28 days
Weighted average exercise price (usd per share)	$ 14.80
Shares exercisable (in shares) \| shares	103
Weighted average exercise price (usd per share)	$ 14.80
$26.86 - $29.68
Summarized information about outstanding and exercisable stock option
Range of exercise prices, lower limit (in usd per share)	26.86
Range of exercise prices, upper limit (in usd per share)	$ 29.68
Shares outstanding (in shares) \| shares	47
Weighted average remaining contractual price	8 months 26 days
Weighted average exercise price (usd per share)	$ 28.60
Shares exercisable (in shares) \| shares	47
Weighted average exercise price (usd per share)	$ 28.60

Stock-Based Compensation (Det_3

Stock-Based Compensation (Details 3) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 15,123	$ 9,039	$ 13,625
Employee Stock Options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense	$ 500	$ 1,000	$ 3,400
Restricted Stock Service Based
Summary of non-vested stock options
Non-vested Shares, Beginning Balance (in shares)	589,000
Shares Granted (in shares)	236,000
Shares Vested (in shares)	(126,000)
Shares Forfeited (in shares)	(41,000)
Non-vested Shares, Ending Balance (in shares)	658,000	589,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Weighted average fair value, Beginning Balance (usd per share)	$ 24.59
Weighted average fair value, Granted (usd per share)	45.58
Weighted average fair value, Vested (usd per share)	24.07
Weighted average fair value, Forfeited (usd per share)	19.12
Weighted average fair value, Ending Balance (usd per share)	$ 24.59	$ 24.59
Restricted Stock Units Service Based
Summary of non-vested stock options
Non-vested Shares, Beginning Balance (in shares)	33,000
Shares Granted (in shares)	16,000
Shares Vested (in shares)	(33,000)
Shares Forfeited (in shares)	0
Non-vested Shares, Ending Balance (in shares)	16,000	33,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Weighted average fair value, Beginning Balance (usd per share)	$ 33.39
Weighted average fair value, Granted (usd per share)	66.16
Weighted average fair value, Vested (usd per share)	33.39
Weighted average fair value, Forfeited (usd per share)	0
Weighted average fair value, Ending Balance (usd per share)	$ 66.16	$ 33.39
Restricted Stock Units Performance Based
Summary of non-vested stock options
Non-vested Shares, Beginning Balance (in shares)	963,000
Shares Granted (in shares)	230,000
Shares Vested (in shares)	(597,000)
Shares Forfeited (in shares)	0
Non-vested Shares, Ending Balance (in shares)	596,000	963,000
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value [Abstract]
Weighted average fair value, Beginning Balance (usd per share)	$ 20.26
Weighted average fair value, Granted (usd per share)	65.49
Weighted average fair value, Vested (usd per share)	1.74
Weighted average fair value, Forfeited (usd per share)	0
Weighted average fair value, Ending Balance (usd per share)	$ 56.31	$ 20.26
Restricted Stock Units Performance Based \| 2019 Incentive Plan
Summary of non-vested stock options
Non-vested Shares, Ending Balance (in shares)	597,414
Restricted Stock Units Performance Based \| 2019 Incentive Plan \| Maximum
Summary of non-vested stock options
Non-vested Shares, Ending Balance (in shares)	1,045,472

Stock Based Compensation (Detai

Stock Based Compensation (Details 4) - Restricted Stock Liability Based - shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested Shares, Beginning Balance (in shares)	1,102,000
Shares Granted (in shares)	226,000
Shares Vested (in shares)	(587,251)	(487,252)	(226,363)
Shares Forfeited (in shares)	(19,000)
Non-vested Shares, Ending Balance (in shares)	722,000	1,102,000

Stock Based Compensation (Det_2

Stock Based Compensation (Details Textual) - USD ($)		12 Months Ended
Stock Based Compensation (Details Textual) - USD ($)	Jun. 30, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Cash used to settle liability-based awards		$ 30,800,000	$ 12,400,000	$ 2,400,000
Maximum vesting period 1		5 years
Maximum vesting period 2		6 years
Maximum vesting period 3		10 years
Fair value of stock option awards outstanding (in shares)		150,000	603,000
Aggregate intrinsic value		$ 5,700,000
Aggregate intrinsic value exercisable		$ 5,700,000
Weighted average contractual term		2 years 21 days
Total intrinsic value of options exercised		$ 14,400,000	$ 15,800,000	300,000
Unrecognized compensation expense related to unvested stock options		0
Fair value of option shares vested		800,000	3,000,000	6,700,000
Stock-based compensation expense		$ 15,123,000	9,039,000	13,625,000
Options granted (in shares)		0
Aggregate intrinsic value for the restricted stock and restricted stock units outstanding		$ 114,100,000
Aggregate intrinsic value expected to be settled in cash		41,300,000
Tax benefits recognized for stock based compensation		11,000,000	7,900,000	4,500,000
Capitalized stock-based compensation		5,000,000	7,200,000	3,600,000
Expensed stock-based compensation		$ 47,100,000	30,000,000	17,600,000
Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of shares		3 years
Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of shares		4 years
Restricted Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted average remaining requisite service period of unvested stock awards		1 year 8 months 12 days
Unrecognized compensation expense related to unvested restricted stock and restricted stock units		$ 56,100,000
Unrecognized compensation expense related to unvested restricted stock expected to be settled in cash		23,400,000
Fair value of restricted stock and restricted stock units vested		99,600,000	51,900,000	8,400,000
Restricted stock or unit expenses		$ 51,600,000	36,300,000	17,700,000
Performance-Based Stock Units
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting period of shares		3 years
Performance-Based Stock Units \| Minimum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting percentage		0%
Performance-Based Stock Units \| Maximum
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Vesting percentage		200%
Stock options
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock-based compensation expense		$ 500,000	$ 1,000,000	$ 3,400,000
Restricted Stock Service Based
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock grants (in shares)		236,000
Restricted stock vested (in shares)		126,000
Restricted Stock Liability Based
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Restricted stock grants (in shares)		226,000
Restricted stock vested (in shares)		587,251	487,252	226,363
Employee Stock
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Share-Based Compensation Arrangement by Share-Based Payment Award, Number of Shares (in shares)	4,000,000
Remaining number of shares available (in shares)		3,977,456
2019 Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Additional shares authorized (in shares)		3,725,000
2012 Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum shares of common stock provided (in shares)		8,700,000
2019 Incentive Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum shares of common stock provided (in shares)		4,174,443

Employee Benefit Plans (Details

Employee Benefit Plans (Details) - USD ($)	12 Months Ended
Employee Benefit Plans (Details) - USD ($)	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Employee Benefit Plan (Textual) [Abstract]
Employees annual compensation	3%
Safe Harbor match	$ 1,800,000	$ 1,600,000	$ 1,400,000
Discretionary matching contributions	2,300,000	$ 2,100,000	$ 1,800,000
No additional discretionary contributions	$ 0

Equity (Details)

Equity (Details) - USD ($) $ / shares in Units, $ in Thousands			1 Months Ended		3 Months Ended	6 Months Ended	9 Months Ended	12 Months Ended
	Feb. 15, 2023	Dec. 31, 2022	Jun. 30, 2022	Oct. 31, 2021	Apr. 30, 2022	Dec. 31, 2022	Sep. 30, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Class of Stock [Line Items]
Common stock, dividends (in usd per share)		$ 0.15	$ 0.10	$ 0.05	$ 0.05	$ 0.10	$ 0.025	$ 0.30	$ 0.125
Dividends paid					$ 5,900	$ 11,700		$ 35,246	$ 14,581	$ 0
Preferred shares authorized (in shares)		2,000,000				2,000,000		2,000,000
Subsequent Event
Class of Stock [Line Items]
Common stock, dividends (in usd per share)	$ 0.15

Derivative Financial Instrume_3

Derivative Financial Instruments (Details)	Feb. 21, 2023 bbl $ / bbl	Dec. 31, 2022 USD ($) bbl $ / bbl	Dec. 31, 2021 USD ($)
Derivative [Line Items]
Derivative Asset (Liability), Net \| $		$ 3,931,000	$ (14,878,000)
Open costless collar contracts
Summary of contracts for oil and natural gas
Fair Value of Asset (Liability) \| $		$ 3,931,000
Open costless collar contracts \| Natural Gas \| 01/01/2021 - 12/31/2021
Summary of contracts for oil and natural gas
Notional Quantity (Bbl) \| bbl		2,400,000
Weighted Average Price Floor (usd per Bbl) \| $ / bbl		6
Weighted Average Price Ceiling (usd per Bbl) \| $ / bbl		14
Fair Value of Asset (Liability) \| $		$ 3,931,000
Open costless collar contracts \| Natural Gas \| 01/01/2021 - 12/31/2021 \| Subsequent Event
Summary of contracts for oil and natural gas
Notional Quantity (Bbl) \| bbl	16,700,000
Weighted Average Price Ceiling (usd per Bbl) \| $ / bbl	(1.85)

Derivative Financial Instrume_4

Derivative Financial Instruments (Details 2) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Offsetting Derivative Assets [Abstract]
Gross amounts of recognized assets	$ 3,931	$ 215,145
Gross amounts of recognized liabilities	0	(230,023)
Total	3,931	(14,878)
Offsetting Derivative Liabilities [Abstract]
Gross amounts netted in the consolidated balance sheets	0	(213,174)
Gross amounts netted in the consolidated balance sheet	0	(213,174)
Gross amounts netted in the consolidated balance sheets	0	0
Derivative asset	3,931	1,971
Derivative liability	0	(16,849)
Derivative Asset (Liability), Net	$ 3,931	$ (14,878)
Derivative Liability, Statement of Financial Position [Extensible Enumeration]	Other Liabilities, Current	Other Liabilities, Current
Derivative Asset, Statement of Financial Position [Extensible Enumeration]	Other Receivables, Net, Current	Other Receivables, Net, Current

Derivative Financial Instrume_5

Derivative Financial Instruments (Details 3) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Summary of location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations
Realized (loss) gain on derivatives	$ (157,483)	$ (220,105)	$ 38,937
Unrealized gain (loss) on derivatives	18,809	21,011	(32,008)
Revenues
Summary of location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations
Realized (loss) gain on derivatives	(157,483)	(220,105)	38,937
Unrealized gain (loss) on derivatives	18,809	21,011	(32,008)
Total	(138,674)	(199,094)	6,929
Oil \| Revenues
Summary of location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations
Realized (loss) gain on derivatives	(75,806)	(194,058)	38,937
Unrealized gain (loss) on derivatives	14,727	26,857	(37,703)
Natural Gas \| Revenues
Summary of location and aggregate fair value of all derivative financial instruments recorded in the consolidated statements of operations
Realized (loss) gain on derivatives	(81,677)	(26,047)	0
Unrealized gain (loss) on derivatives	$ 4,082	$ (5,846)	$ 5,695

Fair Value Measurements (Detail

Fair Value Measurements (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Assets (Liabilities)
Oil derivatives and basis swaps	$ 0	$ (16,849)
Natural gas derivatives	3,931	1,971
Total	3,931	(14,878)
Fair value on a recurring basis
Assets (Liabilities)
Oil derivatives and basis swaps		(14,727)
Natural gas derivatives	3,931	151
Contingent consideration related to business combination		(8,203)
Total	3,931	(23,081)
Fair value on a recurring basis \| Level 1
Assets (Liabilities)
Oil derivatives and basis swaps		0
Natural gas derivatives	0	0
Contingent consideration related to business combination		0
Total	0	0
Fair value on a recurring basis \| Level 2
Assets (Liabilities)
Oil derivatives and basis swaps		(14,727)
Natural gas derivatives	3,931	151
Contingent consideration related to business combination		0
Total	3,931	(14,878)
Fair value on a recurring basis \| Level 3
Assets (Liabilities)
Oil derivatives and basis swaps		0
Natural gas derivatives	0	0
Contingent consideration related to business combination		(8,203)
Total	$ 0	$ (8,203)

Fair Value Measurements (Deta_2

Fair Value Measurements (Details Textual) - USD ($)	12 Months Ended
Fair Value Measurements (Details Textual) - USD ($)	Dec. 31, 2022	Dec. 31, 2021
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Fair value of notes payable	$ 675,700,000	$ 1,080,000,000
Pipe and other equipment
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Impairment charge for equipments held in inventory	$ 0

Commitments and Contingencies (

Commitments and Contingencies (Details Textual) $ in Thousands		12 Months Ended
	Feb. 17, 2017	Dec. 31, 2022 USD ($) compressorStation	Dec. 31, 2021 USD ($)
Long-term Purchase Commitment [Line Items]
Purchase Obligation, to be Paid, Year One		$ 29,800
Compressor stations \| compressorStation		12
Delivery Of Natural Gas And Oil Production To Third Parties
Long-term Purchase Commitment [Line Items]
Payment for other commitment		$ 48,300	$ 48,700
Other commitment		541,100
Drilling Rig Commitments
Long-term Purchase Commitment [Line Items]
Maximum termination outstanding obligations of contracts		17,700
Minimum outstanding commitments		26,000
Corporate Joint Venture \| San Mateo Midstream
Long-term Purchase Commitment [Line Items]
Contractual obligation		$ 292,000
2019 15-Year Fixed Fee Natural Gas Transportation Agreement \| San Mateo Midstream
Long-term Purchase Commitment [Line Items]
Supply agreement, term		15 years
Rustler Breaks Asset Area \| Corporate Joint Venture \| San Mateo Midstream
Long-term Purchase Commitment [Line Items]
Contractual obligation, term	15 years
Rustler Breaks and Wolf Asset Area \| Corporate Joint Venture \| San Mateo Midstream
Long-term Purchase Commitment [Line Items]
Contractual obligation, term	15 years

Supplemental Disclosures (Detai

Supplemental Disclosures (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021
Summary of current accrued liabilities
Total accrued liabilities	$ 261,310	$ 253,283
Other	25,372	37,458
Accrued evaluated and unproved and unevaluated property costs
Summary of current accrued liabilities
Total accrued liabilities	112,766	128,598
Accrued midstream properties costs
Summary of current accrued liabilities
Total accrued liabilities	11,623	7,799
Accrued lease operating expenses
Summary of current accrued liabilities
Total accrued liabilities	46,975	32,182
Accrued interest on debt
Summary of current accrued liabilities
Total accrued liabilities	10,461	18,232
Accrued asset retirement obligations
Summary of current accrued liabilities
Total accrued liabilities	756	270
Accrued partners’ share of joint interest charges
Summary of current accrued liabilities
Total accrued liabilities	42,199	17,460
Accrued payable related to purchased natural gas
Summary of current accrued liabilities
Total accrued liabilities	$ 11,158	$ 11,284

Supplemental Disclosures (Det_2

Supplemental Disclosures (Details 1) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Supplemental disclosures of cash flow information
Cash paid for income taxes	$ 63,500	$ 0	$ 0
Cash paid for interest expense, net of amounts capitalized	72,561	74,843	76,880
Increase (decrease) in asset retirement obligations related to mineral properties	9,111	1,091	(208)
Increase in asset retirement obligations related to midstream properties	251	257	690
(Decrease) increase in liabilities for drilling, completion and equipping capital expenditures	(13,304)	80,255	(26,126)
(Decrease) increase in liabilities for acquisition of oil and natural gas properties	(2,531)	2,981	(2,346)
Increase (decrease) in liabilities for midstream capital expenditures	3,824	(4,478)	(33,609)
Stock-based compensation expense recognized as liability	31,906	24,494	3,702
Transfer of inventory from (to) oil and natural gas properties	148	(398)	608
Cash paid for income taxes	$ 63,500	$ 0	$ 0

Supplemental Disclosures Supple

Supplemental Disclosures Supplemental Disclosures (Details 2) (Details) - USD ($) $ in Thousands	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Supplemental Disclosures [Abstract]
Cash	$ 505,179	$ 48,135	$ 57,916
Restricted cash	42,151	38,785	33,467
Total cash and restricted cash	$ 547,330	$ 86,920	$ 91,383	$ 65,128

Segment Reporting (Details)

Segment Reporting (Details)	12 Months Ended
Segment Reporting (Details)	Dec. 31, 2022 USD ($) segment	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)
Segment Reporting Information [Line Items]
Number of business segments \| segment	2
Revenues	$ 3,196,699,000	$ 1,862,075,000	$ 851,135,000
Lease bonus - mineral acreage	0	0	4,062,000
Realized gain on derivatives	(157,483,000)	(220,105,000)	38,937,000
Unrealized gain on derivatives	18,809,000	21,011,000	(32,008,000)
Expenses	1,298,755,000	869,905,000	1,383,625,000
Operating income (loss)	1,759,270,000	793,076,000	(521,499,000)
Assets	5,554,505,000	4,262,153,000	3,687,280,000
Capital expenditures	1,063,275,000	837,928,000	721,838,000
Depletion, depreciation and amortization	466,348,000	344,905,000	361,831,000
Impairment charge of net capitalized costs	0	0	684,743,000
Midstream capital expenditures	80,051,000	63,359,000	234,359,000
Operating Segments \| Exploration and Production
Segment Reporting Information [Line Items]
Lease bonus - mineral acreage			4,062,000
Realized gain on derivatives	(157,483,000)	(220,105,000)	38,937,000
Unrealized gain on derivatives	18,809,000	21,011,000	(32,008,000)
Expenses	1,177,104,000	794,880,000	1,334,378,000
Operating income (loss)	1,698,330,000	748,456,000	(561,559,000)
Assets	4,022,609,000	3,324,681,000	2,782,819,000
Capital expenditures	903,518,000	778,191,000	518,198,000
Depletion, depreciation and amortization	429,700,000	310,900,000	335,800,000
Payments to acquire productive assets		263,500,000	70,500,000
Operating Segments \| Midstream
Segment Reporting Information [Line Items]
Lease bonus - mineral acreage			0
Realized gain on derivatives	0	0	0
Unrealized gain on derivatives	0	0	0
Expenses	227,556,000	142,444,000	97,599,000
Operating income (loss)	162,613,000	130,519,000	92,970,000
Assets	1,016,580,000	879,672,000	836,509,000
Capital expenditures	158,544,000	59,361,000	201,440,000
Depletion, depreciation and amortization	34,700,000	31,500,000	23,300,000
Income (loss) attributable to noncontrolling interest	72,100,000	55,700,000	39,600,000
Land and seismic acquisition expenditures	131,000,000
Midstream capital expenditures	75,800,000
Payments to acquire productive assets	39,600,000	28,500,000	112,100,000
Corporate
Segment Reporting Information [Line Items]
Lease bonus - mineral acreage			0
Realized gain on derivatives	0	0	0
Unrealized gain on derivatives	0	0	0
Expenses	101,673,000	85,899,000	52,910,000
Operating income (loss)	(101,673,000)	(85,899,000)	(52,910,000)
Assets	515,316,000	57,800,000	67,952,000
Capital expenditures	1,213,000	376,000	2,200,000
Depletion, depreciation and amortization	2,000,000	2,600,000	2,700,000
Consolidations and Eliminations
Segment Reporting Information [Line Items]
Lease bonus - mineral acreage			0
Realized gain on derivatives	0	0	0
Unrealized gain on derivatives	0	0	0
Expenses	(207,578,000)	(153,318,000)	(101,262,000)
Operating income (loss)	0	0	0
Assets	0	0	0
Capital expenditures	0	0	0
Oil and natural gas revenues
Segment Reporting Information [Line Items]
Revenues	2,905,738,000	1,700,542,000	744,461,000
Oil and natural gas revenues \| Operating Segments \| Exploration and Production
Segment Reporting Information [Line Items]
Revenues	2,897,336,000	1,695,032,000	741,092,000
Oil and natural gas revenues \| Operating Segments \| Midstream
Segment Reporting Information [Line Items]
Revenues	8,402,000	5,510,000	3,369,000
Oil and natural gas revenues \| Corporate
Segment Reporting Information [Line Items]
Revenues	0	0	0
Oil and natural gas revenues \| Consolidations and Eliminations
Segment Reporting Information [Line Items]
Revenues	0	0	0
Third-party midstream services revenues
Segment Reporting Information [Line Items]
Revenues	90,606,000	75,499,000	64,932,000
Third-party midstream services revenues \| Operating Segments \| Exploration and Production
Segment Reporting Information [Line Items]
Revenues	0	0	0
Third-party midstream services revenues \| Operating Segments \| Midstream
Segment Reporting Information [Line Items]
Revenues	298,184,000	228,817,000	166,194,000
Third-party midstream services revenues \| Corporate
Segment Reporting Information [Line Items]
Revenues	0	0	0
Third-party midstream services revenues \| Consolidations and Eliminations
Segment Reporting Information [Line Items]
Revenues	(207,578,000)	(153,318,000)	(101,262,000)
Sales of purchased natural gas
Segment Reporting Information [Line Items]
Revenues	200,355,000	86,034,000	41,742,000
Sales of purchased natural gas \| Operating Segments \| Exploration and Production
Segment Reporting Information [Line Items]
Revenues	116,772,000	47,398,000	20,736,000
Sales of purchased natural gas \| Operating Segments \| Midstream
Segment Reporting Information [Line Items]
Revenues	83,583,000	38,636,000	21,006,000
Sales of purchased natural gas \| Corporate
Segment Reporting Information [Line Items]
Revenues	0	0	0
Sales of purchased natural gas \| Consolidations and Eliminations
Segment Reporting Information [Line Items]
Revenues	$ 0	$ 0	$ 0

Subsequent Events (Details)

Subsequent Events (Details) $ in Millions	1 Months Ended	12 Months Ended
Subsequent Events (Details) $ in Millions	Jan. 24, 2023 USD ($) $ / bbl	Dec. 31, 2022 $ / bbl	Dec. 31, 2022 $ / MMBTU	Dec. 31, 2021 $ / bbl	Dec. 31, 2021 $ / MMBTU	Dec. 31, 2020 $ / bbl	Dec. 31, 2020 $ / MMBTU
Subsequent Event [Line Items]
Oil and Gas, average sale price		90.15	6.36	63.04	3.60	36.04	1.99
Subsequent Event \| Advance
Subsequent Event [Line Items]
Consideration transferred	$ 1,600
Cash	$ 7.5
Oil and Gas, average sale price \| $ / bbl	85