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美國
證券交易委員會
華盛頓特區20549
 ________________________________________________________ 
表格 10-Q
 _________________________________________________________  
☒根據1934年證券交易所法案第13或15(d)條的季報告
截至2024年6月30日季度結束 2024年9月30日
或
☐​
過渡期從             到           
委員會檔案編號 001-35410
 _________________________________________________________  
Matador Resources 公司
（依憑章程所載的完整登記名稱）
  _________________________________________________________ 
德克薩斯州27-4662601
(依據所在地或其他管轄區)
的註冊地或組織地點)		(國稅局雇主識別號碼)
識別號碼)
5400 LBJ Freeway, 1500套房
達拉斯， 德克薩斯州
75240
(總部辦公地址)（郵政編碼）
(972) 371-5200
(註冊人電話號碼，包括區號)
 _________________________________________________________  
根據法案第12(b)條規定註冊的證券：
每種類別的名稱交易標的每個註冊交易所的名稱
每股普通股，面值為0.01美元MTDR紐約證券交易所
請勾選是否申報人已於前12個月（或申報人被要求申報該等報告之期間較短的時間）內按照1934年證券交易法第13條或第15(d)條的要求提交所有報告，並且（2）在過去90天內一直受到該等申報要求的約束。☒  是    ☐否
標示勾選，表明在過去12個月（或登記人應提交該等文件的較短期間）內，登記人是否依據S-t條例第405條規定提交了每一個應提交的互動數據文件。☒  是    ☐否
通過勾選標記指出註冊人是大型加速申報器、加速申報器、非加速申報公司、較小的報告公司還是新興成長公司。請參閱《交易法》第 120 億條第 2 條中的「大型加速申報公司」、「加速申報公司」、「較小的報告公司」和「新興增長公司」的定義。
大型加速歸檔人☒加速檔案提交者☐
非加速歸檔人☐較小報告公司☐
新興成長型企業☐
如果是新興成長型公司，請打勾表示申報人選擇不使用根據《交易法》第13(a)條提供的適應任何新或修訂的財務會計準則的延長過渡期。 ☐
請用勾選標示，以表示公司是否為貝殼公司（依據《交易所法》第120億2條定義）。☐是☒否
截至2024年10月22日， 124,772,721 公司的普通股份總共 s每股面值為$0.01的股份，發行總數。

目錄
牛鬥資源公司
表格10-Q
2024年9月30日止季度
目 錄
 頁面

目錄
第一部分 — 財務資訊
項目 1. 基本報表 — 未經查核
Matador Resources公司及其附屬公司
縮編合併資產負債表-未經審計
(以千為單位，除面值和股份資料外)
九月三十日，
2024		12月31日，
2023
資產
流動資產合計
現金$23,277 $52,662 
限制性現金53,746 53,636 
應收帳款
石油和天然氣收入297,757 274,192 
聯合利益帳單255,724 163,660 
其他52,656 35,102 
衍生金融工具25,697 2,112 
租賃和井設備庫存34,119 41,808 
預付費用及其他流動資產104,210 92,700 
全部流動資產847,186 715,872 
不動產和設備，成本
石油和天然氣資產，完整成本法
評估完成12,035,981 9,633,757 
未經證實和未經評估1,757,034 1,193,257 
中遊資產1,617,007 1,318,015 
其他資產及設備45,676 40,375 
較少累積減值、折舊和攤銷(5,910,029)(5,228,963)
淨固定資產9,545,669 6,956,441 
其他資產
股權法之投資115,000 — 
衍生金融工具2,336 558 
其他長期資產 113,100 54,125 
其他總資產230,436 54,683 
資產總額$10,623,291 $7,726,996 
負債和股東權益
流動負債
應付賬款$114,206 $68,185 
應付負債474,238 365,848 
應支付的權利金224,554 161,983 
應付聯屬公司款項28,321 28,688 
合資利益所有人預付款項55,059 19,954 
其他流動負債69,577 40,617 
流動負債合計965,955 685,275 
長期負債
信貸協議下的借款955,000 500,000 
San Mateo授信備用借款526,000 522,000 
無擔保債務備付款2,115,229 1,184,627 
養老資產負債119,392 87,485 
推延所得稅784,475 581,439 
其他長期負債61,030 38,482 
長期負債總額4,561,126 2,914,033 
合同和應付之可能負債（註10）
股東權益
　　　普通股 - $0.01 每股面額為 160,000,000 授權股份為 124,895,537 和 119,478,282 股份發行;
與 124,813,565 和 119,458,674 流通股數，分別
1,249 1,194 
資本公積額額外增資2,498,678 2,133,172 
保留收益2,373,732 1,776,541 
按成本核算的庫藏股 81,972 和 19,608 股，分別為
(3,029)(45)
Matador Resources公司的總股東權益4,870,630 3,910,862 
子公司中的非控制權益225,580 216,826 
股東權益總額5,096,210 4,127,688 
總負債及股東權益$10,623,291 $7,726,996 




附註是此基本報表的一個重要部分。
3
目錄
Matador Resources公司及其附屬公司
未經審核的綜合收益簡明合併財務報表
(以千為單位，除每股數據外)
 三個月結束了
九月三十日，		截至九個月
九月三十日，
 2024202320242023
收益
石油和天然氣收入$770,155 $701,527 $2,249,974 $1,792,353 
第三方中遊服務收入38,316 29,931 103,324 86,517 
購買天然氣銷售51,666 40,329 147,377 106,481 
衍生工具實現收益（虧損）4,528 (6,975)8,573 (6,454)
衍生工具未實現收益（虧損）35,118 7,482 25,364 (8,244)
總收益899,783 772,294 2,534,612 1,970,653 
費用
生產稅、運輸和處理72,737 71,697 219,702 189,174 
租賃營運86,808 66,395 242,133 171,845 
工廠和其他中遊服務營運43,695 30,808 120,576 92,510 
購買天然氣31,222 37,641 105,894 93,192 
減損費用、折舊及攤銷242,821 192,794 681,066 496,633 
養老資產逐步減少攤提1,657 1,218 4,259 2,709 
總務與行政28,787 31,731 86,353 80,879 
總支出507,727 432,284 1,459,983 1,126,942 
營收392,056 340,010 1,074,629 843,711 
其他收益（費用）
減值損失— — — (202)
利息費用(36,169)(35,408)(111,717)(85,813)
其他收益（費用） 2,111 (11,614)567 5,289 
其他總費用(34,058)(47,022)(111,150)(80,726)
稅前收入357,998 292,988 963,479 762,985 
所得稅費用（利益）
目前(21,096)8,958 26,280 8,958 
递延106,417 5,631 203,805 119,609 
所得稅總負債85,321 14,589 230,085 128,567 
凈利潤272,677 278,399 733,394 634,418 
凈利潤歸屬於子公司非控制權益(24,386)(14,660)(62,605)(42,883)
凈利潤歸屬於matador resources公司股東$248,291 $263,739 $670,789 $591,535 
每個普通股的盈利
基礎$1.99 $2.21 $5.45 $4.97 
稀釋$1.99 $2.20 $5.44 $4.93 
加權平均流通在外的普通股股數
基礎124,814 119,147 123,107 119,121 
稀釋124,983 120,081 123,358 120,045 
The accompanying notes are an integral part of these financial statements.
4
Table of Contents
Matador Resources Company and Subsidiaries
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY — UNAUDITED
(In thousands)
For the Three and Nine Months Ended September 30, 2024
Total shareholders’ equity attributable to Matador Resources Company
Non-controlling interest in subsidiariesTotal shareholders’ equity
 Common StockAdditional
paid-in capital		Retained earningsTreasury Stock
 SharesAmountSharesAmount
Balance at January 1, 2024119,478 $1,194 $2,133,172 $1,776,541 20 $(45)$3,910,862 $216,826 $4,127,688 
Dividends declared ($0.20 per share)
— — — (23,858)— — (23,858)— (23,858)
Issuance of common stock pursuant to employee stock compensation plan100 1 (11,382)— — — (11,381)— (11,381)
Issuance of common stock pursuant to public offering5,250 53 344,610 — — — 344,663 — 344,663 
Cost to issue equity— — (53)— — — (53)— (53)
Stock-based compensation expense related to equity-based awards including amounts capitalized— — 5,149 — — — 5,149 — 5,149 
Stock options exercised, net of options forfeited in net share settlements7 — — — — — — — — 
Restricted stock forfeited— — — — 35 (2,046)(2,046)— (2,046)
Contribution related to formation of San Mateo, net of tax of $0.3 million (see Note 7)
— — 1,185 — — — 1,185 — 1,185 
Contributions from non-controlling interest owners of less-than-wholly-owned subsidiaries— — — — — — — 7,350 7,350 
Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries— — — — — — — (25,725)(25,725)
Current period net income— — — 193,729 — — 193,729 19,461 213,190 
Balance at March 31, 2024124,835 $1,248 $2,472,681 $1,946,412 55 $(2,091)$4,418,250 $217,912 $4,636,162 
Dividends declared ($0.20 per share)
— — — (24,889)— — (24,889)— (24,889)
Issuance of common stock pursuant to employee stock compensation plan33 1 1,027 — — — 1,028 — 1,028 
Cost to issue equity— — (2,513)— — — (2,513)— (2,513)
Issuance of common stock pursuant to directors’ compensation plan18 — — — — — — — — 
Stock-based compensation expense related to equity-based awards including amounts capitalized— — 4,967 — — — 4,967 — 4,967 
Restricted stock forfeited— — — — 19 (899)(899)— (899)
Contribution related to formation of San Mateo, net of tax of $1.8 million (see Note 7)
— — 6,913 — — — 6,913 — 6,913 
Contributions from non-controlling interest owners of less-than-wholly-owned subsidiaries— — — — — — — 11,760 11,760 
Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries— — — — — — — (24,451)(24,451)
Current period net income— — — 228,769 — — 228,769 18,758 247,527 
Balance at June 30, 2024124,886 $1,249 $2,483,075 $2,150,292 74 $(2,990)$4,631,626 $223,979 $4,855,605 

The accompanying notes are an integral part of these financial statements.
5
Table of Contents
Matador Resources Company and Subsidiaries
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY — UNAUDITED
(In thousands)
For the Three and Nine Months Ended September 30, 2024
Total shareholders’ equity attributable to Matador Resources Company
Non-controlling interest in subsidiariesTotal shareholders’ equity
Common StockAdditional
paid-in capital		Retained earningsTreasury Stock
SharesAmountSharesAmount
Balance at July 1, 2024124,886 $1,249 $2,483,075 $2,150,292 74 $(2,990)$4,631,626 $223,979 $4,855,605 
Dividends declared ($0.20 per share)
— — — (24,851)— — (24,851)— (24,851)
Issuance of common stock pursuant to employee stock compensation plan9 — 54 — — — 54 — 54 
Stock-based compensation expense related to equity-based awards including amounts capitalized— — 5,871 — — — 5,871 — 5,871 
Restricted stock forfeited— — — — 8 (39)(39)— (39)
Contribution related to formation of San Mateo, net of tax of $2.6 million (see Note 7)
— — 9,678 — — — 9,678 — 9,678 
Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries— — — — — — — (22,785)(22,785)
Current period net income— — — 248,291 — — 248,291 24,386 272,677 
Balance at September 30, 2024124,895 $1,249 $2,498,678 $2,373,732 82 $(3,029)$4,870,630 $225,580 $5,096,210 








The accompanying notes are an integral part of these financial statements.
6
Table of Contents

Matador Resources Company and Subsidiaries
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY — UNAUDITED
(In thousands)

For the Three and Nine Months Ended September 30, 2023
Total shareholders’ equity attributable to Matador Resources Company
Non-controlling interest in subsidiariesTotal shareholders’ equity
Common StockAdditional
paid-in capital		Retained earningsTreasury Stock
SharesAmountSharesAmount
Balance at January 1, 2023118,953 $1,190 $2,101,999 $1,007,642 5 $(34)$3,110,797 $206,294 $3,317,091 
Dividends declared ($0.15 per share)
— — — (17,768)— — (17,768)— (17,768)
Issuance of common stock pursuant to employee stock compensation plan264 2 (17,592)— — — (17,590)— (17,590)
Stock-based compensation expense related to equity-based awards including amounts capitalized— — 3,894 — — — 3,894 — 3,894 
Stock options exercised, net of options forfeited in net share settlements15 — 12 — — — 12 — 12 
Restricted stock forfeited— — — — 21 (1,236)(1,236)— (1,236)
Contribution related to formation of San Mateo, net of tax of $3.1 million (see Note 7)
— — 11,613 — — — 11,613 — 11,613 
Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries— — — — — — — (19,110)(19,110)
Current period net income— — — 163,130 — — 163,130 15,794 178,924 
Balance at March 31, 2023119,232 $1,192 $2,099,926 $1,153,004 26 $(1,270)$3,252,852 $202,978 $3,455,830 
Dividends declared ($0.15 per share)
— — — (17,917)— — (17,917)— (17,917)
Issuance of common stock pursuant to employee stock compensation plan27 — 950 — — — 950 — 950 
Issuance of common stock pursuant to directors' compensation plan11 — — — — — — — — 
Stock-based compensation expense related to equity-based awards including amounts capitalized— — 6,097 — — — 6,097 — 6,097 
Stock options exercised, net of options forfeited in net share settlements2 — 14 — — — 14 — 14 
Restricted stock forfeited— — — — 100 (3,806)(3,806)— (3,806)
Contributions from non-controlling interest owners of less-than-wholly-owned subsidiaries— — — — — — — 24,500 24,500 
Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries— — — — — — — (25,333)(25,333)
Current period net income— — — 164,666 — — 164,666 12,429 177,095 
Balance at June 30, 2023119,272 $1,192 $2,106,987 $1,299,753 126 $(5,076)$3,402,856 $214,574 $3,617,430 



The accompanying notes are an integral part of these financial statements.
7
Table of Contents


Matador Resources Company and Subsidiaries
CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN SHAREHOLDERS’ EQUITY — UNAUDITED
(In thousands)

For the Three and Nine Months Ended September 30, 2023
Total shareholders’ equity attributable to Matador Resources Company
Non-controlling interest in subsidiariesTotal shareholders’ equity
Common StockAdditional
paid-in capital		Accumulated deficitTreasury Stock
SharesAmountSharesAmount
Balance at July 1, 2023119,272 $1,192 $2,106,987 $1,299,753 126 $(5,076)$3,402,856 $214,574 $3,617,430 
Dividends declared ($0.15 per share)
— — — (17,780)— — (17,780)— (17,780)
Issuance of common stock pursuant to employee stock compensation plan3 — 43 — — — 43 — 43 
Stock-based compensation expense related to equity-based awards including amounts capitalized— — 6,751 — — — 6,751 — 6,751 
Stock options exercised, net of options forfeited in net share settlements2 — 5 — — — 5 — 5 
Restricted stock forfeited— — — — 6 — — — — 
Contribution related to formation of San Mateo, net of tax of $1.9 million (See Note 7)
— — 7,110 — — — 7,110 — 7,110 
Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries— — — — — — — (16,660)(16,660)
Current period net income— — — 263,739 263,739 14,660 278,399 
Balance at September 30, 2023119,277 $1,192 $2,120,896 $1,545,712 132 $(5,076)$3,662,724 $212,574 $3,875,298 
The accompanying notes are an integral part of these financial statements.
8
Table of Contents
Matador Resources Company and Subsidiaries
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS — UNAUDITED
(In thousands)
 Nine Months Ended
September 30,
 20242023
Operating activities
Net income$733,394 $634,418 
Adjustments to reconcile net income to net cash provided by operating activities
Unrealized (gain) loss on derivatives(25,364)8,244 
Depletion, depreciation and amortization681,066 496,633 
Accretion of asset retirement obligations4,259 2,709 
Stock-based compensation expense10,091 10,777 
Deferred income tax provision203,805 119,609 
Amortization of debt issuance cost and other debt-related costs12,286 4,996 
Other non-cash changes(1,027)14 
Changes in operating assets and liabilities
Accounts receivable(75,904)3,424 
Lease and well equipment inventory(8,587)(10,223)
Prepaid expenses and other current assets(78)(41,817)
Other long-term assets3,075 1,269 
Accounts payable, accrued liabilities and other current liabilities45,932 18,691 
Royalties payable52,882 22,655 
Advances from joint interest owners35,105 (30,941)
Income taxes payable(1,948)8,873 
Other long-term liabilities2,939 150 
Net cash provided by operating activities1,671,926 1,249,481 
Investing activities
Drilling, completion and equipping capital expenditures(905,431)(855,468)
Acquisition of Advance— (1,608,427)
Acquisition of Ameredev(1,831,214)— 
Acquisition of oil and natural gas properties(321,827)(120,586)
Midstream capital expenditures(219,189)(75,609)
Expenditures for other property and equipment(3,957)(2,964)
Proceeds from sale of assets900 730 
Net cash used in investing activities(3,280,718)(2,662,324)
Financing activities
Repayments of borrowings under Credit Agreement(3,080,000)(2,622,000)
Borrowings under Credit Agreement3,535,000 3,152,000 
Repayments of borrowings under San Mateo Credit Facility(193,000)(140,000)
Borrowings under San Mateo Credit Facility197,000 150,000 
Cost to amend credit facilities(25,936)(8,645)
Proceeds from issuance of senior unsecured notes1,650,000 494,800 
Cost to issue senior unsecured notes(26,073)(8,503)
Purchase of senior unsecured notes(699,191)— 
Proceeds from issuance of common stock344,663 — 
Cost to issue equity(2,566)— 
Dividends paid(73,598)(53,465)
Contributions related to formation of San Mateo22,500 23,700 
Contributions from non-controlling interest owners of less-than-wholly-owned subsidiaries19,110 24,500 
Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries(72,961)(61,103)
Taxes paid related to net share settlement of stock-based compensation(14,519)(22,833)
Other(912)(764)
Net cash provided by financing activities1,579,517 927,687 
Change in cash and restricted cash(29,275)(485,156)
Cash and restricted cash at beginning of period106,298 547,330 
Cash and restricted cash at end of period$77,023 $62,174 
Supplemental disclosures of cash flow information (Note 11)

The accompanying notes are an integral part of these financial statements.
9
Table of Contents
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED
NOTE 1 — 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 and its subsidiaries (“San Mateo”), and Pronto Midstream, LLC and its subsidiary (“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.
NOTE 2 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Interim Financial Statements, Basis of Presentation, Consolidation and Significant Estimates
The interim unaudited condensed consolidated financial statements of the Company have been prepared in accordance with the rules and regulations of the Securities and Exchange Commission (“SEC”) but do not include all of the information and footnotes required by generally accepted accounting principles in the United States of America (“U.S. GAAP”) for complete financial statements and should be read in conjunction with the Company’s audited consolidated financial statements and notes thereto included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2023 filed with the SEC on February 27, 2024 (the “Annual Report”). 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, 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. In management’s opinion, these interim unaudited condensed consolidated financial statements include all normal, recurring adjustments that are necessary for a fair presentation of the Company’s interim unaudited condensed consolidated financial statements as of September 30, 2024. Amounts as of December 31, 2023 are derived from the Company’s audited consolidated financial statements included in the Annual Report.
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 interim unaudited condensed 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. 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.
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Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED

NOTE 2 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES — Continued
Revenues
The following table summarizes the Company’s total revenues and revenues from contracts with customers on a disaggregated basis for the three and nine months ended September 30, 2024 and 2023 (in thousands).
Three Months Ended
September 30,		Nine Months Ended
September 30,
2024202320242023
Revenues from contracts with customers$860,137 $771,787 $2,500,675 $1,985,351 
Realized gain (loss) on derivatives4,528 (6,975)8,573 (6,454)
Unrealized gain (loss) on derivatives35,118 7,482 25,364 (8,244)
Total revenues$899,783 $772,294 $2,534,612 $1,970,653 
Three Months Ended
September 30,		Nine Months Ended
September 30,
2024202320242023
Oil revenues$698,391 $588,370 $2,002,454 $1,500,511 
Natural gas revenues71,764 113,157 247,520 291,842 
Third-party midstream services revenues38,316 29,931 103,324 86,517 
Sales of purchased natural gas51,666 40,329 147,377 106,481 
Total revenues from contracts with customers$860,137 $771,787 $2,500,675 $1,985,351 

Property and Equipment
The Company uses the full-cost method of accounting for its investments in oil and natural gas properties. Under this method, the Company is required to perform a ceiling test each quarter that determines a limit, or ceiling, on the capitalized costs of oil and natural gas properties based primarily on the after-tax estimated future net cash flows from oil and natural gas properties using a 10% discount rate and the arithmetic average of first-day-of-the-month oil and natural gas prices for the prior 12-month period. For each of the three and nine months ended September 30, 2024 and 2023, the cost center ceiling was higher than the capitalized costs of oil and natural gas properties, and, as a result, no impairment charge was necessary.
The Company capitalized approximately $15.0 million and $14.4 million of its general and administrative costs for the three months ended September 30, 2024 and 2023, respectively, and $47.2 million and $41.4 million of its general and administrative costs for the nine months ended September 30, 2024 and 2023, respectively. The Company capitalized approximately $8.2 million and $7.4 million of its interest expense for the three months ended September 30, 2024 and 2023, respectively, and $23.4 million and $16.1 million of its interest expense for the nine months ended September 30, 2024 and 2023, respectively.
Earnings Per Common Share
The Company reports basic earnings attributable to Matador shareholders per common share, which excludes the effect of potentially dilutive securities, and diluted earnings attributable to Matador shareholders per common share, which includes the effect of all potentially dilutive securities unless their impact is anti-dilutive.
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Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED

NOTE 2 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES — Continued
The following table sets forth the computation of diluted weighted average common shares outstanding for the three and nine months ended September 30, 2024 and 2023 (in thousands).
 Three Months Ended
September 30,		Nine Months Ended
September 30,
2024202320242023
Weighted average common shares outstanding
Basic124,814 119,147 123,107 119,121 
Dilutive effect of options and restricted stock units169 934 251 924 
Diluted weighted average common shares outstanding 124,983 120,081 123,358 120,045 
Recent Accounting Pronouncements
Segments. In November 2023, the Financial Accounting Standards Board (“FASB”) issued ASU 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures, which enhances the disclosures required for operating segments in the Company’s annual and interim consolidated financial statements. This ASU is effective retrospectively for fiscal years beginning after December 15, 2023 and for interim periods within fiscal years beginning after December 15, 2024. The Company is currently evaluating the impact of this standard on its disclosures.
Income Taxes. In December 2023, the FASB issued ASU 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures, which is intended to enhance the transparency and decision usefulness of income tax disclosures. The amendments in this standard provide for enhanced income tax information primarily through changes to the rate reconciliation and income taxes paid. This ASU is effective for the Company prospectively to all annual periods beginning after December 15, 2024. The Company is currently evaluating the impact of this standard on its disclosures.
Climate-Related Disclosures. On March 6, 2024, the SEC adopted a new set of rules that require a wide range of climate-related disclosures, including material climate-related risks, information on any climate-related targets or goals that are material to the registrant’s business, results of operations or financial condition, Scope 1 and Scope 2 greenhouse gas emissions on a phased-in basis by certain larger registrants when those emissions are material and the filing of an attestation report covering the same, and disclosure of the financial statement effects of severe weather events and other natural conditions including costs and losses. Compliance dates under the final rule are phased in by registrant category. Multiple lawsuits have been filed challenging the SEC’s new climate rules, which have been consolidated and will be heard in the U.S. Court of Appeals for the Eighth Circuit. On April 4, 2024, the SEC issued an order staying the final rules until judicial review is complete. The Company is currently evaluating the impact of the final rules on its disclosures.
NOTE 3 — BUSINESS COMBINATIONS
Ameredev Acquisition
On September 18, 2024, a wholly-owned subsidiary of the Company completed the acquisition (the “Ameredev Acquisition”) of Ameredev Stateline II, LLC (“Ameredev”) from affiliates of EnCap Investments L.P., including (i) certain oil and natural gas producing properties and undeveloped acreage located in Lea County, New Mexico and Loving and Winkler Counties, Texas, and (ii) an approximate 19% stake (the “Piñon Investment”) in the parent company of Piñon Midstream, LLC (“Piñon”), which has midstream assets in southern Lea County, New Mexico. The Ameredev Acquisition had an effective date of June 1, 2024 and an aggregate as-adjusted closing purchase price of approximately $1.831 billion in cash, which amount is subject to customary post-closing adjustments, of which approximately $95.3 million was deposited in escrow in connection with the execution of the Securities Purchase Agreement, dated as of June 12, 2024. The purchase price for the Ameredev Acquisition was funded by a combination of cash on hand and borrowings under the Company’s existing secured revolving credit facility (the “Credit Agreement”), which was amended on September 18, 2024 to, among other things: (i) provide for a term loan of $250.0 million, the full amount of which was borrowed to fund the Ameredev Acquisition, and (ii) increase the elected borrowing commitments under the revolving credit facility from $1.50 billion to $2.25 billion. On September 25, 2024, the Company completed the sale of $750.0 million in aggregate principal amount of the Company’s 6.25% senior unsecured notes due 2033 (the “2033 Notes”) and used the net proceeds to partially repay borrowings outstanding under the Credit Agreement, including all of the $250.0 million in outstanding borrowings under the term loan.
The Ameredev Acquisition was accounted for under the acquisition method of accounting as a business combination in accordance with Accounting Standards Codification Topic 805, Business Combinations (“ASC Topic 805”). Under ASC Topic
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 3 — BUSINESS COMBINATIONS — Continued
805, the purchase price is allocated to the underlying tangible and intangible assets acquired and liabilities assumed based upon their estimated fair values as of the respective acquisition date, with any excess purchase price allocated to goodwill. As the Company acquired 100% of the membership interests of Ameredev, the acquisition was treated as an asset acquisition for tax purposes. The Company concluded that the Piñon Investment is an equity method investment.
The preliminary allocation of the total purchase price for the Ameredev Acquisition is set forth below (in thousands). As of the date of this filing, the valuation of assets acquired and liabilities assumed remains ongoing and adjustments may be made. The Company expects to complete the final purchase price allocation during the 12-month period subsequent to the Ameredev Acquisition closing date.
ConsiderationAllocation
Cash consideration given$1,831,214 
Allocation of purchase price
Current assets$57,279 
Oil and natural gas properties
Evaluated1,258,433 
Unproved and unevaluated369,258 
Midstream assets125,860 
Equity method investment115,000 
Current liabilities(88,283)
Asset retirement obligations(6,333)
Net assets acquired$1,831,214 
The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market and therefore represent Level 3 inputs. The fair value of evaluated oil and gas properties and asset retirement obligations were measured using the discounted cash flow technique of valuation.
Significant inputs to the valuation of oil and gas properties include estimates of: (i) future production volumes, (ii) future commodity prices and (iii) recent market comparable transactions for unproved acreage. These inputs require significant judgments and estimates and are the most sensitive and subject to change.
The results of operations for the Ameredev Acquisition since the closing date have been included in the Company’s condensed consolidated financial statements for the three and nine months ended September 30, 2024. The oil and natural gas production from Ameredev increased the Company’s revenues and net income for the period from September 18, 2024 through September 30, 2024 by $16.5 million and $5.5 million, respectively.
Pro Forma Information
The following unaudited pro forma financial information represents a summary of the condensed consolidated results of operations for the three and nine months ended September 30, 2024 and 2023, assuming the Ameredev Acquisition had been completed as of January 1, 2023. The pro forma financial information is provided for illustrative purposes only and does not purport to represent what the actual consolidated results of operations or the consolidated financial position of the Company would have been had the Ameredev Acquisition occurred on the dates noted above, nor is it necessarily indicative of the future results of operations or consolidated financial position of the Company. Future results may vary significantly from the results reflected because of various factors.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 3 — BUSINESS COMBINATIONS — Continued
The information below reflects certain nonrecurring pro forma adjustments that were directly related to the business combination based on currently available information and certain estimates and assumptions that the Company believes provide a reasonable basis for presenting the significant effects of the Ameredev Acquisition, including (i) the increase in depletion reflecting the relative fair values and production volumes attributable to Ameredev’s properties and the revision to the depletion rate reflecting the reserve volumes acquired, (ii) adjustments to interest expense as a result of the incremental borrowings necessary to finance the Ameredev Acquisition and (iii) the estimated tax impacts of the pro-forma adjustments. The pro forma financial information does not reflect the benefits of projected synergies, potential cost savings or the costs that may be necessary to achieve such savings, opportunities to increase revenue generation or other factors that may result from the Ameredev Acquisition and, accordingly, does not attempt to predict or suggest future results. Management cannot identify the timing, nature and amount of such savings, costs or other factors, any of which could affect the future consolidated results of operations or consolidated financial position of the Company.
Three Months Ended
September 30,		Nine Months Ended
September 30,
2024202320242023
(In thousands, except per share data)
Total revenue$997,535 $941,900 $2,808,101 $2,448,270 
Net income attributable to Matador Resources Company shareholders$241,882 $268,370 $655,453 $606,432 
Earnings per share:
Basic$1.94 $2.25 $5.32 $5.09 
Diluted$1.94 $2.23 $5.31 $5.05 
Q1 2024 Acquisition
On February 15, 2024, a wholly-owned subsidiary of the Company acquired oil and natural gas producing properties and undeveloped acreage located in Lea County, New Mexico (the “Q1 2024 Acquisition”). The Q1 2024 Acquisition had an effective date of October 1, 2023 and consideration for the acquisition consisted of an amount in cash equal to approximately $155.1 million (which amount, at September 30, 2024, was subject to certain customary post-closing adjustments).
The Q1 2024 Acquisition was accounted for under the acquisition method of accounting as a business combination in accordance with ASC Topic 805. Under ASC Topic 805, the purchase price is allocated to the underlying tangible and intangible assets acquired and liabilities assumed based upon their estimated fair values as of the acquisition date, with any excess purchase price allocated to goodwill.
The preliminary allocation of the total purchase price for the Q1 2024 Acquisition is set forth below (in thousands). The Company anticipates that the allocation of the purchase price should be finalized during 2024 upon determination of the final purchase price adjustments.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 3 — BUSINESS COMBINATIONS — Continued
Consideration Allocation
Cash consideration given$155,054 
Allocation of purchase price
Current assets$3,358 
Oil and natural gas properties
Evaluated45,778
Unproved and unevaluated107,072
Asset retirement obligations(1,154)
Net assets acquired$155,054 
The fair value measurements of assets acquired and liabilities assumed are based on inputs that are not observable in the market and therefore represent Level 3 inputs. The fair value of evaluated oil and gas properties and asset retirement obligations were measured using the discounted cash flow technique of valuation.
Significant inputs to the valuation of oil and gas properties include estimates of: (i) future production volumes, (ii) future commodity prices and (iii) recent market comparable transactions for unproved acreage. These inputs require significant judgments and estimates and are the most sensitive and subject to change.
The results of operations for the Q1 2024 Acquisition since the closing date have been included in the Company’s interim unaudited condensed consolidated financial statements for the three and nine months ended September 30, 2024. The pro forma impact of this business combination to revenues and net income for 2024 and 2023 would not be material to the Company’s 2024 or 2023 revenues and net income as reported.
Advance Acquisition
On April 12, 2023, a wholly-owned subsidiary of the Company completed the acquisition of Advance Energy Partners Holdings, LLC (“Advance”) from affiliates of EnCap Investments L.P., including certain oil and natural gas producing properties, undeveloped acreage and midstream assets located primarily in Lea County, New Mexico and Ward County, Texas (the “Initial Advance Acquisition”). The Initial Advance Acquisition had an effective date of January 1, 2023 and an aggregate purchase price consisting of (i) an amount in cash equal to approximately $1.60 billion (which amount was subject to certain customary post-closing adjustments) (the “Cash Consideration”) and (ii) potential additional cash consideration of $7.5 million for each month of 2023 in which the average oil price (as defined in the securities purchase agreement) exceeded $85 per barrel (all such payments for the 12 months in 2023, the “Contingent Consideration”). The Cash Consideration was paid upon the closing of the Initial Advance Acquisition and was funded by a combination of cash on hand and borrowings under the Credit Agreement. In the fourth quarter of 2023, the Company paid Contingent Consideration of $15.0 million, as the average oil price for the months of September and October 2023 exceeded $85 per barrel.
On December 1, 2023, the Company acquired additional interests from affiliates of EnCap Investments L.P., including overriding royalty interests and royalty interests in certain oil and natural gas properties located primarily in Lea County, New Mexico, most of which were included in the Initial Advance Acquisition (the “Advance Royalty Acquisition”). The Advance Royalty Acquisition had an effective date of October 1, 2023 and an aggregate purchase price of approximately $81.0 million (which amount was subject to certain customary post-closing adjustments), and was funded by cash on hand.
The Initial Advance Acquisition and Advance Royalty Acquisition (collectively, the “Advance Acquisition”) were accounted for under the acquisition method of accounting as a business combination in accordance with ASC Topic 805. Under ASC Topic 805, the purchase price is allocated to the underlying tangible and intangible assets acquired and liabilities assumed based upon their estimated fair values as of the respective acquisition dates, with any excess purchase price allocated to goodwill. The Advance Acquisition was treated as an asset acquisition for tax purposes, as the Company acquired 100% of the membership interests of Advance in the Initial Advance Acquisition and acquired additional overriding royalty interests and royalty interests in the Advance Royalty Acquisition.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 3 — BUSINESS COMBINATIONS — Continued
The final allocation of the total purchase price for the Advance Acquisition is set forth below (in thousands).
Consideration Allocation
Cash$1,676,132 
Working capital adjustments(4,060)
Fair value of Contingent Consideration at April 12, 202321,151
Total consideration given$1,693,223 
Allocation of purchase price
Current assets$79,287 
Oil and natural gas properties
Evaluated1,418,668
Unproved and unevaluated213,835
Midstream assets63,644
Current liabilities(73,885)
Asset retirement obligations(8,326)
Net assets acquired$1,693,223 

NOTE 4 — ASSET RETIREMENT OBLIGATIONS
The following table summarizes the changes in the Company’s asset retirement obligations for the nine months ended September 30, 2024 (in thousands).
Beginning asset retirement obligations$92,090 
Liabilities incurred during period5,511 
Liabilities settled during period(725)
Revisions in estimated cash flows16,351 
Acquisitions during period7,487 
Divestitures during period(334)
Accretion expense4,259 
Ending asset retirement obligations124,639 
Less: current asset retirement obligations(1)
(5,247)
Long-term asset retirement obligations$119,392 
 _______________
(1)Included in accrued liabilities in the Company’s interim unaudited condensed consolidated balance sheet at September 30, 2024.
NOTE 5 — DEBT
At September 30, 2024, the Company had (i) $500.0 million of outstanding senior notes due 2028 (the “2028 Notes”), (ii) $900.0 million of outstanding senior notes due 2032 (the “2032 Notes”), (iii) $750.0 million of outstanding 2033 Notes, (iv) $955.0 million in borrowings outstanding under the Credit Agreement and (v) approximately $52.9 million in outstanding letters of credit issued pursuant to the Credit Agreement. Between September 30, 2024 and October 22, 2024, the Company repaid $65.0 million of borrowings under the Credit Agreement.
At September 30, 2024, San Mateo had $526.0 million in borrowings outstanding under its revolving credit facility (the “San Mateo Credit Facility”) and approximately $9.0 million in outstanding letters of credit issued pursuant to the San Mateo Credit Facility. Between September 30, 2024 and October 22, 2024, San Mateo repaid $32.0 million of borrowings under the San Mateo Credit Facility.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED

NOTE 5 — DEBT — Continued
Credit Agreements
MRC Energy Company
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.
On March 22, 2024, the Company and its lenders entered into an amendment to the Fourth Amended and Restated Credit Agreement, which amended the Credit Agreement to, among other things: (i) reaffirm the borrowing base at $2.50 billion,
(ii) increase the elected borrowing commitments from $1.325 billion to $1.50 billion, (iii) increase the maximum facility amount from $2.00 billion to $3.50 billion, (iv) extend the maturity date from October 31, 2026 to March 22, 2029, (v) appoint PNC Bank, National Association as administrative agent thereunder and (vi) add five new banks to the lending group. This March 2024 reaffirmation of the borrowing base constituted the regularly scheduled May 1 redetermination.
On September 18, 2024, the Company and its lenders entered into an amendment to the Fourth Amended and Restated Credit Agreement, which amended the Credit Agreement to, among other things: (i) provide for a term loan of $250.0 million, the full amount of which was borrowed to fund the Ameredev Acquisition, and (ii) increase the elected borrowing commitments under the revolving credit facility from $1.50 billion to $2.25 billion. On September 25, 2024, the Company completed the sale of $750.0 million in aggregate principal amount of the 2033 Notes and used the net proceeds to partially repay borrowings outstanding under the Credit Agreement, including all of the $250.0 million in outstanding borrowings under the term loan.
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 at the end of each fiscal quarter and (ii) a debt to EBITDA ratio, which is defined as debt outstanding (net of cash or cash equivalents of up to the greater of (a) $150.0 million and
(b) 10% of the elected commitment), divided by a rolling four quarter EBITDA calculation, of 3.5 or less. The Company believes that it was in compliance with the terms of the Credit Agreement at September 30, 2024.
San Mateo Midstream, LLC
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. The outstanding borrowings under the San Mateo Credit Facility mature on December 9, 2026, and lender commitments under the facility were $535.0 million at September 30, 2024. The San Mateo Credit Facility includes an accordion feature, which provides for potential increases in lender commitments of up to $735.0 million.
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 5.0 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 2.5 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. The Company believes that San Mateo was in compliance with the terms of the San Mateo Credit Facility at September 30, 2024.
Senior Unsecured Notes
2026 Notes Tender Offer and Redemption
On April 2 and April 4, 2024, the Company completed the repurchase of an aggregate principal amount of approximately $556.3 million of the $699.2 million of outstanding senior notes due 2026 (the “2026 Notes”) pursuant to the Company’s cash tender offer for the 2026 Notes announced on March 26, 2024 (the “2026 Notes Tender Offer”). On April 2, 2024, the Company exercised its optional right, under the indenture governing the 2026 Notes, to redeem the remaining aggregate principal amount of approximately $142.9 million of 2026 Notes outstanding on September 15, 2024 (the “2026 Notes Redemption”) and, in connection therewith, to satisfy and discharge the Company’s obligations under such indenture with respect to the 2026 Notes. In connection with the 2026 Notes Tender Offer and 2026 Notes Redemption, the Company incurred a loss of approximately $3.0 million included in interest expense for the nine months ended September 30, 2024.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED

NOTE 5 — DEBT — Continued
2028 Senior Notes
At September 30, 2024, the Company had $500.0 million of outstanding 2028 Notes, which have a 6.875% coupon rate. The 2028 Notes mature April 15, 2028, and interest is payable on the 2028 Notes semi-annually in arrears on each April 15 and October 15. The 2028 Notes are jointly and severally guaranteed on a senior unsecured basis by certain subsidiaries of the Company (the “Guarantor Subsidiaries”). Neither San Mateo nor Pronto is a guarantor of the 2028 Notes.
2032 Senior Notes
On April 2, 2024, the Company completed the sale of $900.0 million in aggregate principal amount of the 2032 Notes, which have a 6.50% coupon rate and mature on April 15, 2032. Interest on the 2032 Notes is payable in arrears on each April 15 and October 15. The first interest payment date for the 2032 Notes was October 15, 2024. The 2032 Notes are guaranteed on a senior unsecured basis by the Guarantor Subsidiaries. Neither San Mateo nor Pronto is a guarantor of the 2032 Notes.
At any time prior to April 15, 2027, the Company may redeem up to 40% in aggregate principal amount of 2032 Notes at a redemption price of 106.500% of the principal amount thereof, plus accrued and unpaid interest, if any, to the redemption date, in an amount not greater than the net proceeds of certain equity offerings, so long as the redemption occurs within 180 days of completing such equity offering and at least 60% of the aggregate principal amount of the 2032 Notes remains outstanding after such redemption. In addition, at any time prior to April 15, 2027, the Company may redeem all or part of the 2032 Notes for cash at a redemption price equal to 100% of their principal amount plus an applicable make-whole premium and accrued and unpaid interest, if any, to the applicable redemption date.
On or after April 15, 2027, the Company may redeem all or a part of the 2032 Notes at any time or from time to time at the following redemption prices (expressed as percentages of the principal amount) plus accrued and unpaid interest, if any, to the applicable redemption date, if redeemed during the twelve-month period beginning April 15 of the years indicated below:
YearRedemption Price
2027103.250%
2028101.625%
2029 and thereafter100.000%
2033 Senior Notes
On September 25, 2024, the Company completed the sale of $750.0 million in aggregate principal amount of the 2033 Notes, which have a 6.25% coupon rate and mature on April 15, 2033. Interest on the 2033 Notes is payable in arrears on each April 15 and October 15. The first interest payment date for the 2033 Notes will be April 15, 2025. The 2033 Notes are guaranteed on a senior unsecured basis by the Guarantor Subsidiaries. Neither San Mateo nor Pronto is a guarantor of the 2033 Notes.
At any time prior to April 15, 2028, the Company may redeem up to 40% in aggregate principal amount of 2033 Notes at a redemption price of 106.250% of the principal amount thereof, plus accrued and unpaid interest, if any, to the redemption date, in an amount not greater than the net proceeds of certain equity offerings, so long as the redemption occurs within 180 days of completing such equity offering and at least 60% of the aggregate principal amount of the 2033 Notes remains outstanding after such redemption. In addition, at any time prior to April 15, 2028, the Company may redeem all or part of the 2033 Notes for cash at a redemption price equal to 100% of their principal amount plus an applicable make-whole premium and accrued and unpaid interest, if any, to the applicable redemption date.
On or after April 15, 2028, the Company may redeem all or a part of the 2033 Notes at any time or from time to time at the following redemption prices (expressed as percentages of the principal amount) plus accrued and unpaid interest, if any, to the applicable redemption date, if redeemed during the twelve-month period beginning April 15 of the years indicated below:
YearRedemption Price
2028103.125%
2029101.563%
2030 and thereafter100.000%
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED

NOTE 5 — DEBT — Continued
Debt Maturities
The outstanding borrowings of $526.0 million at September 30, 2024 under the San Mateo Credit Facility mature on December 9, 2026. The outstanding borrowings of $955.0 million at September 30, 2024 under the Credit Agreement mature on March 22, 2029. The $500.0 million of outstanding 2028 Notes at September 30, 2024 mature on April 15, 2028. The $900.0 million of outstanding 2032 Notes at September 30, 2024 mature on April 15, 2032. The $750.0 million of outstanding 2033 Notes at September 30, 2024 mature on April 15, 2033.
NOTE 6 — INCOME TAXES
The Company recorded a current income tax benefit of $21.1 million and a current income tax provision of $26.3 million for the three and nine months ended September 30, 2024, respectively, and a deferred income tax provision of $106.4 million and $203.8 million for the three and nine months ended September 30, 2024, respectively. The Company recorded a current income tax provision of $9.0 million for each of the three and nine months ended September 30, 2023 and a deferred income tax provision of $5.6 million and $119.6 million for the three and nine months ended September 30, 2023, respectively.
The Company’s effective income tax rate of 26% for both the three and nine months ended September 30, 2024 differed from the U.S. federal statutory rate due primarily to permanent differences between book and taxable income and state taxes, primarily in New Mexico. The Company’s effective income tax rates of 5% and 18% for the three and nine months ended September 30, 2023, respectively, differed from the U.S. federal statutory rate due primarily to recognizing research and experimental expenditure tax credits of $65.1 million in the third quarter of 2023, which were partially offset by permanent differences between book and taxable income and state taxes, primarily in New Mexico.
NOTE 7 — EQUITY
Equity Offering
On March 28, 2024, the Company completed an underwritten public offering of 5,250,000 shares of its common stock. After deducting underwriting discounts and offering expenses, the Company received net proceeds of approximately $342.1 million. The net proceeds from this offering were used for general corporate purposes, including the funding of acquisitions and the repayment of borrowings outstanding under the Credit Agreement.
Stock-based Compensation
During the nine months ended September 30, 2024, the Company granted awards to certain of its employees of 140,200 service-based restricted stock units to be settled in cash, which are liability instruments, and 176,000 performance-based stock units and 119,950 service-based shares of restricted stock, which are equity instruments. The performance-based stock units 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 period ending December 31, 2026, as compared to a designated peer group. The service-based restricted stock and restricted stock units vest over a three-year period. The fair value of these awards was approximately $26.4 million on their respective grant dates.
Common Stock Dividend
Matador’s Board of Directors (the “Board”) declared a quarterly cash dividend of $0.20 per share of common stock in each of the first, second and third quarters of 2024. The first quarter dividend, which totaled $23.9 million, was paid on March 13, 2024 to shareholders of record as of February 23, 2024. The second quarter dividend, which totaled $24.9 million, was paid on June 7, 2024 to shareholders of record as of May 17, 2024. The third quarter dividend, which totaled $24.9 million, was paid on September 5, 2024 to shareholders of record as of August 15, 2024. On October 16, 2024, the Board amended the Company’s dividend policy to increase the quarterly dividend to $0.25 per share of common stock for future dividend payments and also declared a quarterly cash dividend of $0.25 per share of common stock payable on December 6, 2024 to shareholders of record as of November 15, 2024.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED

NOTE 7 — EQUITY— Continued
San Mateo Distributions and Contributions
During the three months ended September 30, 2024 and 2023, San Mateo distributed $23.7 million and $17.3 million, respectively, to the Company and $22.8 million and $16.7 million, respectively, to a subsidiary of Five Point Energy LLC (“Five Point”), the Company’s joint venture partner in San Mateo. During the nine months ended September 30, 2024 and 2023, San Mateo distributed $75.9 million and $63.6 million, respectively, to the Company and $73.0 million and $61.1 million, respectively, to a subsidiary of Five Point. During the nine months ended September 30, 2024 and 2023, the Company contributed $19.9 million and $25.5 million, respectively, and Five Point contributed $19.1 million and $24.5 million, respectively, of cash to San Mateo. During the three months ended September 30, 2024 and 2023, there were no contributions to San Mateo by either the Company or Five Point.
Performance Incentives
Five Point paid the Company $12.3 million and $9.0 million of performance incentives during the three months ended September 30, 2024 and 2023, respectively. Five Point paid the Company $22.5 million and $23.7 million of performance incentives during the nine months ended September 30, 2024 and 2023, respectively. These performance incentives are recorded when received, net of the $2.6 million and $1.9 million deferred tax impact to the Company for the three months ended September 30, 2024 and 2023, respectively, and the $4.7 million and $5.0 million deferred tax impact to the Company for the nine months ended September 30, 2024 and 2023, respectively, in “Additional paid-in capital” in the Company’s interim unaudited condensed consolidated balance sheets. These performance incentives for the three and nine months ended September 30, 2024 and 2023 are also denoted as “Contributions related to formation of San Mateo” under “Financing activities” in the Company’s interim unaudited condensed consolidated statements of cash flows and changes in shareholders’ equity.
NOTE 8 — DERIVATIVE FINANCIAL INSTRUMENTS
At September 30, 2024, the Company had various costless collar contracts open and in place to mitigate its exposure to oil price volatility, each with an established price floor and ceiling. At September 30, 2024, the Company had natural gas basis differential swap contracts open and in place to mitigate its exposure to natural gas price volatility, with a specific term (calculation period), notional quantity (volume hedged) and fixed price. The Company had no open contracts associated with natural gas liquids prices at September 30, 2024.
The following is a summary of the Company’s open costless collar contracts at September 30, 2024.

CommodityCalculation PeriodNotional Quantity
(Bbl)		Weighted Average Price Floor
($/Bbl)		Weighted Average Price Ceiling
($/Bbl)		Fair Value of
Asset
(Liability)
(thousands)
Oil Costless Collar10/01/2024 - 6/30/202512,285,000 $60.00 $86.26 $20,898 
Total open costless collar contracts$20,898 

The following is a summary of the Company’s open basis differential swap contracts at September 30, 2024.
CommodityCalculation PeriodNotional Quantity (MMBtu)Fixed Price
($/MMBtu)		Fair Value of
Asset
(Liability)
(thousands)
Natural Gas Basis Differential10/01/2024 - 12/31/202513,710,000 $(0.59)$7,135 
Total open basis differential swap contracts$7,135 
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 interim unaudited condensed consolidated balance sheets.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED

NOTE 8 — DERIVATIVE FINANCIAL INSTRUMENTS — Continued
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 interim unaudited condensed consolidated balance sheets as of September 30, 2024 and December 31, 2023 (in thousands).
Derivative InstrumentsGross
amounts
recognized		Gross amounts
netted in the condensed
consolidated
balance sheets		Net amounts presented in the condensed
consolidated
balance sheets
September 30, 2024
Current assets$55,076 $(29,379)$25,697 
Other assets8,190 (5,854)2,336 
Current liabilities(29,379)29,379 — 
Long-term liabilities(5,854)5,854 — 
Total$28,033 $— $28,033 
December 31, 2023
Current assets$2,573 $(461)$2,112 
Other assets1,743 (1,185)558 
Total$4,316 $(1,646)$2,670 
The following table summarizes the location and aggregate gain (loss) of all derivative financial instruments recorded in the interim unaudited condensed consolidated statements of income for the periods presented (in thousands).
 Three Months Ended
September 30,		Nine Months Ended
September 30,
Type of InstrumentLocation in Condensed Consolidated 
Statement of Income		2024202320242023
Derivative Instrument
Natural GasRevenues: Realized gain (loss) on derivatives$4,528 $(6,975)$8,573 $(6,454)
Realized gain (loss) on derivatives$4,528 $(6,975)$8,573 $(6,454)
OilRevenues: Unrealized gain on derivatives$35,602 $— $20,898 $— 
Natural GasRevenues: Unrealized (loss) gain on derivatives(484)7,482 4,466 (8,244)
Unrealized gain (loss) on derivatives$35,118 $7,482 $25,364 $(8,244)
Total$39,646 $507 $33,937 $(14,698)
NOTE 9 — 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.
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UNAUDITED — CONTINUED

NOTE 9 — FAIR VALUE MEASUREMENTS — Continued
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 September 30, 2024 and December 31, 2023 (in thousands).
 
Fair Value Measurements at
 September 30, 2024 using
DescriptionLevel 1Level 2Level 3Total
Assets (Liabilities)
Oil costless collars$— $20,898 $— $20,898 
Natural gas basis differential swaps— 7,135 — 7,135 
Total$— $28,033 $— $28,033 
 
Fair Value Measurements at
December 31, 2023 using
DescriptionLevel 1Level 2Level 3Total
Assets (Liabilities)
Natural gas basis differential swaps$— $2,670 $— $2,670 
Total$— $2,670 $— $2,670 

Additional disclosures related to derivative financial instruments are provided in Note 8.
Other Fair Value Measurements
At September 30, 2024 and December 31, 2023, the carrying values reported on the interim unaudited condensed 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 September 30, 2024 and December 31, 2023, 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 September 30, 2024 and December 31, 2023, the fair value of the 2028 Notes was $508.8 million and $510.9 million, respectively, based on quoted market prices, which represent Level 1 inputs in the fair value hierarchy.
At September 30, 2024, the fair value of the 2032 Notes was $900.0 million based on quoted market prices, which represent Level 1 inputs in the fair value hierarchy.
At September 30, 2024, the fair value of the 2033 Notes was $736.9 million based on quoted market prices, which represent Level 1 inputs in the fair value hierarchy.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED

NOTE 9 — FAIR VALUE MEASUREMENTS — Continued
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 the inventory and other property and equipment that are reduced to fair value when they are impaired or held for sale. See Note 3 for discussion of the fair value measurement of assets acquired and liabilities assumed as part of the Ameredev Acquisition, the Q1 2024 Acquisition and the Advance Acquisition.
NOTE 10 — 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 transportation, gathering, processing, fractionation, sales and disposal. The Company paid approximately $18.6 million and $16.0 million for deliveries under these agreements during the three months ended September 30, 2024 and 2023, respectively, and $50.2 million and $38.1 million for deliveries under these agreements during the nine months ended September 30, 2024 and 2023, 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 September 30, 2024, the total deficiencies required to be paid by the Company under these agreements would be approximately $617.5 million.
San Mateo Commitments
The Company dedicated to San Mateo its current and certain future leasehold interests in the Rustler Breaks asset area and the Wolf portion of the West Texas asset area and acreage in the southern portion of the Arrowhead asset area (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 September 30, 2024 was approximately $131.7 million.
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 on 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.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED

NOTE 11 — SUPPLEMENTAL DISCLOSURES
Accrued Liabilities
The following table summarizes the Company’s current accrued liabilities at September 30, 2024 and December 31, 2023 (in thousands).
September 30,
2024		December 31,
2023
Accrued evaluated and unproved and unevaluated property costs$191,173 $144,443 
Accrued midstream properties costs21,422 55,195 
Accrued lease operating expenses86,564 62,005 
Accrued interest on debt50,585 22,857 
Accrued asset retirement obligations5,247 4,605 
Accrued partners’ share of joint interest charges52,296 42,101 
Accrued payable related to purchased natural gas10,263 10,400 
Other56,688 24,242 
Total accrued liabilities$474,238 $365,848 

Supplemental Cash Flow Information
The following table provides supplemental disclosures of cash flow information for the nine months ended September 30, 2024 and 2023 (in thousands).
 Nine Months Ended
September 30,
 20242023
Cash paid for income taxes$34,283 $1,677 
Cash paid for interest expense, net of amounts capitalized$84,406 $77,396 
Increase in asset retirement obligations related to mineral properties$27,799 $32,448 
Increase in asset retirement obligations related to midstream properties$492 $1,106 
Increase in liabilities for drilling, completion and equipping capital expenditures$65,925 $63,299 
Increase in liabilities for acquisition of oil and natural gas properties$1,066 $360 
(Decrease) increase in liabilities for midstream properties capital expenditures$(33,773)$11,556 
Stock-based compensation expense recognized as a liability$8,004 $8,557 
Transfer of inventory (to) from oil and natural gas properties$(13,377)$550 

The following table provides a reconciliation of cash and restricted cash recorded in the interim unaudited condensed consolidated balance sheets to cash and restricted cash as presented on the interim unaudited condensed consolidated statements of cash flows (in thousands).
 Nine Months Ended
September 30,
 20242023
Cash$23,277 $25,935 
Restricted cash53,746 36,239 
Total cash and restricted cash$77,023 $62,174 
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UNAUDITED — CONTINUED


NOTE 12 — SEGMENT INFORMATION
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. The majority of the Company’s midstream operations in the Rustler Breaks, West Texas and Stateline asset areas and the Greater Stebbins Area in the Delaware Basin are conducted through San Mateo. In addition, at September 30, 2024, the Company operated a cryogenic gas processing plant, compressor stations and natural gas gathering pipelines in Lea and Eddy Counties, New Mexico through Pronto, which is a wholly-owned subsidiary of the Company. During the third quarter of 2024, the Company also acquired the Piñon Investment as part of the Ameredev Acquisition.
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 ProductionConsolidations and EliminationsConsolidated Company
MidstreamCorporate
Three Months Ended September 30, 2024
Oil and natural gas revenues$765,181 $4,974 $— $— $770,155 
Midstream services revenues— 120,056 — (81,740)38,316 
Sales of purchased natural gas7,079 44,587 — — 51,666 
Realized gain on derivatives4,528 — — — 4,528 
Unrealized gain on derivatives35,118 — — — 35,118 
Expenses(1)
465,797 98,260 25,410 (81,740)507,727 
Operating income(2)
$346,109 $71,357 $(25,410)$— $392,056 
Total assets$8,899,141 $1,653,821 $70,329 $— $10,623,291 
Capital expenditures(3)
$1,915,453 $295,650 $3,186 $— $2,214,289 
_____________________
(1)Includes depletion, depreciation and amortization expenses of $231.6 million and $10.9 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $0.4 million.
(2)Includes $24.4 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment.
(3)Includes $1.59 billion attributable to land and seismic acquisition expenditures related to the exploration and production segment, $240.9 million attributable to midstream acquisition expenditures and $5.9 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment.
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NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 12 — SEGMENT INFORMATION — Continued
Exploration and ProductionConsolidations and EliminationsConsolidated Company
MidstreamCorporate
Three Months Ended September 30, 2023
Oil and natural gas revenues$700,227 $1,300 $— $— $701,527 
Midstream services revenues— 89,300 — (59,369)29,931 
Sales of purchased natural gas5,719 34,610 — — 40,329 
Realized loss on derivatives(6,975)— — — (6,975)
Unrealized gain on derivatives7,482 — — — 7,482 
Expenses(1)
383,259 79,353 29,041 (59,369)432,284 
Operating income(2)
$323,194 $45,857 $(29,041)$— $340,010 
Total assets$6,246,067 $1,131,399 $61,697 $— $7,439,163 
Capital expenditures(3)
$249,293 $55,922 $486 $— $305,701 
_____________________
(1)Includes depletion, depreciation and amortization expenses of $182.2 million and $10.3 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $0.3 million.
(2)Includes $14.7 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment.
(3)Includes $53.3 million attributable to land and seismic acquisition expenditures related to the exploration and production segment and $14.1 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment.

Exploration and ProductionConsolidations and EliminationsConsolidated Company
MidstreamCorporate
Nine Months Ended September 30, 2024
Oil and natural gas revenues$2,238,873 $11,679 $— $(578)$2,249,974 
Midstream services revenues— 324,248 — (220,924)103,324 
Sales of purchased natural gas17,278 130,099 — — 147,377 
Realized gain on derivatives8,573 — — — 8,573 
Unrealized gain on derivatives25,364 — — — 25,364 
Expenses(1)
1,319,255 286,016 76,214 (221,502)1,459,983 
Operating income(2)
$970,833 $180,010 $(76,214)$— $1,074,629 
Total assets$8,899,141 $1,653,821 $70,329 $— $10,623,291 
Capital expenditures(3)
$2,939,236 $433,587 $3,957 $— $3,376,780 

_____________________
(1)Includes depletion, depreciation and amortization expenses of $647.5 million and $32.7 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $1.0 million.
(2)Includes $62.6 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment.
(3)Includes $1.94 billion attributable to land and seismic acquisition expenditures related to the exploration and production segment, $240.9 million attributable to midstream acquisition expenditures and $19.2 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment.
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Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 12 — SEGMENT INFORMATION — Continued
Exploration and ProductionConsolidations and EliminationsConsolidated Company
MidstreamCorporate
Nine Months Ended September 30, 2023
Oil and natural gas revenues$1,788,307 $4,046 $— $— $1,792,353 
Midstream services revenues— 243,764 — (157,247)86,517 
Sales of purchased natural gas17,094 89,387 — — 106,481 
Realized loss on derivatives(6,454)— — — (6,454)
Unrealized loss on derivatives(8,244)— — — (8,244)
Expenses(1)
992,351 219,324 72,514 (157,247)1,126,942 
Operating income(2)
$798,352 $117,873 $(72,514)$— $843,711 
Total assets$6,246,067 $1,131,399 $61,697 $— $7,439,163 
Capital expenditures(3)
$2,465,477 $151,331 $2,964 $— $2,619,772 

_____________________
(1)Includes depletion, depreciation and amortization expenses of $466.2 million and $29.5 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $1.0 million.
(2)Includes $42.9 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment.
(3)Includes $1.67 billion attributable to land and seismic acquisition expenditures related to the exploration and production segment, $63.6 million attributable to midstream acquisition expenditures and $25.4 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations
The following discussion and analysis of our financial condition and results of operations should be read in conjunction with our interim unaudited condensed consolidated financial statements and related notes thereto contained herein and the consolidated financial statements and related notes thereto contained in our Annual Report on Form 10-K for the year ended December 31, 2023 (the “Annual Report”) filed with the Securities and Exchange Commission (the “SEC”) on February 27, 2024, along with Management’s Discussion and Analysis of Financial Condition and Results of Operations contained in the Annual Report. The Annual Report is accessible on the SEC’s website at www.sec.gov and on our website at www.matadorresources.com. Our discussion and analysis includes forward-looking information that involves risks and uncertainties and should be read in conjunction with the “Risk Factors” section of the Annual Report and the section entitled “Cautionary Note Regarding Forward-Looking Statements” below for information about the risks and uncertainties that could cause our actual results to be materially different than our forward-looking statements.
In this Quarterly Report on Form 10-Q (this “Quarterly Report”), (i) references to “we,” “our” or the “Company” refer to Matador Resources Company and its subsidiaries as a whole (unless the context indicates otherwise), (ii) references to “Matador” refer solely to Matador Resources Company, (iii) references to “San Mateo” refer to San Mateo Midstream, LLC, collectively with its subsidiaries, (iv) references to “Pronto” refer to Pronto Midstream, LLC together with its subsidiary, (v) references to “Advance” refer to Advance Energy Partners Holdings, LLC, (vi) references to the “Advance Acquisition” refer to the acquisition of Advance from affiliates of EnCap Investments L.P., including certain oil and natural gas producing properties, undeveloped acreage and midstream assets located primarily in Lea County, New Mexico and Ward County, Texas, that was completed by a subsidiary of the Company on April 12, 2023, and the acquisition of additional interests from affiliates of EnCap Investments L.P., including overriding royalty interests and royalty interests in certain oil and natural gas properties located primarily in Lea County, New Mexico on December 1, 2023, (vii) references to “Ameredev” refer to Ameredev Stateline II, LLC, (viii) references to “Piñon” refer to Piñon Midstream, LLC, which has midstream assets in southern Lea County, New Mexico, and (ix) references to the “Ameredev Acquisition” refer to the acquisition of Ameredev from affiliates of EnCap Investments L.P., including (a) certain oil and natural gas producing properties and undeveloped acreage located in Lea County, New Mexico and Loving and Winkler Counties, Texas, and (b) an approximate 19% stake in the parent company of Piñon, which was completed by a subsidiary of the Company on September 18, 2024. For certain oil and natural gas terms used in this Quarterly Report, please see the “Glossary of Oil and Natural Gas Terms” included with the Annual Report.
Cautionary Note Regarding Forward-Looking Statements
Certain statements in this Quarterly Report constitute “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). Additionally, forward-looking statements may be made orally or in press releases, conferences, reports, on our website or otherwise, in the future by us or on our behalf. Such statements are generally identifiable by the terminology used such as “anticipate,” “believe,” “continue,” “could,” “estimate,” “expect,” “forecasted,” “hypothetical,” “intend,” “may,” “might,” “plan,” “potential,” “predict,” “project,” “should,” “would” or other similar words, although not all forward-looking statements contain such identifying words.
By their very nature, forward-looking statements require us to make assumptions that may not materialize or that may not be accurate. Forward-looking statements are subject to known and unknown risks and uncertainties and other factors that may cause actual results, levels of activity and achievements to differ materially from those expressed or implied by such statements. Such factors include those described in the “Risk Factors” section of the Annual Report, as well as the following factors, among others: general economic conditions; our ability to execute our business plan, including whether our drilling program is successful; changes in oil, natural gas and natural gas liquids (“NGL”) prices and the demand for oil, natural gas and NGLs; our ability to replace reserves and efficiently develop current reserves; the operating results of our midstream business’s oil, natural gas and water gathering and transportation systems, pipelines and facilities, the acquiring of third-party business and the drilling of any additional salt water disposal wells; costs of operations; delays and other difficulties related to producing oil, natural gas and NGLs; delays and other difficulties related to regulatory and governmental approvals and restrictions; impact on our operations due to seismic events; availability of sufficient capital to execute our business plan, including from future cash flows, available borrowing capacity under our revolving credit facilities and otherwise; our ability to make acquisitions on economically acceptable terms; our ability to integrate acquisitions, including the Ameredev Acquisition; the operating results of and availability of any potential distributions from our joint ventures; weather and environmental conditions; disruption from our acquisitions, including the Ameredev Acquisition, making it more difficult to maintain business and operational relationships; significant transaction costs associated with our acquisitions, including the Ameredev Acquisition; the risk of litigation and/or regulatory actions related to our acquisitions, including the Ameredev Acquisition; and the other factors discussed below and elsewhere in this Quarterly Report and in other documents that we file with or furnish to the SEC, all of which are difficult to predict. Forward-looking statements may include statements about:
•our business strategy;
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•our estimated future reserves and the present value thereof, including whether or not a full-cost ceiling impairment could be realized;
•our cash flows and liquidity;
•the amount, timing and payment of dividends, if any;
•our financial strategy, budget, projections and operating results;
•the supply and demand of oil, natural gas and NGLs;
•oil, natural gas and NGL prices, including our realized prices thereof;
•the timing and amount of future production of oil and natural gas;
•the availability of drilling and production equipment;
•the availability of oil storage capacity;
•the availability of oil field labor;
•the amount, nature and timing of capital expenditures, including future exploration and development costs;
•the availability and terms of capital;
•our drilling of wells;
•our ability to negotiate and consummate acquisition and divestiture opportunities;
•the integration of acquisitions, including the Ameredev Acquisition, with our business;
•government regulation and taxation of the oil and natural gas industry;
•our marketing of oil and natural gas;
•our exploitation projects or property acquisitions;
•the ability of our midstream business to construct, maintain and operate midstream pipelines and facilities, including the operation of cryogenic natural gas processing plants and the drilling of additional salt water disposal wells;
•the ability of our midstream business to attract third-party volumes;
•our costs of exploiting and developing our properties and conducting other operations;
•general economic conditions;
•competition in the oil and natural gas industry, including in both the exploration and production and midstream segments;
•the effectiveness of our risk management and hedging activities;
•our technology;
•environmental liabilities;
•our initiatives and efforts relating to environmental, social and governance matters;
•counterparty credit risk;
•geopolitical instability and developments in oil-producing and natural gas-producing countries;
•our future operating results;
•the Ameredev Acquisition and the anticipated benefits thereof;
•the pending sale of Piñon and our anticipated receipt of proceeds therefrom;
•the impact of the Inflation Reduction Act of 2022; and
•our plans, objectives, expectations and intentions contained in this Quarterly Report or in our other filings with the SEC that are not historical.
Although we believe that the expectations conveyed by the forward-looking statements in this Quarterly Report are reasonable based on information available to us on the date hereof, no assurances can be given as to future results, levels of activity, achievements or financial condition.
You should not place undue reliance on any forward-looking statement and should recognize that the statements are predictions of future results, which may not occur as anticipated. Actual results could differ materially from those anticipated in the forward-looking statements and from historical results, due to the risks and uncertainties described above, as well as others not now anticipated. The impact of any one factor on a particular forward-looking statement is not determinable with certainty as such factors are interdependent upon other factors. The foregoing statements are not exclusive and further information concerning us, including factors that potentially could materially affect our financial results, may emerge from time to time. We undertake no obligation to update forward-looking statements to reflect actual results or changes in factors or assumptions affecting such forward-looking statements, except as required by law, including the securities laws of the United States and the rules and regulations of the SEC.
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Overview
We are 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. Our 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. We also operate in the Eagle Ford shale play in South Texas and the Haynesville shale and Cotton Valley plays in Northwest Louisiana. Additionally, we conduct midstream operations in support of our exploration, development and production operations and provide natural gas processing, oil transportation services, oil, natural gas and produced water gathering services and produced water disposal services to third parties.
Third Quarter Highlights
For the three months ended September 30, 2024, our total oil equivalent production was 15.8 million BOE, and our average daily oil equivalent production was 171,480 BOE per day, of which 100,315 Bbl per day, or 59%, was oil and 427.0 MMcf per day, or 41%, was natural gas. Our average daily oil production of 100,315 Bbl per day for the three months ended September 30, 2024 increased 29% year-over-year from 77,529 Bbl per day for the three months ended September 30, 2023. Our average daily natural gas production of 427.0 MMcf per day for the three months ended September 30, 2024 increased 24% year-over-year from 345.4 MMcf per day for the three months ended September 30, 2023.
For the third quarter of 2024, we reported net income attributable to Matador shareholders of $248.3 million, or $1.99 per diluted common share, on a GAAP basis, as compared to net income attributable to Matador shareholders of $263.7 million, or $2.20 per diluted common share, for the third quarter of 2023. For the third quarter of 2024, our Adjusted EBITDA, a non-GAAP financial measure, was $574.5 million, as compared to Adjusted EBITDA of $508.3 million during the third quarter of 2023.
For the nine months ended September 30, 2024, we reported net income attributable to Matador shareholders of $670.8 million, or $5.44 per diluted common share, on a GAAP basis, as compared to net income attributable to Matador shareholders of $591.5 million, or $4.93 per diluted common share, for the nine months ended September 30, 2023. For the nine months ended September 30, 2024, our Adjusted EBITDA, a non-GAAP financial measure, was $1.66 billion, as compared to Adjusted EBITDA of $1.30 billion during the nine months ended September 30, 2023.
For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to our net income and net cash provided by operating activities, see “—Liquidity and Capital Resources—Non-GAAP Financial Measures.” For more information regarding our financial results for the three and nine months ended September 30, 2024, see “—Results of Operations” below.
Ameredev Acquisition
On September 18, 2024, our wholly-owned subsidiary completed the acquisition of Ameredev from affiliates of EnCap Investments L.P., including (i) certain oil and natural gas producing properties and undeveloped acreage located in Lea County, New Mexico and Loving and Winkler Counties, Texas, and (ii) an approximate 19% stake in the parent company of Piñon, which has midstream assets in southern Lea County, New Mexico. The Ameredev Acquisition had an effective date of June 1, 2024 and an aggregate as-adjusted closing purchase price of approximately $1.831 billion in cash, which amount is subject to customary post-closing adjustments, of which approximately $95.3 million was deposited in escrow in connection with the execution of the Securities Purchase Agreement, dated as of June 12, 2024. The purchase price for the Ameredev Acquisition was funded by a combination of cash on hand and borrowings under our existing secured revolving credit facility (the “Credit Agreement”), which was amended on September 18, 2024 to, among other things: (i) provide for a term loan of $250.0 million, the full amount of which was borrowed to fund the Ameredev Acquisition, and (ii) increase the elected borrowing commitments under the revolving credit facility from $1.50 billion to $2.25 billion. On September 25, 2024, we completed the sale of $750.0 million in aggregate principal amount of our 6.25% senior unsecured notes due 2033 (the “2033 Notes”) and used the net proceeds to partially repay borrowings outstanding under our Credit Agreement, including all of the $250.0 million in outstanding borrowings under the term loan. The results of operations for the Ameredev Acquisition since the closing date of September 18, 2024 have been included in our condensed consolidated financial statements for the three and nine months ended September 30, 2024. On August 21, 2024, Piñon announced that it expects to be acquired by an affiliate of Enterprise Products Partners L.P. in the fourth quarter of 2024, subject to customary regulatory approvals. We currently expect to receive between $110.0 million and $120.0 million from the sale of Piñon and we expect to use these proceeds to reduce borrowings under our Credit Agreement. See Note 3 to the interim unaudited condensed consolidated financial statements in this Quarterly Report for more information regarding the Ameredev Acquisition.
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Operations Update
We began 2024 operating seven drilling rigs in the Delaware Basin. We added an eighth operated drilling rig in the first quarter of 2024 and a ninth operated drilling rig late in the second quarter of 2024. Prior to the closing of the Ameredev Acquisition, Ameredev was operating one drilling rig, and upon the consummation of the Ameredev Acquisition, we continued operating a total of nine drilling rigs for the combined Matador and Ameredev properties covering approximately 196,200 net acres. We have built significant optionality into our drilling program, which should generally allow us to decrease or increase the number of rigs we operate as necessary based on changing commodity prices and other factors.
Our average daily oil equivalent production in the Delaware Basin for the third quarter of 2024 was 167,000 BOE per day, consisting of 99,600 Bbl of oil per day and 404.0 MMcf of natural gas per day, a 28% increase from 130,400 BOE per day, consisting of 76,800 Bbl of oil per day and 321.6 MMcf of natural gas per day, in the third quarter of 2023. These increases were primarily attributable to the increased number of wells being operated by us and by other operators where we own a working interest. The Delaware Basin contributed approximately 99% of our daily oil production and approximately 95% of our daily natural gas production in the third quarter of 2024, as compared to approximately 99% of our daily oil production and approximately 93% of our daily natural gas production in the third quarter of 2023.
In March 2024, we completed our natural gas pipeline connections between Pronto and San Mateo and between Pronto and Matador’s acreage obtained in the Advance Acquisition. These connector pipelines provide further flow assurance and options for Matador and third-party customer natural gas.
At September 30, 2024, Pronto’s midstream system included a cryogenic natural gas processing plant with a designed inlet processing capacity of 60 MMcf per day (the “Marlan Processing Plant”), four compressor stations and approximately 115 miles of natural gas gathering pipelines in Eddy and Lea Counties, New Mexico, spanning from the northeastern portion of the Arrowhead asset area into the Ranger asset area. Pronto has begun construction on an additional natural gas processing plant with a designed inlet processing capacity of 200 MMcf per day, including a nitrogen rejection unit and additional related facilities, to expand the Marlan Processing Plant.
2024 Capital Expenditure Budget
On October 22, 2024, we increased our estimated drilling, completing and equipping (“D/C/E”) capital expenditures for 2024 to a range of $1.15 to $1.35 billion from a range of $1.10 to $1.30 billion, which includes our expected D/C/E capital expenditures on acreage acquired in the Ameredev Acquisition. At October 22, 2024, our estimated midstream capital expenditures for 2024 remained $200.0 to $250.0 million, which includes our proportionate share of San Mateo’s estimated 2024 capital expenditures as well as the estimated 2024 capital expenditures for other wholly-owned midstream projects, including projects completed by Pronto. The midstream capital expenditure budget includes 100% of the costs associated with the Marlan Processing Plant expansion, although, at October 22, 2024, we were continuing to evaluate potential partners in Pronto that would share in these capital expenditures and strategic opportunities. The midstream capital expenditure budget excludes the acquisition cost of Ameredev’s midstream assets
Capital Resources Update
Matador’s Board of Directors (the “Board”) declared quarterly cash dividends of $0.20 per share of common stock in each of the first, second and third quarters of 2024. On October 16, 2024, the Board amended our dividend policy to increase the quarterly dividend to $0.25 per share of common stock for future dividend payments and also declared a quarterly cash dividend of $0.25 per share of common stock payable on December 6, 2024 to shareholders of record as of November 15, 2024.
On March 22, 2024, we and our lenders entered into an amendment to the Fourth Amended and Restated Credit Agreement, which amended our Credit Agreement to, among other things: (i) reaffirm the borrowing base at $2.50 billion,
(ii) increase the elected borrowing commitments from $1.325 billion to $1.50 billion, (iii) increase the maximum facility amount from $2.00 billion to $3.50 billion, (iv) extend the maturity date from October 31, 2026 to March 22, 2029, (v) appoint PNC Bank, National Association as administrative agent thereunder and (vi) add five new banks to the lending group. This March 2024 reaffirmation of the borrowing base constituted the regularly scheduled May 1 redetermination.
On March 28, 2024, we completed an underwritten public offering of 5,250,000 shares of our common stock (the “2024 Equity Offering”). After deducting underwriting discounts and offering expenses, we received net proceeds of approximately $342.1 million. The net proceeds from the 2024 Equity Offering were used for general corporate purposes, including the funding of acquisitions and the repayment of borrowings outstanding under our Credit Agreement.
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On April 2 and April 4, 2024, we completed the repurchase of an aggregate principal amount of approximately $556.3 million of the $699.2 million of outstanding senior notes due 2026 (the “2026 Notes”) as part of our cash tender offer announced on March 26, 2024 (the “2026 Notes Tender Offer”). On April 2, 2024, we exercised our optional right, under the indenture governing the 2026 Notes, to redeem the remaining aggregate principal amount of approximately $142.9 million of 2026 Notes outstanding on September 15, 2024 (the “2026 Notes Redemption”) and, in connection therewith, to satisfy and discharge the Company’s obligations under such indenture with respect to the 2026 Notes.
On April 2, 2024, we completed the sale of $900.0 million in aggregate principal amount of the Company’s 6.50% senior notes due 2032 (the “2032 Notes”). We used the net proceeds from the sale of the 2032 Notes (the “2032 Notes Offering”) of approximately $885.0 million, after deducting the initial purchasers’ discounts and estimated offering expenses, to fund the 2026 Notes Tender Offer and 2026 Notes Redemption and for general corporate purposes, including the funding of acquisitions and the repayment of borrowings outstanding under our Credit Agreement.
On September 18, 2024, we and our lenders entered into an amendment to the Fourth Amended and Restated Credit Agreement, which amended the Credit Agreement to, among other things: (i) provide for a term loan of $250.0 million, the full amount of which was borrowed to fund the Ameredev Acquisition, and (ii) increase the elected borrowing commitments from $1.50 billion to $2.25 billion.
On September 25, 2024, we completed the sale of $750.0 million in aggregate principal amount of the 2033 Notes (the “2033 Notes Offering”). We used the net proceeds from the 2033 Notes Offering of approximately $736.4 million, after deducting the initial purchasers’ discounts and estimated offering expenses, to partially repay borrowings outstanding under our Credit Agreement, including all of the $250.0 million in outstanding borrowings under the term loan.
At September 30, 2024, we had (i) $955.0 million in borrowings outstanding under our Credit Agreement,
(ii) approximately $52.9 million in outstanding letters of credit issued pursuant to the Credit Agreement, (iii) $500.0 million of outstanding 6.875% senior notes due 2028 (the “2028 Notes”), (iv) $900.0 million of outstanding 2032 Notes and (v) $750.0 million of outstanding 2033 Notes. Between September 30, 2024 and October 22, 2024, we repaid $65.0 million of borrowings under the Credit Agreement.
At September 30, 2024, San Mateo had $526.0 million in borrowings outstanding under San Mateo’s revolving credit facility (the “San Mateo Credit Facility”) and approximately $9.0 million in outstanding letters of credit issued pursuant to the San Mateo Credit Facility. Between September 30, 2024 and October 22, 2024, San Mateo repaid $32.0 million of borrowings under the San Mateo Credit Facility.
Critical Accounting Policies
There have been no changes to our critical accounting policies and estimates from those set forth in the Annual Report.
Recent Accounting Pronouncements
See Note 2 to the interim unaudited condensed consolidated financial statements for a description of recent accounting pronouncements.
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Results of Operations
Revenues
The following table summarizes our unaudited revenues and production data for the periods indicated:
 Three Months Ended
September 30,		Nine Months Ended
September 30,
 2024202320242023
Operating Data
Revenues (in thousands)(1)
Oil$698,391 $588,370 $2,002,454 $1,500,511 
Natural gas71,764 113,157 247,520 291,842 
Total oil and natural gas revenues770,155 701,527 2,249,974 1,792,353 
Third-party midstream services revenues38,316 29,931 103,324 86,517 
Sales of purchased natural gas51,666 40,329 147,377 106,481 
Realized gain (loss) on derivatives4,528 (6,975)8,573 (6,454)
Unrealized gain (loss) on derivatives35,118 7,482 25,364 (8,244)
Total revenues$899,783 $772,294 $2,534,612 $1,970,653 
Net Production Volumes(1)
Oil (MBbl)(2)
9,229 7,133 25,633 19,385 
Natural gas (Bcf)(3)
39.3 31.8 110.2 87.2 
Total oil equivalent (MBOE)(4)
15,776 12,429 43,992 33,920 
Average daily production (BOE/d)(5)
171,480 135,096 160,555 124,248 
Average Sales Prices
Oil, without realized derivatives (per Bbl)$75.67 $82.49 $78.12 $77.41 
Oil, with realized derivatives (per Bbl)$75.67 $82.49 $78.12 $77.41 
Natural gas, without realized derivatives (per Mcf)$1.83 $3.56 $2.25 $3.35 
Natural gas, with realized derivatives (per Mcf)$1.94 $3.34 $2.32 $3.27 
_________________
(1)We report our production volumes in two streams: oil and natural gas, including both dry and liquids-rich natural gas. Revenues associated with NGLs are included with our natural gas revenues.
(2)One thousand Bbl of oil.
(3)One billion cubic feet of natural gas.
(4)One thousand Bbl of oil equivalent, estimated using a conversion ratio of one Bbl of oil per six Mcf of natural gas.
(5)Barrels of oil equivalent per day, estimated using a conversion ratio of one Bbl of oil per six Mcf of natural gas.
Three Months Ended September 30, 2024 as Compared to Three Months Ended September 30, 2023
Oil and natural gas revenues. Our oil and natural gas revenues increased $68.6 million, or 10%, to $770.2 million for the three months ended September 30, 2024, as compared to $701.5 million for the three months ended September 30, 2023. Our oil revenues increased $110.0 million, or 19%, to $698.4 million for the three months ended September 30, 2024, as compared to $588.4 million for the three months ended September 30, 2023. The increase in oil revenues resulted from a 29% increase in our oil production to 9.2 million Bbl for the three months ended September 30, 2024, as compared to 7.1 million Bbl for the three months ended September 30, 2023, which was partially offset by an 8% decrease in the weighted average oil price realized for the three months ended September 30, 2024 to $75.67 per Bbl, as compared to $82.49 per Bbl for the three months ended September 30, 2023. Our natural gas revenues decreased $41.4 million, or 37%, to $71.8 million for the three months ended September 30, 2024, as compared to $113.2 million for the three months ended September 30, 2023. The decrease in natural gas revenues resulted from a 49% decrease in the weighted average natural gas price realized for the three months ended September 30, 2024 to $1.83 per Mcf, as compared to a weighted average natural gas price of $3.56 per Mcf realized for the three months ended September 30, 2023, which was partially offset by a 24% increase in our natural gas production to 39.3 Bcf for the three months ended September 30, 2024, as compared to 31.8 Bcf for the three months ended September 30, 2023.
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Third-party midstream services revenues. Our third-party midstream services revenues increased $8.4 million, or 28%, to $38.3 million for the three months ended September 30, 2024, as compared to $29.9 million for the three months ended September 30, 2023. Third-party midstream services revenues are those revenues from midstream operations related to third parties, including working interest owners in our operated wells. This increase was primarily attributable to an increase in our third-party produced water disposal revenues to $15.4 million for the three months ended September 30, 2024, as compared to $10.5 million for the three months ended September 30, 2023, and an increase in our third-party natural gas gathering and processing revenues to $18.8 million for the three months ended September 30, 2024, as compared to $16.7 million for the three months ended September 30, 2023.
Sales of purchased natural gas. Our sales of purchased natural gas increased $11.3 million, or 28%, to $51.7 million for the three months ended September 30, 2024, as compared to $40.3 million for the three months ended September 30, 2023. This increase was primarily the result of an 83% increase in natural gas volumes sold, which was partially offset by a 30% decrease in natural gas price realized. Sales of purchased natural gas reflect those natural gas purchase transactions that we periodically enter into with third parties whereby we purchase natural gas and (i) subsequently sell the natural gas to other purchasers or (ii) process the natural gas at either Pronto’s or San Mateo’s cryogenic natural gas processing plant and subsequently sell the residue natural gas and NGLs to other purchasers. These revenues, and the expenses related to these transactions included in “Purchased natural gas,” are presented on a gross basis in our interim unaudited condensed consolidated statements of income.
Realized gain (loss) on derivatives. Our realized gain on derivatives was $4.5 million for the three months ended September 30, 2024, as compared to a realized loss of $7.0 million for the three months ended September 30, 2023. We realized a net gain of $4.5 million related to our natural gas basis differential swap contracts for the three months ended September 30, 2024, resulting primarily from natural gas basis differentials that were below the fixed prices of certain of our natural gas basis differential swap contracts. For the three months ended September 30, 2023, we realized a net loss of $7.0 million related to our natural gas basis differential swap contracts, resulting primarily from natural gas basis differentials that were above the fixed prices of certain of our natural gas basis differential swap contracts. We realized an average gain on our natural gas derivatives of approximately $0.11 per Mcf produced during the three months ended September 30, 2024, as compared to an average loss of approximately $0.22 per Mcf produced during the three months ended September 30, 2023.
Unrealized gain (loss) on derivatives. During the three months ended September 30, 2024, the aggregate net fair value of our open oil costless collar and natural gas basis differential swap contracts changed to a net asset of $28.0 million from a net liability of $7.1 million at June 30, 2024, resulting in an unrealized gain on derivatives of $35.1 million for the three months ended September 30, 2024. During the three months ended September 30, 2023, the aggregate net fair value of our open natural gas basis differential swap contracts changed to a net liability of $4.3 million from a net liability of $11.8 million at June 30, 2023, resulting in an unrealized gain on derivatives of $7.5 million for the three months ended September 30, 2023.
Nine Months Ended September 30, 2024 as Compared to Nine Months Ended September 30, 2023
Oil and natural gas revenues. Our oil and natural gas revenues increased $457.6 million, or 26%, to $2.25 billion for the nine months ended September 30, 2024, as compared to $1.79 billion for the nine months ended September 30, 2023. Our oil revenues increased $501.9 million, or 33%, to $2.00 billion for the nine months ended September 30, 2024, as compared to $1.50 billion for the nine months ended September 30, 2023. This increase in oil revenues resulted from a 32% increase in our oil production to 25.6 million Bbl for the nine months ended September 30, 2024, as compared to 19.4 million Bbl for the nine months ended September 30, 2023 and a 1% increase in the weighted average oil price realized for the nine months ended September 30, 2024 to $78.12 per Bbl, as compared to $77.41 per Bbl for the nine months ended September 30, 2023. Our natural gas revenues decreased by $44.3 million, or 15%, to $247.5 million for the nine months ended September 30, 2024, as compared to $291.8 million for the nine months ended September 30, 2023. The decrease in natural gas revenues resulted from a 33% decrease in the weighted average natural gas price realized for the nine months ended September 30, 2024 to $2.25 per Mcf, as compared to a weighted average natural gas price of $3.35 per Mcf for the nine months ended September 30, 2023, which was partially offset by a 26% increase in our natural gas production to 110.2 Bcf for the nine months ended September 30, 2024, as compared to 87.2 Bcf for the nine months ended September 30, 2023.
Third-party midstream services revenues. Our third-party midstream services revenues increased $16.8 million, or 19%, to $103.3 million for the nine months ended September 30, 2024, as compared to $86.5 million for the nine months ended September 30, 2023. This increase was primarily attributable to an increase in our third-party produced water disposal revenues to $42.9 million for the nine months ended September 30, 2024, as compared to $31.4 million for the nine months ended September 30, 2023, and an increase in our oil transportation revenues to $10.6 million for the nine months ended September 30, 2024, as compared to $7.7 million for the nine months ended September 30, 2023.
Sales of purchased natural gas. Our sales of purchased natural gas increased $40.9 million, or 38%, to $147.4 million for the nine months ended September 30, 2024, as compared to $106.5 million for the nine months ended September 30, 2023. This increase was the result of a 59% increase in natural gas volumes sold, which was partially offset by a 13% decrease in natural gas price realized.
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Realized gain (loss) on derivatives. Our realized gain on derivatives was $8.6 million for the nine months ended September 30, 2024, as compared to a realized loss of $6.5 million for the nine months ended September 30, 2023. We realized a net gain of $8.6 million related to our natural gas basis differential swap contracts for the nine months ended September 30, 2024, resulting primarily from natural gas basis differentials that were below the fixed prices of our natural gas basis differential swap contracts. For the nine months ended September 30, 2023, we realized a net loss of $6.5 million related to our natural gas costless collar and natural gas basis differential swap contracts, resulting primarily from natural gas prices that were above the fixed prices of our natural gas basis differential swap contracts, offset by natural gas prices that were below the floor prices of certain of our natural gas costless collar contracts. We realized an average gain on our natural gas derivatives of approximately $0.07 per Mcf produced during the nine months ended September 30, 2024, as compared to an average loss of approximately $0.08 per Mcf produced during the nine months ended September 30, 2023.
Unrealized gain (loss) on derivatives. During the nine months ended September 30, 2024, the aggregate net fair value of our open oil costless collar and natural gas basis differential swap contracts changed to a net asset of $28.0 million from a net asset of $2.7 million at December 31, 2023, resulting in an unrealized gain on derivatives of $25.4 million for the nine months ended September 30, 2024. During the nine months ended September 30, 2023, the aggregate net fair value of our open natural gas costless collar and natural gas basis differential swap contracts changed to a net liability of $4.3 million from a net asset of $3.9 million at December 31, 2022, resulting in an unrealized loss on derivatives of $8.2 million for the nine months ended September 30, 2023.

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Expenses
The following table summarizes our unaudited operating expenses and other income (expense) for the periods indicated:
 Three Months Ended
September 30,		Nine Months Ended
September 30,
(In thousands, except expenses per BOE)2024202320242023
Expenses
Production taxes, transportation and processing $72,737 $71,697 $219,702 $189,174 
Lease operating
86,808 66,395 242,133 171,845 
Plant and other midstream services operating43,695 30,808 120,576 92,510 
Purchased natural gas31,222 37,641 105,894 93,192 
Depletion, depreciation and amortization242,821 192,794 681,066 496,633 
Accretion of asset retirement obligations1,657 1,218 4,259 2,709 
General and administrative28,787 31,731 86,353 80,879 
Total expenses507,727 432,284 1,459,983 1,126,942 
Operating income392,056 340,010 1,074,629 843,711 
Other income (expense)
Net loss on impairment— — — (202)
Interest expense(36,169)(35,408)(111,717)(85,813)
Other income (expense) 2,111 (11,614)567 5,289 
Total other expense(34,058)(47,022)(111,150)(80,726)
Income before income taxes357,998 292,988 963,479 762,985 
Income tax provision (benefit)
Current(21,096)8,958 26,280 8,958 
Deferred106,417 5,631 203,805 119,609 
Total income tax provision85,321 14,589 230,085 128,567 
Net income272,677 278,399 733,394 634,418 
Net income attributable to non-controlling interest in subsidiaries(24,386)(14,660)(62,605)(42,883)
Net income attributable to Matador Resources Company shareholders$248,291 $263,739 $670,789 $591,535 
Expenses per BOE
Production taxes, transportation and processing $4.61 $5.77 $4.99 $5.58 
Lease operating$5.50 $5.34 $5.50 $5.07 
Plant and other midstream services operating$2.77 $2.48 $2.74 $2.73 
Depletion, depreciation and amortization$15.39 $15.51 $15.48 $14.64 
General and administrative$1.82 $2.55 $1.96 $2.38 
Three Months Ended September 30, 2024 as Compared to Three Months Ended September 30, 2023
Production taxes, transportation and processing. Our production taxes and transportation and processing expenses increased $1.0 million, or 1%, to $72.7 million for the three months ended September 30, 2024, as compared to $71.7 million for the three months ended September 30, 2023. The increase was primarily attributable to a $5.4 million increase in production taxes to $60.2 million for the three months ended September 30, 2024, as compared to $54.8 million for the three months ended September 30, 2023, which was partially offset by a $4.3 million decrease in transportation and processing expenses to $12.6 million for the three months ended September 30, 2024, as compared to $16.9 million for the three months ended September 30, 2023. This increase in production taxes is primarily due to the increase in oil and natural gas revenues between the two periods. On a unit-of-production basis, our production taxes and transportation and processing expenses decreased 20% to $4.61 per BOE for the three months ended September 30, 2024, as compared to $5.77 per BOE for the three months ended September 30, 2023, primarily due to a favorable one-time transportation fee adjustment with a third-party vendor during the third quarter of 2024.
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Lease operating. Our lease operating expenses increased $20.4 million, or 31%, to $86.8 million for the three months ended September 30, 2024, as compared to $66.4 million for the three months ended September 30, 2023. Our lease operating expenses on a unit-of-production basis increased 3% to $5.50 per BOE for the three months ended September 30, 2024, as compared to $5.34 per BOE for the three months ended September 30, 2023. These increases were primarily attributable to the increased number of wells being operated by us and other operators (where we own a working interest) and to operating cost inflation for the three months ended September 30, 2024, as compared to the three months ended September 30, 2023.
Plant and other midstream services operating. Our plant and other midstream services operating expenses increased $12.9 million, or 42%, to $43.7 million for the three months ended September 30, 2024, as compared to $30.8 million for the three months ended September 30, 2023. This increase was primarily attributable to increased throughput volumes from Matador and other San Mateo and Pronto customers, which resulted in (i) increased expenses associated with our expanded pipeline operations of $16.5 million for the three months ended September 30, 2024, as compared to $9.9 million for the three months ended September 30, 2023, and (ii) increased expenses associated with our commercial produced water disposal operations of $16.7 million for the three months ended September 30, 2024, as compared to $12.5 million for the three months ended September 30, 2023.
Depletion, depreciation and amortization. Our depletion, depreciation and amortization expenses increased $50.0 million, or 26%, to $242.8 million for the three months ended September 30, 2024, as compared to $192.8 million for the three months ended September 30, 2023, primarily as a result of a 27% increase in our total oil equivalent production for the three months ended September 30, 2024, as compared to the three months ended September 30, 2023. On a unit-of-production basis, our depletion, depreciation and amortization expenses decreased 1% to $15.39 per BOE for the three months ended September 30, 2024, as compared to $15.51 per BOE for the three months ended September 30, 2023.
General and administrative. Our general and administrative expenses decreased $2.9 million, or 9%, to $28.8 million for the three months ended September 30, 2024, as compared to $31.7 million for the three months ended September 30, 2023. Our general and administrative expenses decreased by 29% on a unit-of-production basis to $1.82 per BOE for the three months ended September 30, 2024, as compared to $2.55 per BOE for the three months ended September 30, 2023, primarily as a result of a 27% increase in our total oil equivalent production between the two periods.
Interest expense. For the three months ended September 30, 2024, we incurred total interest expense of $44.4 million. We capitalized $8.2 million of our interest expense on certain qualifying projects for the three months ended September 30, 2024 and expensed the remaining $36.2 million to operations. For the three months ended September 30, 2023, we incurred total interest expense of $42.8 million. We capitalized $7.4 million of our interest expense on certain qualifying projects for the three months ended September 30, 2023 and expensed the remaining $35.4 million to operations. The increase in interest expense for the three months ended September 30, 2024 was primarily attributable to an increase in our average debt outstanding between the two periods. In April 2024, we completed the 2026 Notes Tender Offer, the 2026 Notes Redemption and the 2032 Notes Offering and in September 2024 we completed the 2033 Notes Offering, resulting in a net increase in our total senior notes outstanding to $2.15 billion at September 30, 2024 as compared to $1.20 billion at September 30, 2023.
Income tax provision (benefit). We recorded a current income tax benefit of $21.1 million and a deferred income tax provision of $106.4 million for the three months ended September 30, 2024. We recorded a current income tax provision of $9.0 million and a deferred income tax provision of $5.6 million for the three months ended September 30, 2023. Our effective income tax rate of 26% for the three months ended September 30, 2024 differed from the U.S. federal statutory rate due primarily to permanent differences between book and taxable income and state taxes, primarily in New Mexico. Our effective income tax rate of 5% for the three months ended September 30, 2023 differed from the U.S. federal statutory rate due primarily to recognizing research and experimental expenditure tax credits of $65.1 million in the third quarter of 2023, which were partially offset by permanent differences between book and taxable income and state taxes, primarily in New Mexico.
Nine Months Ended September 30, 2024 as Compared to Nine Months Ended September 30, 2023
Production taxes, transportation and processing. Our production taxes, transportation and processing expenses increased $30.5 million, or 16%, to $219.7 million for the nine months ended September 30, 2024, as compared to $189.2 million for the nine months ended September 30, 2023. This increase was primarily attributable to a $33.1 million increase in production taxes to $174.3 million for the nine months ended September 30, 2024, as compared to $141.2 million for the nine months ended September 30, 2023, primarily due to the increase in oil and natural gas revenues between the two periods. On a unit-of-production basis, our production taxes, transportation and processing expenses decreased 11% to $4.99 per BOE for the nine months ended September 30, 2024, as compared to $5.58 per BOE for the nine months ended September 30, 2023. This decrease was primarily attributable to a decrease in the transportation and processing expense per BOE that resulted from the mix of revenue contracts, including from San Mateo and Pronto, between the two periods.
Lease operating expenses. Our lease operating expenses increased $70.3 million, or 41%, to $242.1 million for the nine months ended September 30, 2024, as compared to $171.8 million for the nine months ended September 30, 2023. Our lease
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operating expenses per unit of production increased 8% to $5.50 per BOE for the nine months ended September 30, 2024, as compared to $5.07 per BOE for the nine months ended September 30, 2023. These increases were primarily attributable to the increased number of wells being operated by us, including 127 wells from the Advance Acquisition, and operated by other operators (where we own a working interest) and to operating cost inflation for the nine months ended September 30, 2024, as compared to the nine months ended September 30, 2023.
Plant and other midstream services operating. Our plant and other midstream services operating expenses increased $28.1 million, or 30%, to $120.6 million for the nine months ended September 30, 2024, as compared to $92.5 million for the nine months ended September 30, 2023. This increase was primarily attributable to increased throughput volumes from Matador and other San Mateo and Pronto customers, which resulted in (i) increased expenses associated with our expanded pipeline operations of $46.1 million for the three months ended September 30, 2024, as compared to $30.0 million for the three months ended September 30, 2023, and (ii) increased expenses associated with our commercial produced water disposal operations of $47.7 million for the three months ended September 30, 2024, as compared to $38.4 million for the three months ended September 30, 2023.
Depletion, depreciation and amortization. Our depletion, depreciation and amortization expenses increased $184.4 million, or 37%, to $681.1 million for the nine months ended September 30, 2024, as compared to $496.6 million for the nine months ended September 30, 2023, primarily as a result of the Advance Acquisition and the approximate 30% increase in our total oil equivalent production for the nine months ended September 30, 2024, as compared to the nine months ended September 30, 2023. On a unit-of-production basis, our depletion, depreciation and amortization expenses increased 6% to $15.48 per BOE for the nine months ended September 30, 2024, as compared to $14.64 per BOE for the nine months ended September 30, 2023, primarily as a result of the Advance Acquisition.
General and administrative. Our general and administrative expenses increased $5.5 million, or 7%, to $86.4 million for the nine months ended September 30, 2024, as compared to $80.9 million for the nine months ended September 30, 2023, primarily as a result of increased payroll for our existing employees as well as with additional employees joining Matador to support our increased land, geoscience, drilling, completion, production, midstream and administration functions as a result of our continued growth. Our general and administrative expenses decreased by 18% on a unit-of-production basis to $1.96 per BOE for the nine months ended September 30, 2024, as compared to $2.38 per BOE for the nine months ended September 30, 2023, primarily as a result of the approximate 30% increase in our total oil equivalent production between the two periods.
Interest expense. For the nine months ended September 30, 2024, we incurred total interest expense of approximately $135.1 million. We capitalized approximately $23.4 million of our interest expense on certain qualifying projects for the nine months ended September 30, 2024 and expensed the remaining $111.7 million to operations. For the nine months ended September 30, 2023, we incurred total interest expense of approximately $101.9 million. We capitalized approximately $16.1 million of our interest expense on certain qualifying projects for the nine months ended September 30, 2023 and expensed the remaining $85.8 million to operations. The increase in interest expense for the nine months ended September 30, 2024 was primarily attributable to an increase in our average debt outstanding between the two periods. In April 2024, we completed the 2026 Notes Tender Offer, the 2026 Notes Redemption and the 2032 Notes Offering and in September 2024 we completed the 2033 Notes Offering, resulting in a net increase in our total senior notes outstanding to $2.15 billion at September 30, 2024 as compared to $1.20 billion at September 30, 2023. In connection with the 2026 Notes Tender Offer, 2026 Notes Redemption and the amendment of our Credit Agreement in March 2024, we also incurred a loss of approximately $5.6 million included in interest expense for the nine months ended September 30, 2024.
Income tax provision (benefit). We recorded a current income tax provision of $26.3 million and a deferred income tax provision of $203.8 million for the nine months ended September 30, 2024. We recorded a current income tax provision of $9.0 million and a deferred income tax provision of $119.6 million for the nine months ended September 30, 2023. Our effective income tax rate of 26% for the nine months ended September 30, 2024 differed from the U.S. federal statutory rate due primarily to permanent differences between book and taxable income and state taxes, primarily in New Mexico. Our effective income tax rate of 18% for the nine months ended September 30, 2023 differed from the U.S. federal statutory rate due primarily to recognizing research and experimental expenditure tax credits of $65.1 million in the third quarter of 2023, which were partially offset by permanent differences between book and taxable income and state taxes, primarily in New Mexico.
Liquidity and Capital Resources
Our primary use of capital has been, and we expect will continue to be during the remainder of 2024 and for the foreseeable future, for the acquisition, exploration and development of oil and natural gas properties and for midstream investments. On September 18, 2024, we closed the Ameredev Acquisition that was funded through a combination of cash on hand and borrowings under our Credit Agreement. On August 21, 2024, Piñon announced that it expects to be acquired by an affiliate of Enterprise Products Partners L.P. in the fourth quarter of 2024, subject to customary regulatory approvals. We currently expect to receive between $110.0 million and $120.0 million from the sale of Piñon and we expect to use these
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proceeds to reduce borrowings under our Credit Agreement. Excluding the Ameredev Acquisition and any future significant acquisitions, we expect to fund our 2024 capital expenditures through a combination of cash on hand, operating cash flows and performance incentives paid to us by Five Point Energy, LLC or its affiliates. If capital expenditures were to exceed our operating cash flows during the remainder of 2024, we expect to fund any such excess capital expenditures, including for significant acquisitions, through borrowings under the Credit Agreement or the San Mateo Credit Facility (assuming availability under such facilities) or through other capital sources, including borrowings under expanded or additional credit arrangements, the sale or joint venture of midstream assets, oil and natural gas producing assets, leasehold interests or mineral interests and potential issuances of equity, debt or convertible securities, none of which may be available on satisfactory terms or at all. Our future success in growing proved reserves and production will be highly dependent on our ability to generate operating cash flows and access outside sources of capital.
The Board declared quarterly cash dividends of $0.20 per share of common stock in each of the first, second and third quarters of 2024. On October 16, 2024, the Board amended our dividend policy to increase the quarterly dividend to $0.25 per share of common stock for future dividend payments and also declared a quarterly cash dividend of $0.25 per share of common stock payable on December 6, 2024 to shareholders of record as of November 15, 2024.
On March 22, 2024, we and our lenders entered into an amendment to the Fourth Amended and Restated Credit Agreement, which amended our Credit Agreement to, among other things: (i) reaffirm the borrowing base at $2.50 billion,
(ii) increase the elected borrowing commitments from $1.325 billion to $1.50 billion, (iii) increase the maximum facility amount from $2.00 billion to $3.50 billion, (iv) extend the maturity date from October 31, 2026 to March 22, 2029, (v) appoint PNC Bank, National Association as administrative agent thereunder and (vi) add five new banks to the lending group. This March 2024 reaffirmation of the borrowing base constituted the regularly scheduled May 1 redetermination.
On September 18, 2024, we and our lenders entered into an amendment to the Fourth Amended and Restated Credit Agreement, which amended our Credit Agreement to, among other things: (i) provide for a term loan of $250.0 million, the full amount of which was borrowed to fund the Ameredev Acquisition, and (ii) increase the elected borrowing commitments under our revolving credit facility from $1.50 billion to $2.25 billion.
The Credit Agreement requires us 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 at the end of each fiscal quarter and (ii) a debt to EBITDA ratio, which is defined as debt outstanding (net of cash or cash equivalents of up to the greater of (a) $150.0 million and (b) 10% of the elected commitment), divided by a rolling four quarter EBITDA calculation, of 3.5 or less. We believe that we were in compliance with the terms of the Credit Agreement at September 30, 2024.
On March 28, 2024, we completed the 2024 Equity Offering. After deducting underwriting discounts and offering expenses, we received net proceeds of approximately $342.1 million. The net proceeds from the 2024 Equity Offering were used for general corporate purposes, including the funding of acquisitions and the repayment of borrowings outstanding under our Credit Agreement.
On April 2, 2024, we completed the 2032 Notes Offering. We used the net proceeds from the 2032 Notes Offering of approximately $885.0 million, after deducting the initial purchasers’ discounts and estimated offering expenses, to fund the 2026 Notes Tender Offer and 2026 Notes Redemption and for general corporate purposes, including the funding of acquisitions and the repayment of borrowings outstanding under our Credit Agreement.
On September 25, 2024, we completed the 2033 Notes Offering. We used the net proceeds from the 2033 Notes Offering of approximately $736.4 million, after deducting the initial purchasers’ discounts and estimated offering expenses, to partially repay borrowings outstanding under our Credit Agreement, including all of the $250.0 million in outstanding borrowings under the term loan.
At September 30, 2024, we had cash totaling $23.3 million and restricted cash totaling $53.7 million, which was primarily associated with San Mateo. By contractual agreement, the cash in the accounts held by our less-than-wholly-owned subsidiaries is not to be commingled with our other cash and is to be used only to fund the capital expenditures and operations of these less-than-wholly-owned subsidiaries.
At September 30, 2024, we had (i) $500.0 million of outstanding 2028 Notes, (ii) $900.0 million of outstanding 2032 Notes, (iii) $750.0 million of outstanding 2033 Notes, (iv) $955.0 million in borrowings outstanding under the Credit Agreement and (v) approximately $52.9 million in outstanding letters of credit issued pursuant to the Credit Agreement. Between September 30, 2024 and October 22, 2024, we repaid $65.0 million of borrowings under the Credit Agreement.
At September 30, 2024, San Mateo had $526.0 million in borrowings outstanding under the San Mateo Credit Facility and approximately $9.0 million in outstanding letters of credit issued pursuant to the San Mateo Credit Facility. Between September 30, 2024 and October 22, 2024, San Mateo repaid $32.0 million of borrowings under the San Mateo Credit Facility.
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The outstanding borrowings under the San Mateo Credit Facility mature on December 9, 2026, and lender commitments under the facility were $535.0 million at September 30, 2024. The San Mateo Credit Facility includes an accordion feature, which provides for potential increases in lender commitments of 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. 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. We believe that San Mateo was in compliance with the terms of the San Mateo Credit Facility at September 30, 2024.
We expect that development of our Delaware Basin assets will be the primary focus of our operations and capital expenditures for the remainder of 2024. We began 2024 operating seven drilling rigs in the Delaware Basin. We added an eighth operated drilling rig in the first quarter of 2024 and a ninth operated drilling rig late in the second quarter of 2024. Prior to the closing of the Ameredev Acquisition, Ameredev was operating one drilling rig, and upon the consummation of the Ameredev Acquisition, we continued operating a total of nine drilling rigs on the combined Matador and Ameredev properties covering approximately 196,200 net acres. We have built significant optionality into our drilling program, which should generally allow us to decrease or increase the number of rigs we operate as necessary based on changing commodity prices and other factors. On October 22, 2024, we increased our estimated D/C/E capital expenditures for 2024 to a range of $1.15 to $1.35 billion from a range of $1.10 to $1.30 billion, which includes our expected D/C/E capital expenditures on acreage acquired in the Ameredev Acquisition. At October 22, 2024, our estimated midstream capital expenditures for 2024 remained $200.0 to $250.0 million, which includes our proportionate share of San Mateo’s estimated 2024 capital expenditures as well as the estimated 2024 capital expenditures for other wholly-owned midstream projects, including projects completed by Pronto. The midstream capital expenditure budget includes 100% of the costs associated with the Marlan Processing Plant expansion noted above, although, at October 22, 2024, we were continuing to evaluate potential partners in Pronto that would share in these capital expenditures and strategic opportunities. The midstream capital expenditure budget excludes the acquisition cost of Ameredev’s midstream assets. Substantially all of these 2024 estimated capital expenditures are expected to be allocated to (i) the further delineation and development of our leasehold position, (ii) the construction, installation and maintenance of midstream assets and (iii) our participation in certain non-operated well opportunities in the Delaware Basin, South Texas and Haynesville shale. Our 2024 Delaware Basin operated drilling program is expected to focus on the continued development of our various asset areas throughout the Delaware Basin, with a continued emphasis on drilling and completing a high percentage of longer horizontal wells in 2024, including 99% with anticipated completed lateral lengths of one mile or greater.
As we have done in recent years, we may divest portions of our non-core assets, particularly in the Eagle Ford shale in South Texas and the Haynesville shale in Northwest Louisiana, as well as consider monetizing other assets, such as certain midstream assets and mineral and royalty interests, as value-creating opportunities arise. In addition, during 2024, we intend to continue evaluating the opportunistic acquisition of producing properties, acreage and mineral interests and midstream assets, principally in the Delaware Basin. These monetizations, divestitures and expenditures are opportunity-specific, and purchase price multiples and per-acre prices can vary significantly based on the asset or prospect. As a result, it is difficult to estimate these 2024 monetizations, divestitures and capital expenditures with any degree of certainty; therefore, we have not provided estimated proceeds related to monetizations or divestitures or estimated capital expenditures related to acquiring producing properties, acreage and mineral interests and midstream assets for 2024.
Our 2024 capital expenditures may be adjusted as business conditions warrant, and the amount, timing and allocation of such expenditures is largely discretionary and within our control. The aggregate amount of capital we will expend may fluctuate materially based on market conditions, the actual costs to drill, complete and place on production operated or non-operated wells, our drilling results, the actual costs and scope of our midstream activities, the ability of our joint venture partners to meet their capital obligations, other opportunities that may become available to us and our ability to obtain capital. When oil or natural gas prices decline, or costs increase significantly, we have the flexibility to defer a significant portion of our capital expenditures until later periods to conserve cash or to focus on projects that we believe have the highest expected returns and potential to generate near-term cash flows. We routinely monitor and adjust our capital expenditures in response to changes in prices, availability of financing, drilling, completion and acquisition costs, industry conditions, the timing of regulatory approvals, the availability of rigs, success or lack of success in our exploration and development activities, contractual obligations, drilling plans for properties we do not operate and other factors both within and outside our control.
Exploration and development activities are subject to a number of risks and uncertainties, which could cause these activities to be less successful than we anticipate. A significant portion of our anticipated cash flows from operations for the remainder of 2024 is expected to come from producing wells and development activities on currently proved properties in the
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Wolfcamp and Bone Spring plays in the Delaware Basin, the Eagle Ford shale in South Texas and the Haynesville shale in Northwest Louisiana. Our existing operated and non-operated wells may not produce at the levels we are forecasting or may be temporarily shut in or restricted due to low commodity prices, and our exploration and development activities in these areas may not be as successful as we anticipate. Additionally, our anticipated cash flows from operations are based upon current expectations of oil and natural gas prices for 2024 and the hedges we currently have in place. For further discussion of our expectations of such commodity prices, see “—General Outlook and Trends” below. At times, we use commodity derivative financial instruments to mitigate our exposure to fluctuations in oil, natural gas and NGL prices and to partially offset reductions in our cash flows from operations resulting from declines in commodity prices. See Note 8 to the interim unaudited condensed consolidated financial statements in this Quarterly Report for a summary of our open derivative financial instruments.
Our unaudited cash flows for the nine months ended September 30, 2024 and 2023 are presented below:
 Nine Months Ended
September 30,
(In thousands)20242023
Net cash provided by operating activities$1,671,926 $1,249,481 
Net cash used in investing activities(3,280,718)(2,662,324)
Net cash provided by financing activities1,579,517 927,687 
Net change in cash and restricted cash$(29,275)$(485,156)
Adjusted EBITDA attributable to Matador Resources Company shareholders(1)
$1,657,927 $1,296,750 
__________________
(1)Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to our net income and net cash provided by operating activities, see “—Non-GAAP Financial Measures” below.
Net Cash Provided by Operating Activities
Net cash provided by operating activities increased $422.4 million to $1.67 billion for the nine months ended September 30, 2024 from $1.25 billion for the nine months ended September 30, 2023. Excluding changes in operating assets and liabilities, net cash provided by operating activities increased $341.1 million to $1.62 billion for the nine months ended September 30, 2024 from $1.28 billion for the nine months ended September 30, 2023. This increase was primarily attributable to higher oil and natural gas production and higher realized oil prices for the nine months ended September 30, 2024, as compared to the nine months ended September 30, 2023, partially offset by lower realized natural gas prices. Changes in our operating assets and liabilities between the two periods resulted in a net increase of approximately $81.3 million in net cash provided by operating activities for the nine months ended September 30, 2024, as compared to the nine months ended September 30, 2023.
Net Cash Used in Investing Activities
Net cash used in investing activities increased $618.4 million to $3.28 billion for the nine months ended September 30, 2024 from $2.66 billion for the nine months ended September 30, 2023. This increase in net cash used in investing activities was primarily due to (i) $1.83 billion in expenditures related to the Ameredev Acquisition in the third quarter of 2024, (ii) an increase between the periods of $201.2 million in expenditures related to the acquisition of oil and natural gas properties,
(iii) an increase between the periods of $143.6 million in midstream capital expenditures and (iv) an increase between the periods of $50.0 million in D/C/E capital expenditures primarily attributable to our operated and non-operated drilling, completion and equipping activities in the Delaware Basin. These increases were partially offset by a decrease between the periods of $1.61 billion in expenditures related to the Advance Acquisition in the second quarter of 2023.
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Net Cash Provided by Financing Activities
Net cash provided by financing activities increased $651.8 million to $1.58 billion for the nine months ended September 30, 2024 from $927.7 million for the nine months ended September 30, 2023. During the nine months ended September 30, 2024, our primary sources of cash from financing activities included (i) proceeds from the 2032 Notes Offering of $900.0 million, (ii) proceeds from the 2033 Notes Offering of $750.0 million, (iii) proceeds from the 2024 Equity Offering of $344.7 million and (iv) net borrowings under the Credit Agreement of $455.0 million. These increases were partially offset by (i) the repurchase of an aggregate principal amount of approximately $699.2 million of 2026 Notes, (ii) dividends paid of $73.6 million, (iii) net distributions related to San Mateo of $31.4 million, (iv) costs associated with the 2032 Notes Offering and 2033 Notes Offering of $26.1 million, (v) costs to amend the Credit Agreement of $25.9 million and (vi) payment of taxes related to stock-based compensation of $14.5 million. During the nine months ended September 30, 2023, our primary sources of cash from financing activities included proceeds from the issuance of the 2028 Notes of $494.8 million and net borrowings under the Credit Agreement of $530.0 million, partially offset by dividends of $53.5 million, payment of taxes related to stock-based compensation of $22.8 million and net distributions related to San Mateo of $12.9 million.
See Note 5 to the interim unaudited condensed consolidated financial statements in this Quarterly Report for a summary of our debt, including the Credit Agreement, the San Mateo Credit Facility, the 2028 Notes, the 2032 Notes and the 2033 Notes.
Non-GAAP Financial Measures
We define Adjusted EBITDA as earnings before interest expense, income taxes, depletion, depreciation and amortization, accretion of asset retirement obligations, property impairments, unrealized derivative gains and losses, non-recurring transaction costs for certain acquisitions, certain other non-cash items and non-cash stock-based compensation expense and net gain or loss on asset sales and impairment. Adjusted EBITDA is not a measure of net income or cash flows as determined by GAAP. Adjusted EBITDA is a supplemental non-GAAP financial measure that is used by management and external users of our consolidated financial statements, such as industry analysts, investors, lenders and rating agencies.
Management believes Adjusted EBITDA is necessary because it allows us to evaluate our operating performance and compare the results of operations from period to period without regard to our financing methods or capital structure. We exclude the items listed above from net income in calculating Adjusted EBITDA because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures and the method by which certain assets were acquired.
Adjusted EBITDA should not be considered an alternative to, or more meaningful than, net income or net cash provided by operating activities as determined in accordance with GAAP or as a primary indicator of our operating performance or liquidity. Certain items excluded from Adjusted EBITDA are significant components of understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure. Our Adjusted EBITDA may not be comparable to similarly titled measures of another company because all companies may not calculate Adjusted EBITDA in the same manner.
The following table presents our calculation of Adjusted EBITDA and the reconciliation of Adjusted EBITDA to the GAAP financial measures of net income and net cash provided by operating activities, respectively.
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 Three Months Ended
September 30,		Nine Months Ended
September 30,
(In thousands)2024202320242023
Unaudited Adjusted EBITDA Reconciliation to Net Income
Net income attributable to Matador Resources Company shareholders$248,291 $263,739 $670,789 $591,535 
Net income attributable to non-controlling interest in subsidiaries24,386 14,660 62,605 42,883 
Net income272,677 278,399 733,394 634,418 
Interest expense36,169 35,408 111,717 85,813 
Total income tax provision85,321 14,589 230,085 128,567 
Depletion, depreciation and amortization242,821 192,794 681,066 496,633 
Accretion of asset retirement obligations1,657 1,218 4,259 2,709 
Unrealized (gain) loss on derivatives(35,118)(7,482)(25,364)8,244 
Non-cash stock-based compensation expense4,279 4,556 10,091 10,777 
Net loss on impairment — — — 202 
Expense (income) related to contingent consideration and other243 11,895 3,176 (2,740)
Consolidated Adjusted EBITDA608,049 531,377 1,748,424 1,364,623 
Adjusted EBITDA attributable to non-controlling interest in subsidiaries(33,565)(23,102)(90,497)(67,873)
Adjusted EBITDA attributable to Matador Resources Company shareholders$574,484 $508,275 $1,657,927 $1,296,750 
 Three Months Ended
September 30,		Nine Months Ended
September 30,
(In thousands)2024202320242023
Unaudited Adjusted EBITDA Reconciliation to Net Cash Provided by Operating Activities
Net cash provided by operating activities$610,437 $460,970 $1,671,926 $1,249,481 
Net change in operating assets and liabilities(15,367)31,943 (53,416)27,919 
Interest expense, net of non-cash portion33,469 33,307 99,431 80,817 
Current income tax (benefit) provision(21,096)8,958 26,280 8,958 
Other non-cash and non-recurring expense606 (3,801)4,203 (2,552)
Adjusted EBITDA attributable to non-controlling interest in subsidiaries(33,565)(23,102)(90,497)(67,873)
Adjusted EBITDA attributable to Matador Resources Company shareholders$574,484 $508,275 $1,657,927 $1,296,750 
For the three months ended September 30, 2024, net income attributable to Matador shareholders decreased $15.4 million to $248.3 million, as compared to $263.7 million for the three months ended September 30, 2023. The decrease in net income attributable to Matador shareholders primarily resulted from increased depletion, depreciation and amortization expenses of $242.8 million for the three months ended September 30, 2024, as compared to $192.8 million for the three months ended September 30, 2023, and an income tax provision of $85.3 million for the three months ended September 30, 2024, as compared to an income tax provision of $14.6 million for the three months ended September 30, 2023. These decreases to net income were partially offset by higher oil and natural gas production for the three months ended September 30, 2024, as compared to the three months ended September 30, 2023, which was partially offset by lower realized oil and natural gas prices.
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For the nine months ended September 30, 2024, net income attributable to Matador shareholders increased $79.3 million to $670.8 million, as compared to net income attributable to Matador shareholders of $591.5 million for the nine months ended September 30, 2023. This increase in net income attributable to Matador shareholders primarily resulted from higher oil and natural gas production for the nine months ended September 30, 2024, as compared to the nine months ended September 30, 2023. These increases were partially offset by increased depletion, depreciation and amortization expenses of $681.1 million for the nine months ended September 30, 2024, as compared to $496.6 million for the nine months ended September 30, 2023, increased lease operating expense of $242.1 million for the nine months ended September 30, 2024, as compared to $171.8 million for the nine months ended September 30, 2023, increased interest expense of $111.7 million for the nine months ended September 30, 2024, as compared to $85.8 million for the nine months ended September 30, 2023, and an income tax provision of $230.1 million for the nine months ended September 30, 2024, as compared to $128.6 million for the nine months ended September 30, 2023.
Adjusted EBITDA, a non-GAAP financial measure, increased $66.2 million to $574.5 million for the three months ended September 30, 2024, as compared to $508.3 million for the three months ended September 30, 2023. This increase was primarily attributable to higher oil and natural gas production, partially offset by lower oil and natural gas prices, for the three months ended September 30, 2024, as compared to the three months ended September 30, 2023.
Adjusted EBITDA, a non-GAAP financial measure, increased $361.2 million to $1.66 billion for the nine months ended September 30, 2024, as compared to $1.30 billion for the nine months ended September 30, 2023. This increase is primarily attributable to higher oil and natural gas production and higher realized oil prices, partially offset by lower natural gas prices, for the nine months ended September 30, 2024, as compared to the nine months ended September 30, 2023.
Off-Balance Sheet Arrangements
From time to time, we enter into off-balance sheet arrangements and transactions that can give rise to material off-balance sheet obligations. As of September 30, 2024, the material off-balance sheet arrangements and transactions that we have entered into include (i) non-operated drilling commitments, (ii) firm gathering, transportation, processing, fractionation, sales and disposal commitments and (iii) contractual obligations for which the ultimate settlement amounts are not fixed and determinable, such as derivative contracts that are sensitive to future changes in commodity prices or interest rates, gathering, treating, transportation and disposal commitments on uncertain volumes of future throughput, open delivery commitments and indemnification obligations following certain divestitures. Other than the off-balance sheet arrangements described above, we have no transactions, arrangements or other relationships with unconsolidated entities or other persons that are reasonably likely to materially affect our liquidity or availability of or requirements for capital resources. See “—Obligations and Commitments” below and Note 10 to the interim unaudited condensed consolidated financial statements in this Quarterly Report for more information regarding our off-balance sheet arrangements. Such information is incorporated herein by reference.
Obligations and Commitments
We had the following material contractual obligations and commitments at September 30, 2024:
 Payments Due by Period
(In thousands)TotalLess
Than
1 Year		1 - 3
Years		3 - 5
Years		More
Than
5 Years
Contractual Obligations
Borrowings, including letters of credit(1)
$1,542,908 $— $535,000 $1,007,908 $— 
Senior unsecured notes(2)
2,150,000 — — 500,000 1,650,000 
Office leases6,964 4,409 2,555 — — 
Non-operated drilling commitments(3)
50,507 50,507 — — — 
Drilling rig contracts(4)
22,967 22,967 — — — 
Asset retirement obligations(5)
124,639 5,247 6,351 2,063 110,978 
Transportation, gathering, processing and disposal agreements with non-affiliates(6)
617,478 112,243 202,501 146,051 156,683 
Transportation, gathering, processing and disposal agreements with San Mateo(7)
131,747 17,939 113,808 — — 
Midstream contracts(8)
107,785 107,785 — — — 
Total contractual cash obligations$4,754,995 $321,097 $860,215 $1,656,022 $1,917,661 
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(1)The amounts included in the table above represent principal maturities only. At September 30, 2024, we had $955.0 million in borrowings outstanding under the Credit Agreement and approximately $52.9 million in outstanding letters of credit issued pursuant to the Credit Agreement. The Credit Agreement matures March 22, 2029. At September 30, 2024, San Mateo had $526.0 million of borrowings outstanding under the San Mateo Credit Facility and approximately $9.0 million in outstanding letters of credit issued pursuant to the San Mateo Credit Facility. The San Mateo Credit Facility matures December 9, 2026. Assuming the amounts outstanding and interest rates of 7.14% and 7.45%, respectively, for the Credit Agreement and the San Mateo Credit Facility at September 30, 2024, the interest expense for such facilities is expected to be approximately $69.1 million and $39.7 million, respectively, each year until maturity.
(2)The amounts included in the table above represent principal maturities only. Interest expense on the $500.0 million of outstanding 2028 Notes as of September 30, 2024 is expected to be approximately $34.4 million each year until maturity. Interest expense on the $900.0 million of outstanding 2032 Notes as of September 30, 2024 is expected to be approximately $58.5 million. Interest expense on the $750.0 million of outstanding 2033 Notes as of September 30, 2024 is expected to be approximately $46.9 million.
(3)At September 30, 2024, we had outstanding commitments to participate in the drilling and completion of various non-operated wells.
(4)We do not own or operate our own drilling rigs, but instead we enter into contracts with third parties for such drilling rigs.
(5)The amounts included in the table above represent discounted cash flow estimates for future asset retirement obligations at September 30, 2024.
(6)From time to time, we enter into agreements with third parties whereby we commit to deliver anticipated natural gas and oil production and produced water from certain portions of our acreage for transportation, gathering, processing, fractionation, sales and disposal. Certain of these agreements contain minimum volume commitments. If we do not meet the minimum volume commitments under these agreements, we would be required to pay certain deficiency fees. See Note 10 to the interim unaudited condensed consolidated financial statements in this Quarterly Report for more information about these contractual commitments.
(7)We dedicated to San Mateo our current and certain future leasehold interests in the Rustler Breaks asset area and the Wolf portion of the West Texas asset area and acreage in the southern portion of the Arrowhead asset area (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, we dedicated to San Mateo our 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. See Note 10 to the interim unaudited condensed consolidated financial statements in this Quarterly Report for more information about these contractual commitments.
(8)At September 30, 2024, we had outstanding commitments related to the construction and installation of Pronto’s additional natural gas processing plant with a designed inlet processing capacity of 200 MMcf per day, including a nitrogen rejection unit and additional related facilities, in addition to commitments to purchase compressors to be utilized in midstream operations.
General Outlook and Trends
Our business success and financial results are dependent on many factors beyond our control, such as economic, political and regulatory developments, as well as competition from other sources of energy. For example, the results of the 2024 presidential election and any potential political uncertainty in the United States may alter our current regulatory framework and impact our business and the oil and gas industry generally. Commodity price volatility, in particular, is a significant risk to our business, cash flows and results of operations. Commodity prices are affected by changes in market supply and demand, which are impacted by overall economic activity, ongoing military conflicts, political instability, particularly in China or the Middle East, the actions of Organization of Petroleum Exporting Countries, Russia and certain other oil-exporting countries (“OPEC+”), weather, pipeline capacity constraints, inventory storage levels, oil and natural gas price differentials and other factors.
The prices we receive for oil, natural gas and NGLs heavily influence our revenues, profitability, cash flow available for capital expenditures, the repayment of debt and the payment of cash dividends, if any, access to capital, borrowing capacity under our Credit Agreement and future rate of growth. Oil, natural gas and NGL prices are subject to wide fluctuations in response to relatively minor changes in supply and demand. Historically, the markets for oil, natural gas and NGLs have been volatile, and these markets will likely continue to be volatile in the future. Declines in oil, natural gas or NGL prices not only reduce our revenues, but could also reduce the amount of oil, natural gas and NGLs we can produce economically and, as a result, could have a material adverse effect on our financial condition, results of operations, cash flows and reserves and our ability to comply with the financial covenants under our Credit Agreement. See “Risk Factors—Risks Related to our Financial Condition—Our success is dependent on the prices of oil, natural gas and NGLs. Low oil, natural gas and NGL prices and the continued volatility in these prices may adversely affect our financial condition and our ability to meet our capital expenditure requirements and financial obligations” in the Annual Report.
Oil prices were lower in the third quarter of 2024, as compared to the third quarter of 2023. For the three months ended September 30, 2024, oil prices averaged $75.27 per Bbl, ranging from a high of $83.88 per Bbl in early July to a low of $65.75 per Bbl in mid-September, based upon the West Texas Intermediate (“WTI”) oil futures contract price for the earliest delivery date. Oil prices averaged $82.22 per Bbl for the three months ended September 30, 2023. We realized a weighted average oil price of $75.67 per Bbl (with no realized gains or losses from oil derivatives) for our oil production for the three months ended September 30, 2024, as compared to $82.49 per Bbl (with no realized gains or losses from oil derivatives) for our oil production for the three months ended September 30, 2023. At October 22, 2024, the WTI oil futures contract for the earliest delivery date had decreased from the average price for the third quarter of 2024 of $75.27 per Bbl, settling at $72.09 per Bbl, which was a decrease as compared to $88.75 per Bbl at October 20, 2023.
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Natural gas prices were lower in the third quarter of 2024, as compared to the third quarter of 2023. For the three months ended September 30, 2024, natural gas prices averaged $2.23 per MMBtu, ranging from a low of $1.90 per MMBtu in late August to a high of $2.92 per MMBtu in late September, based upon the NYMEX Henry Hub natural gas futures contract price for the earliest delivery date. Natural gas prices averaged $2.66 per MMBtu for the three months ended September 30, 2023. We report production volumes in two streams, oil and natural gas (which includes both dry gas and NGLs). Waha prices were also lower for the third quarter of 2024, as compared to the third quarter of 2023, which contributed to lower realized weighted average natural gas prices for the third quarter of 2024. We realized a weighted average natural gas price of $1.83 per Mcf ($1.94 per Mcf including realized gains from natural gas derivatives) for our natural gas production (including revenues attributable to NGLs) for the three months ended September 30, 2024, as compared to $3.56 per Mcf ($3.34 per Mcf including realized losses from natural gas derivatives) for our natural gas production (including revenues attributable to NGLs) for the three months ended September 30, 2023. Certain volumes of our natural gas production are sold at prices established at the beginning of each month by the various markets where we sell our natural gas production, and certain volumes of our natural gas production are sold at daily market prices. At October 22, 2024, the NYMEX Henry Hub natural gas futures contract price for the earliest delivery date had increased from the average price for the third quarter of 2024 of $2.23 per MMBtu, to $2.31 per MMBtu, which was a decrease as compared to $2.90 per MMBtu at October 20, 2023.
The prices we receive for oil and natural gas production often reflect a discount to the relevant benchmark prices, such as the WTI oil price or the NYMEX Henry Hub natural gas price. The difference between the benchmark price and the price we receive is called a differential. At September 30, 2024, most of our oil production from the Delaware Basin was sold based on prices established in Midland, Texas, and a significant portion of our natural gas production from the Delaware Basin was sold based on Houston Ship Channel pricing, while the remainder of our Delaware Basin natural gas production was sold primarily based on prices established at the Waha hub in far West Texas.
The Midland-Cushing (Oklahoma) oil price differential has been highly volatile in recent years. At October 22, 2024, this oil price differential was positive at approximately +$0.60 per Bbl. At October 22, 2024, we had no derivative contracts in place to mitigate our exposure to this Midland-Cushing (Oklahoma) oil price differential for 2024.
Certain volumes of our Delaware Basin natural gas production are exposed to the Waha-Henry Hub basis differential, which has also been highly volatile in recent years. Concerns about natural gas pipeline takeaway capacity out of the Delaware Basin have increased, particularly beginning in the latter half of 2022. As a result, the Waha-Henry Hub basis differential began to widen. The Waha-Henry Hub basis differential averaged ($2.35) per MMBtu for the nine months ended September 30, 2024. Between September 30, 2024 and October 22, 2024, this natural gas price differential remained wide at approximately ($2.30) per MMBtu. As a result of low natural gas prices or wide Waha basis differentials, from time to time we or our non-operated partners may elect to temporarily shut in or restrict a portion of our natural gas production. A significant portion of our Delaware Basin natural gas production, however, is sold at Houston Ship Channel pricing and is not exposed to Waha pricing. During 2022 and 2023, we typically realized a narrower differential to natural gas sold at the Waha hub despite higher transportation charges incurred to transport the natural gas to the Gulf Coast. At certain times, we may also sell a portion of our natural gas production into other markets to improve our realized natural gas pricing. Further, approximately 6% of our reported natural gas production for the nine months ended September 30, 2024 was attributable to the Haynesville and Eagle Ford shale plays, which are not exposed to Waha pricing. In addition, as a two-stream reporter, most of our natural gas volumes in the Delaware Basin are processed for NGLs, resulting in a further reduction in the reported natural gas volumes exposed to Waha pricing.
From time to time, we use derivative financial instruments to mitigate our exposure to commodity price risk associated with oil, natural gas and NGL prices. Even so, decisions as to whether, at what price and what production volumes to hedge are difficult and depend on market conditions and our forecast of future production and oil, natural gas and NGL prices, and we may not always employ the optimal hedging strategy. This, in turn, may affect the liquidity that can be accessed through the borrowing base under the Credit Agreement and through the capital markets. During the first nine months of 2024, we realized a net gain on our natural gas basis differential derivative contracts of approximately $8.6 million, resulting primarily from natural gas basis differentials that were below the fixed prices of certain of our natural gas basis differential swap contracts. At October 22, 2024, we had derivative natural gas basis differential swap contracts in place to mitigate our exposure to the Waha-Henry Hub basis differential for approximately 2.8 Bcf of our anticipated natural gas production for the remainder of 2024 and 11.0 Bcf for 2025.
We have at times experienced pipeline-related interruptions to our oil, natural gas or NGL production or produced water disposal. In certain recent periods, shortages of NGL fractionation capacity were experienced by certain operators in the Delaware Basin. Although we did not encounter such fractionation capacity problems, we can provide no assurances that such problems will not arise. If we do experience any material interruptions with produced water disposal, takeaway capacity or NGL fractionation, our oil and natural gas revenues, business, financial condition, results of operations and cash flows could be adversely affected. Should we experience future periods of negative pricing for natural gas, as we did during the second and
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third quarters of 2024, we may temporarily shut in certain high gas-oil ratio wells and take other actions to mitigate the impact on our realized natural gas prices and results.
We have at times experienced inflation in the costs of certain oilfield services, including diesel, steel, labor, trucking, sand, personnel and completion costs, among others. Should oil prices remain at their current levels or increase, we may be subject to additional service cost inflation in future periods, which may increase our costs to drill, complete, equip and operate wells. In addition, supply chain disruptions and other inflationary pressures experienced in recent periods throughout the United States and global economy and in the oil and natural gas industry may limit our ability to procure the necessary products and services we need for drilling, completing and producing wells in a timely and cost-effective manner, which could result in reduced margins and delays to our operations and could, in turn, adversely affect our business, financial condition, results of operations and cash flows.
Our oil and natural gas exploration, development, production, midstream and related operations are subject to extensive federal, state and local laws, rules and regulations. Failure to comply with these laws, rules and regulations can result in substantial monetary penalties or delay or suspension of operations. The regulatory burden on the oil and natural gas industry increases our cost of doing business and affects our profitability. Because these laws, rules and regulations are frequently amended or reinterpreted and new laws, rules and regulations are proposed or promulgated, we are unable to predict the future cost or impact of complying with the laws, rules and regulations to which we are, or will become, subject. For more information about the Company’s regulatory matters, see “Business—Regulation” and “Risk Factors—Risks Related to Laws and Regulations” in the Annual Report.
On March 6, 2024, the SEC adopted a new set of rules that require a wide range of climate-related disclosures, including material climate-related risks, information on any climate-related targets or goals that are material to the registrant’s business, results of operations or financial condition, Scope 1 and Scope 2 greenhouse gas emissions on a phased-in basis by certain larger registrants when those emissions are material and the filing of an attestation report covering the same, and disclosure of the financial statement effects of severe weather events and other natural conditions, including costs and losses. Compliance dates under the final rule are phased in by registrant category. Multiple lawsuits have been filed challenging the SEC’s new climate rules, which have been consolidated and will be heard in the U.S. Court of Appeals for the Eighth Circuit. On April 4, 2024, the SEC issued an order staying the final rules until judicial review is complete.
In accordance with the requirements of the Inflation Reduction Act of 2022, on January 26, 2024, the Environmental Protection Agency (“EPA”) published its proposed rule regarding the waste emissions charge, applicable to excess methane emissions at certain oil and natural gas facilities. Further, on March 8, 2024, the EPA published its final rules imposing new, stricter requirements for methane monitoring, reporting and emissions control at certain oil and natural gas facilities. Finally, on April 10, 2024, the Bureau of Land Management published its final waste prevention rule, which requires operators of oil and gas leases to take reasonable steps to avoid natural gas waste or pay royalties on certain natural gas waste, as well as develop leak detection, repair, and waste minimization plans.
Like other oil and natural gas producing companies, our properties are subject to natural production declines. By their nature, our oil and natural gas wells will experience rapid initial production declines. We attempt to overcome these production declines by drilling to develop and identify additional reserves, by exploring for new sources of reserves and, at times, by acquisitions. During times of severe oil, natural gas and NGL price declines, however, drilling additional oil or natural gas wells may not be economic, and we may find it necessary to reduce capital expenditures and curtail drilling operations in order to preserve liquidity. A significant reduction in capital expenditures and drilling activities could materially impact our production volumes, revenues, reserves, cash flows and the availability under our Credit Agreement. See “Risk Factors—Risks Related to our Financial Condition—Our exploration, development, exploitation and midstream projects require substantial capital expenditures that may exceed our cash flows from operations and potential borrowings, and we may be unable to obtain needed capital on satisfactory terms, which could adversely affect our future growth” in the Annual Report.
We strive to focus our efforts on increasing oil and natural gas reserves and production while controlling costs at a level that is appropriate for long-term operations. Our ability to find and develop sufficient quantities of oil and natural gas reserves at economical costs is critical to our long-term success. Future finding and development costs are subject to changes in the costs of acquiring, drilling and completing our prospects.
Item 3. Quantitative and Qualitative Disclosures About Market Risk
Except as set forth below, there have been no material changes to the sources and effects of our market risk since December 31, 2023, which are disclosed in Part II, Item 7A of the Annual Report and incorporated herein by reference.
Commodity price exposure. We are exposed to market risk as the prices of oil, natural gas and NGLs fluctuate as a result of changes in supply and demand and other factors. To partially reduce price risk caused by these market fluctuations, we have entered into derivative financial instruments in the past and expect to enter into derivative financial instruments in the future to cover a significant portion of our anticipated future production.
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We typically use costless (or zero-cost) collars, three-way collars and/or swap contracts to manage risks related to changes in oil, natural gas and NGL prices. Costless collars provide us with downside price protection through the purchase of a put option that is financed through the sale of a call option. Because the call option proceeds are used to offset the cost of the put option, these arrangements are initially “costless” to us. Three-way costless collars also provide us with downside price protection through the purchase of a put option, but they also allow us to participate in price upside through the purchase of a call option. The purchase of both the put option and call option are financed through the sale of a call option. Because the proceeds from the call option sale are used to offset the cost of the purchased put and call options, these arrangements are also initially “costless” to us. In the case of a costless collar, the put option or options and the call option or options have different fixed price components. When the settlement price is below the price floor established by the collar, we receive from our counterparty an amount equal to the difference between the settlement price and the price floor multiplied by the contract oil, natural gas or NGL volume. When the settlement price is above the price ceiling established by the costless collar, we pay our counterparty an amount equal to the difference between the settlement price and the price ceiling multiplied by the contract oil, natural gas or NGL volume. In a swap contract, a floating price is exchanged for a fixed price over a specified period, providing downside price protection.
We record all derivative financial instruments at fair value. The fair value of our derivative financial instruments is determined using purchase and sale information available for similarly traded securities. At September 30, 2024, Bank of America, PNC Bank, Truist Bank, The Bank of Nova Scotia, Royal Bank of Canada, Comerica Bank and BOKF (or affiliates thereof) were the counterparties for our derivative instruments. We have considered the credit standing of the counterparty in determining the fair value of our derivative financial instruments.
At September 30, 2024, we had various costless collar contracts open and in place to mitigate our exposure to oil price volatility, each with an established price floor and ceiling. At September 30, 2024, we had natural gas basis differential swap contracts open and in place to mitigate our exposure to natural gas price volatility, with a specific term (calculation period), notional quantity (volume hedged) and fixed price.
See Note 8 to the interim unaudited condensed consolidated financial statements in this Quarterly Report for a summary of our open derivative financial instruments. Such information is incorporated herein by reference.
Item 4. Controls and Procedures
Evaluation of Disclosure Controls and Procedures
As of the end of the period covered by this Quarterly Report, we evaluated the effectiveness of the design and operation of the Company’s disclosure controls and procedures (as defined in Rule 13a-15(e) under the Exchange Act) under the supervision and with the participation of our management, including our Chief Executive Officer and our Chief Financial Officer. Based on that evaluation, our Chief Executive Officer and our Chief Financial Officer concluded that the Company’s disclosure controls and procedures were effective as of September 30, 2024 to ensure that (i) information required to be disclosed in the reports it files and submits under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms and (ii) information required to be disclosed under the Exchange Act is accumulated and communicated to the Company’s management, including our Chief Executive Officer and our Chief Financial Officer, as appropriate to allow timely decisions regarding required disclosure.
Changes in Internal Control over Financial Reporting
During the three months ended September 30, 2024, there were no changes in our internal controls that have materially affected or are reasonably likely to have a material effect on our internal control over financial reporting.


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Part II — OTHER INFORMATION
Item 1. Legal Proceedings
We are party to several legal proceedings encountered in the ordinary course of business. While the ultimate outcome and impact on us cannot be predicted with certainty, in the opinion of management, it is remote that these legal proceedings will have a material adverse impact on our financial condition, results of operations or cash flows.
During the three months ended September 30, 2024, there were no material changes regarding the legal proceedings we have disclosed in “Item 3. Legal Proceedings” in the Annual Report.
Item 1A. Risk Factors
We are subject to various risks and uncertainties in the course of our business. For a discussion of such risks and uncertainties, please see “Item 1A. Risk Factors” in the Annual Report.
Item 2. Repurchase of Equity by the Company or Affiliates
During the quarter ended September 30, 2024, the Company re-acquired shares of common stock from certain employees in order to satisfy the employees’ tax liability in connection with the vesting of restricted stock.
Period
Total Number of Shares Purchased(1)
Average Price Paid Per ShareTotal Number of Shares Purchased as Part of Publicly Announced Plans or ProgramsMaximum Number of Shares that May Yet Be Purchased under the Plans or Programs
July 1, 2024 to July 31, 2024— $— — — 
August 1, 2024 to August 31, 2024297 $55.48 — — 
September 1, 2024 to September 30, 2024334 $55.62 — — 
Total631 $55.55 — — 
_________________
(1)The shares were not re-acquired pursuant to any repurchase plan or program. The Company re-acquired shares of common stock from certain employees in order to satisfy the employees’ tax liability in connection with the vesting of restricted stock.
Item 5. Other Information
Insider Trading Plans
During the three months ended September 30, 2024, no director or officer (as defined in Rule 16a-1(f) under the Exchange Act) of the Company adopted, modified or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408(a) of Regulation S-K.

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Item 6. Exhibits
Exhibit
Number		Description
2.1*
2.2*
2.3*
3.1
3.2
3.3
3.4
4.1
4.2
4.3
10.1
31.1
31.2
32.1
32.2
   101
The following financial information from Matador Resources Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2024, formatted in Inline XBRL (Inline eXtensible Business Reporting Language): (i) the Condensed Consolidated Balance Sheets - Unaudited, (ii) the Condensed Consolidated Statements of Income - Unaudited, (iii) the Condensed Consolidated Statements of Changes in Shareholders’ Equity - Unaudited, (iv) the Condensed Consolidated Statements of Cash Flows - Unaudited and (v) the Notes to Condensed Consolidated Financial Statements - Unaudited (submitted electronically herewith).
   104Cover Page Interactive Data File, formatted in Inline XBRL (included as Exhibit 101).
*This filing excludes certain schedules and exhibits pursuant to Item 601(a)(5) of Regulation S-K, which the registrant agrees to furnish supplementally to the Securities and Exchange Commission upon request by the Commission; provided, however, that the registrant may request confidential treatment pursuant to Rule 24b-2 of the Securities Exchange Act of 1934, as amended, for any schedules or exhibits so furnished.
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SIGNATURES
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
 
MATADOR RESOURCES COMPANY
Date: October 25, 2024By:/s/ Joseph Wm. Foran
Joseph Wm. Foran
Chairman and Chief Executive Officer
Date: October 25, 2024By:/s/ Brian J. Willey
Brian J. Willey
Executive Vice President and Chief Financial Officer

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