Matador Resources Co 10-Q for FY2026 Q3
Matador Resources Co (MTDR)
10-Q
2026-11-06
For: 2026-09-30
View Original
Added on
November 06, 2026
About this 10-Q
Matador Resources Co filed this 10-Q on November 6, 2026, covering the quarter ended September 30, 2026 (FY2026 Q3).
Third-quarter production rose 10% to 21.2 million BOE, and Adjusted EBITDA increased to $738.3 million from $566.5 million. Matador Resources Company reported net income attributable to shareholders of $172.1 million, down from $176.4 million, as derivative losses offset higher revenue. AI summary
Headline figures
Quarter ended September 30, 2026, as reported in this filing, compared with the same period a year earlier where the filing states it.
- Revenue
- $1.16B
- up 23.8% from $939.02M a year earlier
- Net income
- $172.12M
- down 2.4% from net income of $176.36M a year earlier
- Diluted EPS
- $1.39
- down 2.1% from $1.42 a year earlier
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
________________________________________________________
FORM 10-Q
_________________________________________________________
| QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |||||
For the quarterly period ended September 30, 2026
OR
| TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 | |||||
For the transition period from to
Commission File Number 001-35410
_________________________________________________________
(Exact name of registrant as specified in its charter)
_________________________________________________________
| (State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.) | ||||
| (Address of principal executive offices) | (Zip Code) | ||||
(972 ) 371-5200
(Registrant’s telephone number, including area code)
_________________________________________________________
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading symbol(s) | Name of each exchange on which registered | ||||||||||||
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. ☒ Yes ☐ No
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). ☒ Yes ☐ No
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
| ☒ | Accelerated filer | ☐ | ||||||||||||||||||
| Non-accelerated filer | ☐ | Smaller reporting company | ||||||||||||||||||
| Emerging growth company | ||||||||||||||||||||
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). ☐ Yes ☒ No
As of November 3, 2026, there were 123,747,774 shares of the registrant’s common stock, par value $0.01 per share, outstanding.
MATADOR RESOURCES COMPANY
FORM 10-Q
FOR THE QUARTER ENDED SEPTEMBER 30, 2026
TABLE OF CONTENTS
| Page | |||||
Part I — FINANCIAL INFORMATION
Item 1. Financial Statements — Unaudited
Matador Resources Company and Subsidiaries
CONDENSED CONSOLIDATED BALANCE SHEETS — UNAUDITED
(In thousands, except par value and share data)
| September 30, 2026 | December 31, 2025 | ||||||||||
| ASSETS | |||||||||||
| Current assets | |||||||||||
| Cash | $ | $ | |||||||||
| Restricted cash | |||||||||||
| Accounts receivable | |||||||||||
| Oil and natural gas revenues | |||||||||||
| Joint interest billings | |||||||||||
| Other | |||||||||||
| Derivative instruments | |||||||||||
| Lease and well equipment inventory | |||||||||||
| Prepaid expenses and other current assets | |||||||||||
| Total current assets | |||||||||||
| Property and equipment, at cost | |||||||||||
| Oil and natural gas properties, full-cost method | |||||||||||
| Evaluated | |||||||||||
| Unproved and unevaluated | |||||||||||
| Midstream properties | |||||||||||
| Other property and equipment | |||||||||||
| Less accumulated depletion, depreciation and amortization | ( | ( | |||||||||
| Net property and equipment | |||||||||||
| Other assets | |||||||||||
| Intangible assets, net | |||||||||||
| Goodwill | |||||||||||
| Other long-term assets | |||||||||||
| Total other assets | |||||||||||
| Total assets | $ | $ | |||||||||
| LIABILITIES AND SHAREHOLDERS’ EQUITY | |||||||||||
| Current liabilities | |||||||||||
| Accounts payable and accrued liabilities | $ | $ | |||||||||
| Current term loan payable under San Mateo Credit Facility | |||||||||||
| Royalties payable | |||||||||||
| Derivative instruments | |||||||||||
| Advances from joint interest owners | |||||||||||
| Other current liabilities | |||||||||||
| Total current liabilities | |||||||||||
| Long-term liabilities | |||||||||||
| Borrowings under Credit Agreement | |||||||||||
| Borrowings under San Mateo Revolving Credit Facility | |||||||||||
| Senior unsecured notes payable | |||||||||||
| Asset retirement obligations | |||||||||||
| Derivative instruments | |||||||||||
| Deferred income taxes | |||||||||||
| Other long-term liabilities | |||||||||||
| Total long-term liabilities | |||||||||||
| Commitments and contingencies (see Note 11) | |||||||||||
| Shareholders’ equity | |||||||||||
Common stock - $ and | |||||||||||
| Additional paid-in capital | |||||||||||
| Retained earnings | |||||||||||
Treasury stock, at cost, | ( | ( | |||||||||
| Total Matador Resources Company shareholders’ equity | |||||||||||
| Non-controlling interest in subsidiaries | |||||||||||
| Total shareholders’ equity | |||||||||||
| Total liabilities and shareholders’ equity | $ | $ | |||||||||
The accompanying notes are an integral part of these financial statements.
3
Matador Resources Company and Subsidiaries
CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS — UNAUDITED
(In thousands, except per share data)
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Revenues | |||||||||||||||||||||||
| Oil and natural gas revenues | $ | $ | $ | $ | |||||||||||||||||||
| Third-party midstream services revenues | |||||||||||||||||||||||
| Sales of purchased natural gas | |||||||||||||||||||||||
| Realized (loss) gain on derivatives | ( | ( | |||||||||||||||||||||
| Unrealized (loss) gain on derivatives | ( | ( | ( | ||||||||||||||||||||
| Total revenues | |||||||||||||||||||||||
| Expenses | |||||||||||||||||||||||
| Lease operating | |||||||||||||||||||||||
| Transportation and processing | |||||||||||||||||||||||
| Midstream operating | |||||||||||||||||||||||
| Purchased natural gas | |||||||||||||||||||||||
| Depletion, depreciation and amortization | |||||||||||||||||||||||
| Taxes other than income | |||||||||||||||||||||||
| Accretion of asset retirement obligations | |||||||||||||||||||||||
| General and administrative | |||||||||||||||||||||||
| Total expenses | |||||||||||||||||||||||
| Operating income | |||||||||||||||||||||||
| Other income (expense) | |||||||||||||||||||||||
| Interest expense | ( | ( | ( | ( | |||||||||||||||||||
| Loss on debt extinguishment | ( | ||||||||||||||||||||||
| Loss on asset sales | ( | ( | ( | ||||||||||||||||||||
| Other income | |||||||||||||||||||||||
| Total other expense | ( | ( | ( | ( | |||||||||||||||||||
| Income before income taxes | |||||||||||||||||||||||
| Income tax provision (benefit) | |||||||||||||||||||||||
| Current | ( | ||||||||||||||||||||||
| Deferred | |||||||||||||||||||||||
| Total income tax provision | |||||||||||||||||||||||
| Net income | |||||||||||||||||||||||
| Net income attributable to non-controlling interest in subsidiaries | ( | ( | ( | ( | |||||||||||||||||||
| Net income attributable to Matador Resources Company shareholders | $ | $ | $ | $ | |||||||||||||||||||
| Earnings per common share | |||||||||||||||||||||||
| Basic | $ | $ | $ | $ | |||||||||||||||||||
| Diluted | $ | $ | $ | $ | |||||||||||||||||||
| Weighted average common shares outstanding | |||||||||||||||||||||||
| Basic | |||||||||||||||||||||||
| Diluted | |||||||||||||||||||||||
The accompanying notes are an integral part of these financial statements.
4
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, 2026
| Total shareholders’ equity attributable to Matador Resources Company | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Non-controlling interest in subsidiaries | Total shareholders’ equity | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Common Stock | Additional paid-in capital | Retained earnings | Treasury Stock | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Shares | Amount | Shares | Amount | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Balance at January 1, 2026 | $ | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Dividends declared ($ | — | — | — | ( | — | — | ( | — | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Issuance of stock pursuant to incentive and purchase plans, net of shares withheld for taxes | ( | — | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense related to equity-based awards including amounts capitalized | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Contribution related to formation of San Mateo, net of tax of $ | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries | — | — | — | — | — | — | — | ( | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Repurchases of common stock | — | — | — | — | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Current period net (loss) income | — | — | — | ( | — | — | ( | ( | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Balance at March 31, 2026 | $ | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Dividends declared ($ | — | — | — | ( | — | — | ( | — | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Issuance of stock pursuant to incentive and purchase plans, net of shares withheld for taxes | — | ( | ( | — | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense related to equity-based awards including amounts capitalized | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Contribution related to formation of San Mateo, net of tax of $ | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries | — | — | — | — | — | — | — | ( | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Repurchases of common stock | — | — | — | — | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Current period net income | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Balance at June 30, 2026 | $ | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
The accompanying notes are an integral part of these financial statements.
5
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, 2026
| Total shareholders’ equity attributable to Matador Resources Company | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Non-controlling interest in subsidiaries | Total shareholders’ equity | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Common Stock | Additional paid-in capital | Retained earnings | Treasury Stock | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Shares | Amount | Shares | Amount | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Balance at July 1, 2026 | $ | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Dividends declared ($ | — | — | — | ( | — | — | ( | — | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Issuance of stock pursuant to incentive and purchase plans, net of shares withheld for taxes | — | — | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense related to equity-based awards including amounts capitalized | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Contribution related to formation of San Mateo, net of tax of $ | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Contributions from non-controlling interest owners of less-than-wholly-owned subsidiaries | — | — | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries | — | — | — | — | — | — | — | ( | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Repurchases of common stock | — | — | — | — | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Current period net income | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Balance at September 30, 2026 | $ | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
The accompanying notes are an integral part of these financial statements.
6
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, 2025
| Total shareholders’ equity attributable to Matador Resources Company | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Non-controlling interest in subsidiaries | Total shareholders’ equity | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Common Stock | Additional paid-in capital | Retained earnings | Treasury Stock | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Shares | Amount | Shares | Amount | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Balance at January 1, 2025 | $ | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Dividends declared ($ | — | — | — | ( | — | — | ( | — | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Issuance of stock pursuant to incentive and purchase plans, net of shares withheld for taxes | ( | — | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense related to equity-based awards including amounts capitalized | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Contribution related to formation of San Mateo, net of tax of $ | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries | — | — | — | — | — | — | — | ( | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Current period net income | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Balance at March 31, 2025 | $ | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Dividends declared ($ | — | — | — | ( | — | — | ( | — | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Issuance of stock pursuant to incentive and purchase plans, net of shares withheld for taxes | — | ( | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense related to equity-based awards including amounts capitalized | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Contribution related to formation of San Mateo, net of tax of $ | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries | — | — | — | — | — | — | — | ( | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Repurchases of common stock | — | — | — | — | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Current period net income | — | — | — | — | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Balance at June 30, 2025 | $ | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
The accompanying notes are an integral part of these financial statements.
7
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, 2025
| Total shareholders’ equity attributable to Matador Resources Company | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Non-controlling interest in subsidiaries | Total shareholders’ equity | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Common Stock | Additional paid-in capital | Retained earnings | Treasury Stock | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Shares | Amount | Shares | Amount | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Balance at July 1, 2025 | $ | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
Dividends declared ($ | — | — | — | ( | — | — | ( | — | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Issuance of stock pursuant to incentive and purchase plans, net of shares withheld for taxes | ( | — | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Stock-based compensation expense related to equity-based awards including amounts capitalized | — | — | — | — | — | — | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries | — | — | — | — | — | — | — | ( | ( | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Repurchase of common stock | — | — | — | — | ( | ( | — | ( | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Current period net income | — | — | — | ||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||||
| Balance at September 30, 2025 | $ | $ | $ | $ | ( | $ | $ | $ | |||||||||||||||||||||||||||||||||||||||||||||||||||||||||
The accompanying notes are an integral part of these financial statements.
8
Matador Resources Company and Subsidiaries
CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS — UNAUDITED
(In thousands)
| Nine Months Ended September 30, | |||||||||||||||||||||||
| 2026 | 2025 | ||||||||||||||||||||||
| Operating activities | |||||||||||||||||||||||
| Net income | $ | ||||||||||||||||||||||
| Adjustments to reconcile net income to net cash provided by operating activities | |||||||||||||||||||||||
| Unrealized loss on derivatives | |||||||||||||||||||||||
| Depletion, depreciation and amortization | |||||||||||||||||||||||
| Accretion of asset retirement obligations | |||||||||||||||||||||||
| Stock-based compensation expense | |||||||||||||||||||||||
| Loss on extinguishment of debt | |||||||||||||||||||||||
| Deferred income tax provision | |||||||||||||||||||||||
| Amortization of debt issuance costs and other debt-related costs | |||||||||||||||||||||||
| Other non-cash changes | |||||||||||||||||||||||
| Changes in operating assets and liabilities | |||||||||||||||||||||||
| Accounts receivable, prepaid expenses and other current assets | ( | ||||||||||||||||||||||
| Lease and well equipment inventory | ( | ( | |||||||||||||||||||||
| Other long-term assets | ( | ||||||||||||||||||||||
| Accounts payable, accrued liabilities and other current liabilities | |||||||||||||||||||||||
| Royalties payable | |||||||||||||||||||||||
| Advances from joint interest owners | |||||||||||||||||||||||
| Other long-term liabilities | ( | ||||||||||||||||||||||
| Net cash provided by operating activities | |||||||||||||||||||||||
| Investing activities | |||||||||||||||||||||||
| Drilling, completion and equipping capital expenditures | ( | ( | |||||||||||||||||||||
| Acquisition of oil and natural gas properties | ( | ( | |||||||||||||||||||||
| Acquisition of Paloma | ( | ||||||||||||||||||||||
| Acquisition of Cardinal | ( | ||||||||||||||||||||||
| Midstream capital expenditures | ( | ( | |||||||||||||||||||||
| Acquisition of midstream assets | ( | ||||||||||||||||||||||
| Expenditures for other property and equipment | ( | ( | |||||||||||||||||||||
| Proceeds from sale of assets | |||||||||||||||||||||||
| Proceeds from sale of equity method investment | |||||||||||||||||||||||
| Net cash used in investing activities | ( | ( | |||||||||||||||||||||
| Financing activities | |||||||||||||||||||||||
| Repayments of borrowings under Credit Agreement | ( | ( | |||||||||||||||||||||
| Borrowings under Credit Agreement | |||||||||||||||||||||||
| Repayments of borrowings under San Mateo Revolving Credit Facility | ( | ( | |||||||||||||||||||||
| Borrowings under San Mateo Revolving Credit Facility | |||||||||||||||||||||||
| Proceeds from San Mateo Term Loan under San Mateo Credit Facility | |||||||||||||||||||||||
| Cost to issue San Mateo Term Loan | ( | ||||||||||||||||||||||
| Cost to amend credit facilities | ( | ( | |||||||||||||||||||||
| Proceeds from issuance of senior unsecured notes | |||||||||||||||||||||||
| Cost to issue senior unsecured notes | ( | ||||||||||||||||||||||
| Purchase of senior unsecured notes | ( | ||||||||||||||||||||||
| Proceeds from sale-leaseback financing obligation | |||||||||||||||||||||||
| Payments on sale-leaseback financing obligation | ( | ||||||||||||||||||||||
| Repurchases of common stock | ( | ( | |||||||||||||||||||||
| Dividends paid | ( | ( | |||||||||||||||||||||
| Contributions related to formation of San Mateo | |||||||||||||||||||||||
| Contributions from non-controlling interest owners of less-than-wholly-owned subsidiaries | |||||||||||||||||||||||
| Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries | ( | ( | |||||||||||||||||||||
| Taxes paid related to net share settlement of stock-based compensation | ( | ( | |||||||||||||||||||||
| Other | ( | ( | |||||||||||||||||||||
| Net cash provided by (used in) financing activities | ( | ||||||||||||||||||||||
| Change in cash and restricted cash | ( | ||||||||||||||||||||||
| Cash and restricted cash at beginning of period | |||||||||||||||||||||||
| Cash and restricted cash at end of period | $ | $ | |||||||||||||||||||||
The accompanying notes are an integral part of these financial statements.
9
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED
NOTE 1 — NATURE OF OPERATIONS
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, 2025 filed with the SEC on February 26, 2026 (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 810, Consolidation. The Company proportionately consolidates certain joint ventures that are less-than-wholly-owned and are involved in oil and natural gas exploration. All intercompany accounts and transactions have been eliminated in consolidation.
Certain reclassifications to captions within the interim unaudited condensed consolidated balance sheets, statements of operations and statements of changes in shareholders’ equity have been made to the prior period’s financial statements to conform to the current period presentation. These reclassifications had no effect on previously reported results of operations, cash flows or retained earnings. 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, 2026. Amounts as of December 31, 2025 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 in the purchase price allocations and 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.
10
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, 2026 and 2025 (in thousands).
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Revenues from contracts with customers | $ | $ | $ | $ | |||||||||||||||||||
| Realized (loss) gain on derivatives | ( | ( | |||||||||||||||||||||
| Unrealized (loss) gain on derivatives | ( | ( | ( | ||||||||||||||||||||
| Total revenues | $ | $ | $ | $ | |||||||||||||||||||
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Oil revenues | $ | $ | $ | $ | |||||||||||||||||||
| Natural gas revenues | |||||||||||||||||||||||
| Third-party midstream services revenues | |||||||||||||||||||||||
| Sales of purchased natural gas | |||||||||||||||||||||||
| Total revenues from contracts with customers | $ | $ | $ | $ | |||||||||||||||||||
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, 2026 and 2025, the cost center ceiling was higher than the capitalized costs of oil and natural gas properties, and, as a result, no
The Company capitalized approximately $18.7 million and $19.5 million of its general and administrative costs for the three months ended September 30, 2026 and 2025, respectively, and $59.0 million and $55.2 million of its general and administrative costs for the nine months ended September 30, 2026 and 2025, respectively. The Company capitalized approximately $5.3 million and $8.4 million of its interest expense for the three months ended September 30, 2026 and 2025, respectively, and $17.0 million and $23.3 million of its interest expense for the nine months ended September 30, 2026 and 2025, respectively.
Intangibles
Amortization of intangibles with definite lives is calculated using the straight-line method, which is reflective of the benefit pattern in which the estimated economic benefit is expected to be received over the estimated useful life of the intangible asset. Intangibles subject to amortization are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of the intangible may not be recoverable. If the sum of the expected undiscounted future cash flows related to the asset is less than the carrying amount of the asset, an impairment loss is recognized based on the fair value of the asset.
Goodwill
Goodwill represents the excess of the purchase price over the estimated fair value of the net assets acquired in the acquisition of a business. Goodwill is not amortized, but rather is tested for impairment at the reporting unit level annually and when events or changes in circumstances indicate that the fair value of a reporting unit with goodwill has been reduced below carrying value. If the Company determines, based on a qualitative assessment, that it is not more likely than not that a reporting unit’s fair value is less than its carrying amount, no further impairment testing is required. If the Company does not perform a qualitative assessment or if that assessment indicates that further impairment testing is required, the fair value of each reporting
11
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 2 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES — Continued
unit is determined using an income and market approach which is compared to the carrying value of the reporting unit. If the carrying amount of the reporting unit exceeds its fair value, an impairment loss would be recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit.
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.
The following table sets forth the computation of diluted weighted average common shares outstanding for the three and nine months ended September 30, 2026 and 2025 (in thousands).
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | ||||||||||||||||||||
| Weighted average common shares outstanding | |||||||||||||||||||||||
| Basic | |||||||||||||||||||||||
| Dilutive effect of options and restricted stock units | |||||||||||||||||||||||
| Diluted weighted average common shares outstanding | |||||||||||||||||||||||
NOTE 3 — ACQUISITIONS
Cardinal Acquisition
On July 31, 2026, a wholly-owned subsidiary of San Mateo completed the acquisition of the operating subsidiaries of Cardinal Midstream Partners, LLC (“Cardinal”), a portfolio company of EnCap Flatrock Midstream, for total cash consideration of $761.0 million, subject to certain customary post-closing purchase price adjustments (the “Cardinal Acquisition”). The Cardinal Acquisition provides San Mateo with increased processing capacity, future expansion opportunities, new natural gas customers and enhanced flow assurance for producers, including Matador, in the northern Delaware Basin. The results of operations of the acquired business and the assets acquired and liabilities assumed in the Cardinal Acquisition are included in the Company’s midstream segment.
The purchase price for the Cardinal Acquisition was funded through a combination of (i) borrowings under a new $650.0 million incremental senior secured term loan due July 30, 2027 under the San Mateo Credit Facility (as defined below) (the “San Mateo Term Loan”), (ii) capital contributions by Matador and a subsidiary of Five Point Infrastructure LLC (“Five Point”), the Company’s joint venture partner in San Mateo, to San Mateo of $51.0 million and $49.0 million, respectively, and (iii) cash on hand.
The Cardinal Acquisition was accounted for under the acquisition method of accounting as a business combination in accordance with Accounting Standards Codification 805, Business Combinations (“ASC 805”). Under ASC 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 San Mateo acquired 100% of the membership interests of Cardinal, the acquisition was treated as an asset acquisition for tax purposes.
12
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 3 — ACQUISITIONS — Continued
The preliminary allocation of the total purchase price for the Cardinal Acquisition is set forth below (in thousands). As of the date of this filing, the valuation of property, plant and equipment and intangible assets, as well as certain working capital adjustments in connection with the final settlement, remain ongoing and adjustments may be made. The Company expects to complete the final purchase price allocation during the 12-month period subsequent to the Cardinal Acquisition closing date.
| Cash consideration | $ | |||||||||||||
| Allocation of purchase price | ||||||||||||||
| Current assets | ||||||||||||||
| Property, plant and equipment | ||||||||||||||
| Intangible assets | ||||||||||||||
| Goodwill | ||||||||||||||
Other long-term assets(1) | ||||||||||||||
Current liabilities(1) | ( | |||||||||||||
| Asset retirement obligations | ( | |||||||||||||
Other long-term liabilities(1) | $ | ( | ||||||||||||
| Net assets acquired | $ | |||||||||||||
_____________________
(1)Other long-term assets and other long-term liabilities represent lease balances, and current liabilities includes current lease liabilities of $4.7 million.
The historical carrying values of the current assets acquired and the current liabilities assumed approximated their fair values due to their short-term maturities. The fair value measurements of the intangible assets acquired and asset retirement obligations were based on inputs that are not observable in the market and therefore represent Level 3 inputs. The fair values of property, plant and equipment were measured using the replacement cost new and the reproduction cost new methods under the cost approach of valuation. Significant inputs to the valuation of property, plant and equipment include estimates of: (i) replacement or reproduction cost, (ii) adjustments for physical deterioration and (iii) remaining useful lives of the assets. Asset retirement obligations were measured using the discounted cash flow method under the cost approach of valuation.
The fair value of the intangible assets was measured using the multi-period excess earnings method under the income approach of valuation, which considers the incremental cash flows attributable only to the subject intangible asset after deducting contributory asset charges. Significant inputs to the valuation of intangible assets include estimates of: (i) future throughput volumes, (ii) future margins, (iii) cash flows attributable to returns on contributory assets, (iv) the weighted average cost of capital and (v) the economic lives of the customer relationships. These inputs require significant judgments and estimates and are the most sensitive and subject to change.
Goodwill represents the excess of the purchase price of an acquired business over the fair value of net assets acquired. The goodwill recognized in connection with the Cardinal Acquisition reflects the value to San Mateo of flowing additional volumes through the system, including those of Matador. The goodwill is deductible over 15 years for tax purposes, which creates associated deferred tax balances post closing.
The results of operations for the Cardinal Acquisition since the closing date have been included in the Company’s unaudited condensed consolidated financial statements for the three and nine months ended September 30, 2026. Additionally, the Company incurred $3.1 million and $4.1 million in acquisition-related costs for the Cardinal Acquisition during the three and nine months ended September 30, 2026, respectively, which were included in general and administrative expenses in the unaudited condensed consolidated statements of operations.
The pro forma impacts of this business combination to revenues and net income for the three and nine months ended September 30, 2026 and 2025 were not material to the Company’s revenues and net income as reported.
Bureau of Land Management Oil and Gas Lease Acquisition
In May 2026, the Company completed the acquisition of 5,154 net undeveloped acres in the core of the Delaware Basin in Southeast New Mexico for approximately $1.16 billion as part of the Bureau of Land Management Oil and Gas Lease Sale (the “BLM Acquisition”). The acquired acreage complements the Company’s existing acreage position, and as a result, includes proved undeveloped reserves in addition to unproved and unevaluated reserves.
13
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 3 — ACQUISITIONS — Continued
The BLM Acquisition was accounted for as an asset acquisition. The purchase price is allocated to the underlying assets acquired based upon their relative fair values as of the acquisition date as set forth below (in thousands).
| Unproved and unevaluated | $ | ||||
| Evaluated | |||||
| Total oil and natural gas properties acquired | $ | ||||
The fair value measurements of the assets acquired were 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 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) the weighted average cost of capital. These inputs require significant judgments and estimates and are the most sensitive and subject to change.
NOTE 4 — INTANGIBLE ASSETS
The following table summarizes the Company’s intangible assets at September 30, 2026 and December 31, 2025 (in thousands), all of which is derived from the Cardinal Acquisition and attributable to the midstream segment and has been assigned a 20-year economic life. The intangible assets are deductible over 15 years for tax purposes, which creates associated deferred tax balances post closing.
| September 30, 2026 | December 31, 2025 | ||||||||||||||||||||||||||||||||||
| Gross Carrying Amount | Accumulated Amortization | Net | Gross Carrying Amount | Accumulated Amortization | Net | ||||||||||||||||||||||||||||||
| Customer relationships | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
| Total | $ | $ | $ | $ | $ | $ | |||||||||||||||||||||||||||||
The following table presents estimated amortization expense through 2030 (in thousands):
| Remainder of 2026 | $ | |||||||
| 2027 | $ | |||||||
| 2028 | $ | |||||||
| 2029 | $ | |||||||
| 2030 | $ | |||||||
NOTE 5 — ASSET RETIREMENT OBLIGATIONS
The following table summarizes the changes in the Company’s asset retirement obligations for the nine months ended September 30, 2026 (in thousands).
| Beginning asset retirement obligations | $ | ||||
| Revisions in estimated cash flows | |||||
| Liabilities incurred during period | |||||
| Liabilities settled during period | ( | ||||
| Acquisitions during period | |||||
| Accretion expense | |||||
| Ending asset retirement obligations | |||||
Less: current asset retirement obligations(1) | ( | ||||
| Long-term asset retirement obligations | $ | ||||
_______________
(1)Included in accounts payable and accrued liabilities in the Company’s interim unaudited condensed consolidated balance sheet at September 30, 2026.
14
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 6— DEBT
The components of debt, including the effects of issuance costs and discounts, net as of September 30, 2026 and December 31, 2025, are set forth below (in thousands).
| September 30, 2026 | December 31, 2025 | ||||||||||
| San Mateo Term Loan due 2027 | $ | $ | |||||||||
| Issuance costs | ( | ||||||||||
| Total short-term debt | $ | $ | |||||||||
| Revolving credit agreements: | |||||||||||
| Credit Agreement due 2029 | $ | $ | |||||||||
| San Mateo Revolving Credit Facility due 2029 | |||||||||||
| Senior unsecured notes: | |||||||||||
| Issuance costs and discounts, net | ( | ( | |||||||||
| Total senior unsecured notes payable | |||||||||||
| Total long-term debt | $ | $ | |||||||||
| Total debt | $ | $ | |||||||||
Credit Agreements
MRC Energy Company
At September 30, 2026, the Company had $951.0 million in borrowings outstanding under the Company’s secured revolving credit facility (the “Credit Agreement”) and approximately $53.1 million in outstanding letters of credit issued pursuant to the Credit Agreement.
The outstanding borrowings under the Credit Agreement mature on March 22, 2029. The borrowing base under the Credit Agreement is determined semi-annually as of May 1 and November 1 by the lenders based primarily on the estimated value of the Company’s proved oil and natural gas reserves at December 31 and June 30 of each year, respectively. The Company and the lenders may each request an unscheduled redetermination of the borrowing base once between scheduled redetermination dates.
In June 2026, in connection with the regularly scheduled May 1 redetermination, the borrowing base of the Credit Agreement was reaffirmed at $3.25 billion. Additionally, the Company elected to, and the lenders agreed to, increase the borrowing commitments from $2.25 billion to $2.75 billion.
Between September 30, 2026 and November 3, 2026, net borrowings under the Credit Agreement increased $1.30 billion primarily in connection with the Paloma Acquisition (see Note 14, Subsequent Events). Of this increase in net borrowings, $150 million was repaid following the closing of the Paloma Acquisition. At November 3, 2026, the Company had $2.25 billion in borrowings outstanding under the Credit Agreement.
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 of debt, 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 up to the greater of $150.0 million or 10 % of the elected borrowing commitments of unrestricted cash and cash equivalents), divided by a rolling four quarter EBITDA calculation, of 3.5 or less at the end of each fiscal quarter. The Company was in compliance with the terms of the Credit Agreement at September 30, 2026.
15
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 6 — DEBT — Continued
San Mateo Midstream, LLC
In July 2026, in connection with the Cardinal Acquisition, San Mateo amended the San Mateo Credit Facility to include the $650.0 million San Mateo Term Loan.
At September 30, 2026, San Mateo had $1.00 billion in borrowings outstanding under its secured revolving credit facility (the “San Mateo Revolving Credit Facility” and, together with the San Mateo Term Loan, the “San Mateo Credit Facility”) and approximately $22.9 million in outstanding letters of credit issued pursuant to the San Mateo Revolving Credit Facility.
Total deferred financing costs for the San Mateo Term Loan were $2.7 million at September 30, 2026, which are being amortized to interest expense over the term of the loan. The Company recognizes these costs as a deduction to the principal balance in the interim unaudited condensed consolidated balance sheet. San Mateo’s effective interest rate under the San Mateo Term Loan was 6.91 % at September 30, 2026.
As of September 30, 2026, the San Mateo Term Loan is due within twelve months and has therefore been presented as a current liability in the Company’s interim unaudited condensed consolidated balance sheet. San Mateo’s management presently believes measures being taken to refinance the San Mateo Term Loan will enable San Mateo to successfully refinance the balance on a long-term basis prior to its maturity, although no assurance can be given. In the absence of being able to refinance the San Mateo Term Loan on a long-term basis, San Mateo believes it could satisfy the obligation through a combination of cash on hand, cash flows from operations, borrowings under the San Mateo Revolving Credit Facility and contributions from its members.
The San Mateo Credit Facility is non-recourse with respect to Matador and its other 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 Revolving Credit Facility mature on November 26, 2029, and the San Mateo Term Loan matures on July 30, 2027. The floating interest rate margins under the San Mateo Revolving Credit Facility and the San Mateo Term Loan are the same, except there is a 0.50 % fee payable on the principal amount of the San Mateo Term Loan if it is still outstanding on the six-month anniversary date of its funding. The San Mateo Term Loan includes a mandatory prepayment requirement with the proceeds of certain equity issuances, debt issuances and asset sales, in each case relating to San Mateo and its subsidiaries.
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 debt to EBITDA ratio is greater than 4.50 or San Mateo’s liquidity is less than 10 % of the lender commitments under the San Mateo Credit Facility. San Mateo was in compliance with the terms of the San Mateo Credit Facility at September 30, 2026.
Senior Unsecured Notes
2028 Notes Tender Offer and Redemption
In March 2026, the Company completed the repurchase of an aggregate principal amount of $419.8 million of the $500.0 million of the 2028 Notes pursuant to the Company’s cash tender offer announced on February 26, 2026 (the “2028 Notes Tender Offer”). Additionally, in March 2026, the Company irrevocably deposited funds with the trustee to redeem the remaining aggregate principal amount of $80.2 million of 2028 Notes outstanding on April 15, 2026 (the “2028 Notes Redemption”), and as a result of such deposit, to satisfy and discharge the Company’s obligations under the indenture governing the 2028 Notes. In connection with the 2028 Notes Tender Offer and 2028 Notes Redemption, the Company incurred a loss on debt extinguishment of $15.6 million, including a $9.7 million cash prepayment premium and a $5.9 million write-off of remaining unamortized deferred issuance costs and discounts.
16
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 6 — DEBT — Continued
2034 Notes
On March 5, 2026, the Company completed the sale of $750.0 million in aggregate principal amount of the 2034 Notes, which have a 6.0 % coupon rate and mature on April 15, 2034. Interest is payable in arrears on each April 15 and October 15. The first interest payment date was October 15, 2026. The 2034 Notes are jointly and severally guaranteed on a senior unsecured basis by certain subsidiaries of the Company (the “Guarantors”). San Mateo is not a Restricted Subsidiary (as defined in the indenture governing the 2034 Notes (the “2034 Notes Indenture”)) or Guarantor of the 2034 Notes.
The Company used the net proceeds from the sale of the 2034 Notes of $737.1 million, after deducting initial purchasers’ discounts and estimated offering expenses, to fund the 2028 Notes Tender Offer and 2028 Notes Redemption and for general corporate purposes.
At any time prior to April 15, 2029, the Company may redeem up to 40 % in aggregate principal amount of the 2034 Notes at a redemption price of 106.0 % 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 2034 Notes remains outstanding immediately after such redemption. In addition, at any time prior to April 15, 2029, the Company may redeem all or part of the 2034 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, 2029, the Company may redeem all or a part of the 2034 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 on April 15 of the years indicated below:
| Year | Redemption Price | |||||||
| 2029 | ||||||||
| 2030 | ||||||||
| 2031 and thereafter | ||||||||
Subject to certain exceptions, the 2034 Notes Indenture contains various covenants that limit the Company’s and its Restricted Subsidiaries’ ability to take certain actions, including the following:
•incur additional indebtedness;
•sell assets;
•pay dividends or make certain investments;
•create liens that secure indebtedness;
•enter into transactions with affiliates; and
•merge or consolidate with another company.
In the case of an event of default arising from certain events of bankruptcy or insolvency with respect to Matador, any Restricted Subsidiary that is a Significant Subsidiary (as defined in the 2034 Notes Indenture) or any group of Restricted Subsidiaries that, taken together, would constitute a Significant Subsidiary, all outstanding 2034 Notes will become due and payable immediately without further action or notice. If any other event of default occurs and is continuing, the trustee or the holders of at least 25 % in principal amount of the then outstanding 2034 Notes may declare all the 2034 Notes to be due and payable immediately. Events of default include the following:
•default for 30 days in the payment when due of interest on the 2034 Notes;
•default in the payment when due of the principal of, or premium, if any, on the 2034 Notes;
•failure by the Company to comply with its obligations to offer to purchase or purchase 2034 Notes pursuant to the change of control or asset sale covenants of the 2034 Notes Indenture or to comply with the covenant relating to mergers;
•failure by the Company for 180 days after notice to comply with its reporting obligations under the 2034 Notes Indenture;
17
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 6 — DEBT — Continued
•failure by the Company for 60 days after notice to comply with any of the other agreements in the 2034 Notes Indenture;
•payment defaults and accelerations with respect to other indebtedness of the Company and its Restricted Subsidiaries in the aggregate principal amount of $100.0 million or more;
•failure by the Company or any Restricted Subsidiary to pay certain final judgments aggregating in excess of $100.0 million within 60 days;
•any subsidiary guarantee by a Guarantor ceases to be in full force and effect, is declared null and void in a judicial proceeding or is denied or disaffirmed by its maker; and
•certain events of bankruptcy or insolvency with respect to the Company or any Restricted Subsidiary that is a Significant Subsidiary or any group of Restricted Subsidiaries that, taken together, would constitute a Significant Subsidiary.
NOTE 7 — INCOME TAXES
The current income tax provision and the deferred income tax provision for the three months ended September 30, 2026 and 2025 were as follows (in thousands).
| Three Months Ended September 30, | |||||||||||||||||||||||||||||||||||
| 2026 | 2025 | $ Change | % Change | ||||||||||||||||||||||||||||||||
| Income tax provision (benefit) | |||||||||||||||||||||||||||||||||||
| Current | $ | $ | ( | $ | ( | % | |||||||||||||||||||||||||||||
| Deferred | ( | ( | % | ||||||||||||||||||||||||||||||||
| Total income tax provision | $ | $ | $ | % | |||||||||||||||||||||||||||||||
The decrease in the current income tax benefit and the decrease in the deferred income tax provision for the three months ended September 30, 2026 compared to the respective period of 2025 were primarily the result of the enactment of the One Big Beautiful Bill Act of 2025 (the “OBBBA”) during the third quarter of 2025, which resulted in the recognition of the impacts of the OBBBA for the first two quarters of 2025 in the third quarter of 2025. There were no such legislation changes in the third quarter of 2026. See Note 8, Income Taxes, of the Company’s Annual Report for further details of the provisions of the OBBBA that most significantly affect its income taxes. Additionally, the increase in the total income tax provision resulted from higher income before income taxes.
The current income tax provision and the deferred income tax provision for the nine months ended September 30, 2026 and 2025 were as follows (in thousands).
| Nine Months Ended September 30, | |||||||||||||||||||||||
| 2026 | 2025 | $ Change | % Change | ||||||||||||||||||||
| Income tax provision (benefit) | |||||||||||||||||||||||
| Current | $ | $ | $ | ( | ( | % | |||||||||||||||||
| Deferred | ( | ( | % | ||||||||||||||||||||
| Total income tax provision | $ | $ | $ | ( | ( | % | |||||||||||||||||
The decreases in the current, deferred and total income tax provisions for the nine months ended September 30, 2026 compared to the respective period of 2025 were primarily the result of lower income before income taxes.
The Company’s effective income tax rates of 32 % and 26 % for the three and nine months ended September 30, 2026, respectively, differed from the U.S. federal statutory rate primarily due to state taxes in New Mexico and the impact of permanent differences between book and tax income recognized discretely in the current period.
The Company’s effective income tax rates of 25 % and 26 % for the three and nine months ended September 30, 2025, respectively, differed from the U.S. federal statutory rate primarily due to state taxes in New Mexico.
18
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS -
UNAUDITED - CONTINUED
NOTE 7 — INCOME TAXES — Continued
The Company’s cash (refunds) payments for income taxes during the three and nine months ended September 30, 2026 and 2025 are as follows (in thousands).
| Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||||||||||||
| 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||||||
| Federal | $ | $ | $ | ( | $ | |||||||||||||||||||||
| State | ||||||||||||||||||||||||||
| New Mexico | ( | |||||||||||||||||||||||||
| Other | ( | |||||||||||||||||||||||||
| Total cash (refunds) payments for income taxes | $ | $ | $ | ( | $ | |||||||||||||||||||||
NOTE 8 — EQUITY
Stock-Based Compensation
During the nine months ended September 30, 2026, the Company granted awards to certain of its employees of 392,000 service-based restricted stock units to be settled in cash, which are liability instruments, and 392,000 performance-based stock units and 14,450 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, 2028, 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 $38.2 million on their respective grant dates.
Common Stock Dividend
Matador’s Board of Directors (the “Board”) declared a quarterly cash dividend of $0.375 per share of common stock in each of the first, second and third quarters of 2026. The first quarter dividend, which totaled $46.8 million, was paid on March 10, 2026 to shareholders of record as of February 27, 2026. The second quarter dividend, which totaled $46.4 million, was paid on June 5, 2026 to shareholders of record as of May 8, 2026. The third quarter dividend, which totaled $46.2 million, was paid on September 8, 2026 to shareholders of record as of August 10, 2026. On October 21, 2026, the Board amended the Company’s dividend policy to increase the quarterly dividend to $0.4375 per share of common stock for future dividend payments and also declared a quarterly cash dividend of $0.4375 per share of common stock payable on December 4, 2026 to shareholders of record as of November 10, 2026.
Share Repurchase Program
As further described in the Annual Report, the Company maintains a share repurchase program (the “Share Repurchase Program”) authorizing the repurchase of up to $400.0 million of common stock. During the three and nine months ended September 30, 2026, the Company repurchased 253,603 and 496,305 shares of common stock, respectively, under the Share Repurchase Program at a weighted average price of $47.64 and $48.25 per common share, respectively, for a total cost of $12.1 million and $24.0 million, respectively.
San Mateo Distributions and Contributions
During the three months ended September 30, 2026 and 2025, San Mateo distributed $30.6 million and $36.2 million, respectively, to the Company and $29.4 million and $34.8 million, respectively, to Five Point. During the nine months ended September 30, 2026 and 2025, San Mateo distributed $92.3 million and $101.0 million, respectively, to the Company and $88.7 million and $97.0 million, respectively, to Five Point. During the three and nine months ended September 30, 2026, the Company contributed $51.0 million and Five Point contributed $49.0 million of cash to San Mateo in connection with the Cardinal Acquisition. During the three and nine months ended September 30, 2025, there were no
19
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 8 — EQUITY — Continued
Performance Incentives
Five Point paid the Company $2.0 million of performance incentives during the three months ended September 30, 2026. No performance incentives were paid by Five Point to the Company during the three months ended September 30, 2025. Five Point paid the Company $17.1 million and $9.2 million of performance incentives during the nine months ended September 30, 2026 and 2025, respectively. These performance incentives are recorded when received, net of the $0.4 million deferred tax impact to the Company for the three months ended September 30, 2026, and $3.5 million and $1.9 million deferred tax impact to the Company for the nine months ended September 30, 2026 and 2025, respectively, in “Additional paid-in capital” in the Company’s interim unaudited condensed consolidated balance sheets. These performance incentives received in the three and nine months ended September 30, 2026 and 2025 are also denoted as “Contributions related to formation of San Mateo” under “Financing activities” in the Company’s interim unaudited condensed consolidated statements of cash flows and changes in shareholders’ equity.
NOTE 9 — DERIVATIVE FINANCIAL INSTRUMENTS
At September 30, 2026, the Company had various costless collar and price call contracts open and in place to mitigate its exposure to oil and natural gas price volatility, each with an established price floor and ceiling. At September 30, 2026, the Company had natural gas basis differential swap contracts open and in place to mitigate its exposure to natural gas price volatility, with a specific term (calculation period), notional quantity (volume hedged) and fixed price. The Company had no open contracts associated with natural gas liquids prices at September 30, 2026.
The following is a summary of the Company’s open costless collar contracts at September 30, 2026.
| Commodity | Calculation Period | Notional Quantity (Bbl or MMBtu) | Weighted Average Price Floor ($/Bbl or $/MMBtu) | Weighted Average Price Ceiling ($/Bbl or $/MMBtu) | Fair Value of Asset (Liability) (thousands) | |||||||||||||||||||||||||||
| Oil - WTI | 10/01/2026 - 12/31/2026 | $ | $ | $ | ( | |||||||||||||||||||||||||||
| Oil - WTI | 01/01/2027 - 12/31/2027 | $ | $ | ( | ||||||||||||||||||||||||||||
| Natural Gas - Henry Hub | 10/01/2026 - 12/31/2026 | $ | $ | |||||||||||||||||||||||||||||
| Total open costless collar contracts | $ | ( | ||||||||||||||||||||||||||||||
The following is a summary of the Company’s open price call contracts at September 30, 2026.
| Commodity | Calculation Period | Notional Quantity (Bbl) | Fixed Price ($/Bbl) | Fair Value of Asset (Liability) (thousands) | ||||||||||||||||||||||
| Oil - WTI | 10/01/26 - 12/31/2026 | $ | $ | ( | ||||||||||||||||||||||
| Total open price call contracts | $ | ( | ||||||||||||||||||||||||
The following is a summary of the Company’s open basis differential swap contracts at September 30, 2026.
| Commodity | Calculation Period | Notional Quantity (MMBtu) | Fixed Price ($/MMBtu) | Fair Value of Asset (Liability) (thousands) | ||||||||||||||||||||||
| 10/01/2026 - 12/31/2026 | $ | ( | $ | ( | ||||||||||||||||||||||
| Natural Gas Basis Differential - Houston Ship Channel | 10/01/2026 - 09/30/2029 | $ | ( | ( | ||||||||||||||||||||||
| Total open basis differential swap contracts | $ | ( | ||||||||||||||||||||||||
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.
20
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 9 — 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, 2026 and December 31, 2025 (in thousands).
| Derivative Instruments | Gross amounts recognized | Gross amounts netted in the condensed consolidated balance sheets | Net amounts presented in the condensed consolidated balance sheets | |||||||||||||||||||||||
| September 30, 2026 | ||||||||||||||||||||||||||
| $ | $ | ( | $ | |||||||||||||||||||||||
| Other assets | ( | |||||||||||||||||||||||||
| ( | ( | |||||||||||||||||||||||||
| Long-term liabilities | ( | ( | ||||||||||||||||||||||||
| Total | $ | ( | $ | $ | ( | |||||||||||||||||||||
| December 31, 2025 | ||||||||||||||||||||||||||
| Current assets | $ | $ | ( | $ | ||||||||||||||||||||||
| Current liabilities | ( | |||||||||||||||||||||||||
| Total | $ | $ | $ | |||||||||||||||||||||||
The following table summarizes the location and aggregate gain (loss) of all derivative financial instruments recorded in the interim unaudited condensed consolidated statements of operations for the periods presented (in thousands).
| Three Months Ended September 30, | Nine Months Ended September 30, | |||||||||||||||||||||||||||||||
| Type of Instrument | Location in Condensed Consolidated Statement of Operations | 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||||||||||
| Derivative Instrument | ||||||||||||||||||||||||||||||||
| Oil | Revenues: Realized loss on derivatives | $ | ( | $ | $ | ( | $ | |||||||||||||||||||||||||
| Natural Gas | Revenues: Realized (loss) gain on derivatives | ( | ||||||||||||||||||||||||||||||
| Realized (loss) gain on derivatives | ( | ( | ||||||||||||||||||||||||||||||
| Oil | Revenues: Unrealized loss on derivatives | ( | ( | ( | ( | |||||||||||||||||||||||||||
| Natural Gas | Revenues: Unrealized (loss) gain on derivatives | ( | ( | ( | ||||||||||||||||||||||||||||
| Unrealized (loss) gain on derivatives | ( | ( | ( | |||||||||||||||||||||||||||||
| Total | $ | ( | $ | $ | ( | $ | ||||||||||||||||||||||||||
NOTE 10 — FAIR VALUE MEASUREMENTS
The Company measures and reports certain financial and non-financial assets and liabilities on a fair value basis. Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date (exit price). Fair value measurements are classified and disclosed in one of the following categories.
Level 1 Unadjusted quoted prices for identical, unrestricted assets or liabilities in active markets.
Level 2 Quoted prices in markets that are not active, or inputs that are observable, either directly or indirectly, for substantially the full term of the asset or liability. This category includes those derivative instruments that are valued with industry standard models that consider various inputs, including: (i) quoted forward prices for commodities, (ii) time value of money and (iii) current market and contractual prices for the underlying instruments, as well as other relevant economic measures. Substantially all of these inputs are observable in the marketplace throughout the full term of the derivative instrument and can be derived from observable data or supported by observable levels at which transactions are executed in the marketplace.
21
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 10 — FAIR VALUE MEASUREMENTS — Continued
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, 2026 and December 31, 2025 (in thousands).
Fair Value Measurements at September 30, 2026 using | ||||||||||||||||||||||||||
| Description | Level 1 | Level 2 | Level 3 | Total | ||||||||||||||||||||||
| Assets (Liabilities) | ||||||||||||||||||||||||||
| Oil costless collars | $ | $ | ( | $ | $ | ( | ||||||||||||||||||||
| Oil price calls | ( | ( | ||||||||||||||||||||||||
| Natural gas costless collars | ||||||||||||||||||||||||||
| Natural gas basis differential swaps | ( | ( | ||||||||||||||||||||||||
| Total | $ | $ | ( | $ | $ | ( | ||||||||||||||||||||
Fair Value Measurements at December 31, 2025 using | ||||||||||||||||||||||||||
| Description | Level 1 | Level 2 | Level 3 | Total | ||||||||||||||||||||||
| Assets (Liabilities) | ||||||||||||||||||||||||||
| Oil costless collars | $ | $ | $ | $ | ||||||||||||||||||||||
| Natural gas costless collars | ||||||||||||||||||||||||||
| Natural gas basis differential swaps | ||||||||||||||||||||||||||
| Total | $ | $ | $ | $ | ||||||||||||||||||||||
Additional disclosures related to derivative financial instruments are provided in Note 9, Derivative Financial Instruments.
Other Fair Value Measurements
At September 30, 2026 and December 31, 2025, 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, 2026 and December 31, 2025, the carrying value of borrowings under the Credit Agreement and the San Mateo Revolving 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, 2026, the carrying value of the San Mateo Term Loan approximated its fair value as it is subject to short-term floating interest rates and has a short-term maturity and is classified at Level 2 in the fair value hierarchy.
22
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 10 — FAIR VALUE MEASUREMENTS — Continued
The following table summarizes the carrying values and fair values of outstanding senior unsecured notes at September 30, 2026 and December 31, 2025 (in thousands).
| September 30, 2026 | December 31, 2025 | ||||||||||||||||||||||||||||
| Fair Value Hierarchy | Carrying Value | Fair Value | Carrying Value | Fair Value | |||||||||||||||||||||||||
| 2028 Notes | Level 1 | $ | $ | $ | $ | ||||||||||||||||||||||||
| 2032 Notes | Level 1 | $ | $ | $ | $ | ||||||||||||||||||||||||
| 2033 Notes | Level 1 | $ | $ | $ | $ | ||||||||||||||||||||||||
| 2034 Notes | Level 1 | $ | $ | $ | $ | ||||||||||||||||||||||||
NOTE 11 — 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 $34.9 million and $18.8 million for services under these agreements during the three months ended September 30, 2026 and 2025, respectively, and $100.1 million and $62.2 million for services under these agreements during the nine months ended September 30, 2026 and 2025, 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, 2026, the total deficiencies required to be paid by the Company under these agreements would be approximately $2.50 billion.
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. The Company also dedicated to San Mateo certain of its current and future leasehold interests in the Ranger and Antelope Ridge asset areas pursuant to 15-year, fixed-fee natural gas gathering, compression, treating and processing agreements (collectively with the transportation, gathering, produced water disposal and natural gas processing 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, 2026 was approximately $590.1 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.
23
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 12 — SUPPLEMENTAL DISCLOSURES
Accounts Payable and Accrued Liabilities
The following table summarizes the Company’s current accounts payable and accrued liabilities at September 30, 2026 and December 31, 2025 (in thousands).
| September 30, 2026 | December 31, 2025 | ||||||||||
| Accounts payable | $ | $ | |||||||||
| Accrued evaluated and unproved and unevaluated property costs | |||||||||||
| Accrued lease operating expenses | |||||||||||
| Accrued interest on debt | |||||||||||
| Accrued derivative payments | |||||||||||
| Accrued payable related to purchased natural gas | |||||||||||
| Accrued partners’ share of joint interest charges | |||||||||||
| Accrued compensation and benefits | |||||||||||
| Accrued midstream properties costs | |||||||||||
| Accrued asset retirement obligations | |||||||||||
| Other | |||||||||||
| Total accounts payable and accrued liabilities | $ | $ | |||||||||
Supplemental Cash Flow Information
The following table provides supplemental disclosures of cash flow information for the nine months ended September 30, 2026 and 2025 (in thousands).
| Nine Months Ended September 30, | |||||||||||
| 2026 | 2025 | ||||||||||
| Cash paid for interest expense, net of amounts capitalized | $ | $ | |||||||||
| Increase in asset retirement obligations related to mineral properties | $ | $ | |||||||||
| Increase in asset retirement obligations related to midstream properties | $ | $ | |||||||||
| Increase in liabilities for drilling, completion and equipping capital expenditures | $ | $ | |||||||||
| Increase in liabilities for acquisition of oil and natural gas properties | $ | $ | |||||||||
| Increase in liabilities for midstream properties capital expenditures | $ | $ | |||||||||
| Stock-based compensation expense recognized as a liability | $ | $ | |||||||||
| Transfer of inventory to (from) oil and natural gas properties | $ | $ | ( | ||||||||
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, | |||||||||||
| 2026 | 2025 | ||||||||||
| Cash | $ | $ | |||||||||
| Restricted cash | |||||||||||
| Total cash and restricted cash | $ | $ | |||||||||
24
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 13 — SEGMENT INFORMATION
The Company has 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 has operations in the Haynesville shale and Cotton Valley plays in Northwest Louisiana. The midstream segment conducts midstream operations in support of, and provides flow assurance for, 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 Delaware Basin are conducted through San Mateo.
The Company’s chief operating decision maker (“CODM”) is the Chairman and Chief Executive Officer. The CODM uses operating income to assess income generated from each segment to allocate resources by either reinvesting profits as midstream or drilling and completion capital expenditures, or for determining the appropriate amounts for acquisition spend, the repayment of debt, the payment of dividends and repurchases of common stock.
The following tables present selected financial information for the periods presented regarding the Company’s business segments on a stand-alone basis, corporate expenses that are not allocated to a segment and the consolidation and elimination entries necessary to arrive at the financial information for the Company on a consolidated basis (in thousands). On a consolidated basis, midstream services revenues consist primarily of those revenues from midstream operations related to third parties, including working interest owners in the Company’s operated wells. All midstream services revenues associated with Company-owned production are eliminated in consolidation. In evaluating the operating results of the exploration and production and midstream segments, the Company does not allocate certain expenses to the individual segments, including general and administrative expenses. Such expenses are reflected in the column labeled “Corporate.”
| Exploration and Production | Consolidations and Eliminations | Consolidated Company | |||||||||||||||||||||||||||
| Midstream | Corporate | ||||||||||||||||||||||||||||
| Three Months Ended September 30, 2026 | |||||||||||||||||||||||||||||
| Oil and natural gas revenues | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
| Midstream services revenues | ( | ||||||||||||||||||||||||||||
| Sales of purchased natural gas | |||||||||||||||||||||||||||||
| Realized loss on derivatives | ( | ( | |||||||||||||||||||||||||||
| Unrealized loss on derivatives | ( | ( | |||||||||||||||||||||||||||
Operating expense(1) | ( | ||||||||||||||||||||||||||||
Other expenses(2) | ( | ||||||||||||||||||||||||||||
Operating income(3) | $ | $ | $ | ( | $ | $ | |||||||||||||||||||||||
Total assets(4) | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
Capital expenditures(5) | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
_____________________
(1)Includes lease operating expense for the exploration and production segment and midstream operating expense for the midstream segment.
(2)Includes depletion, depreciation and amortization expenses of $320.1 million and $22.6 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $0.3 million. Other expenses for each reportable segment also include (i) transportation and processing, (ii) general and administrative expenses, (iii) accretion of asset retirement obligations, (iv) purchased natural gas and (v) taxes other than income.
(3)Includes $23.0 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment.
(4)Excludes intercompany receivables and investments in subsidiaries.
(5)Includes $25.9 million attributable to land and seismic acquisition expenditures related to the exploration and production segment, $761.0 million attributable to midstream acquisition expenditures and $12.1 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment.
25
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 13 — SEGMENT INFORMATION — Continued
| Exploration and Production | Consolidations and Eliminations | Consolidated Company | |||||||||||||||||||||||||||
| Midstream | Corporate | ||||||||||||||||||||||||||||
| Three Months Ended September 30, 2025 | |||||||||||||||||||||||||||||
| Oil and natural gas revenues | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
| Midstream services revenues | ( | ||||||||||||||||||||||||||||
| Sales of purchased natural gas | |||||||||||||||||||||||||||||
| Realized gain on derivatives | |||||||||||||||||||||||||||||
| Unrealized gain on derivatives | |||||||||||||||||||||||||||||
Operating expense(1) | ( | ||||||||||||||||||||||||||||
Other expenses(2) | ( | ||||||||||||||||||||||||||||
Operating income(3) | $ | $ | $ | ( | $ | $ | |||||||||||||||||||||||
Total assets(4) | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
Capital expenditures(5) | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
_____________________
(1)Includes lease operating expense for the exploration and production segment and midstream operating expense for the midstream segment.
(2)Includes depletion, depreciation and amortization expenses of $290.1 million and $14.9 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $0.4 million. Other expenses for each reportable segment also include (i) transportation and processing, (ii) general and administrative expenses, (iii) accretion of asset retirement obligations, (iv) purchased natural gas and (v) taxes other than income.
(3)Includes $24.3 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment.
(4)Excludes intercompany receivables and investments in subsidiaries.
(5)Includes $140.0 million attributable to land and seismic acquisition expenditures related to the exploration and production segment and $29.4 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment.
| Exploration and Production | Consolidations and Eliminations | Consolidated Company | |||||||||||||||||||||||||||
| Midstream | Corporate | ||||||||||||||||||||||||||||
| Nine Months Ended September 30, 2026 | |||||||||||||||||||||||||||||
| Oil and natural gas revenues | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
| Midstream services revenues | ( | ||||||||||||||||||||||||||||
| Sales of purchased natural gas | |||||||||||||||||||||||||||||
| Realized loss on derivatives | ( | ( | |||||||||||||||||||||||||||
| Unrealized loss on derivatives | ( | ( | |||||||||||||||||||||||||||
Operating expense(1) | ( | ||||||||||||||||||||||||||||
Other expenses(2) | ( | ||||||||||||||||||||||||||||
Operating income(3) | $ | $ | $ | ( | $ | $ | |||||||||||||||||||||||
Total assets(4) | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
Capital expenditures(5) | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
_____________________
(1)Includes lease operating expense for the exploration and production segment and midstream operating expense for the midstream segment.
(2)Includes depletion, depreciation and amortization expenses of $892.5 million and $57.2 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $1.1 million. Other expenses for each reportable segment also includes (i) transportation and processing, (ii) general and administrative expenses, (iii) accretion of asset retirement obligations, (iv) purchased natural gas and (v) taxes other than income.
(3)Includes $66.0 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment.
26
Matador Resources Company and Subsidiaries
NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS —
UNAUDITED — CONTINUED
NOTE 13 — SEGMENT INFORMATION — Continued
(4)Excludes intercompany receivables and investments in subsidiaries.
(5)Includes $1.27 billion attributable to land and seismic acquisition expenditures related to the exploration and production segment, $767.2 million attributable to midstream acquisition expenditures and $30.7 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment.
| Exploration and Production | Consolidations and Eliminations | Consolidated Company | |||||||||||||||||||||||||||
| Midstream | Corporate | ||||||||||||||||||||||||||||
| Nine Months Ended September 30, 2025 | |||||||||||||||||||||||||||||
| Oil and natural gas revenues | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
| Midstream services revenues | ( | ||||||||||||||||||||||||||||
| Sales of purchased natural gas | |||||||||||||||||||||||||||||
| Realized gain on derivatives | |||||||||||||||||||||||||||||
| Unrealized loss on derivatives | ( | ( | |||||||||||||||||||||||||||
Operating expense(1) | ( | ||||||||||||||||||||||||||||
Other expenses(2) | ( | ||||||||||||||||||||||||||||
Operating income(3) | $ | $ | $ | ( | $ | $ | |||||||||||||||||||||||
Total assets(4) | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
Capital expenditures(5) | $ | $ | $ | $ | $ | ||||||||||||||||||||||||
_____________________
(1)Includes lease operating expense for the exploration and production segment and midstream operating expense for the midstream segment.
(2)Includes depletion, depreciation and amortization expenses of $848.6 million and $40.1 million for the exploration and production and midstream segments, respectively. Also includes corporate depletion, depreciation and amortization expenses of $1.2 million. Other expenses for each reportable segment also include (i) transportation and processing, (ii) general and administrative expenses, (iii) accretion of asset retirement obligations, (iv) purchased natural gas and (v) taxes other than income.
(3)Includes $78.6 million in net income attributable to non-controlling interest in subsidiaries related to the midstream segment.
(4)Excludes intercompany receivables and investments in subsidiaries.
(5)Includes $265.6 million attributable to land and seismic acquisition expenditures related to the exploration and production segment and $105.5 million in capital expenditures attributable to non-controlling interest in subsidiaries related to the midstream segment.
NOTE 14 — SUBSEQUENT EVENTS
Paloma Acquisition
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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, 2025 (the “Annual Report”) filed with the Securities and Exchange Commission (the “SEC”) on February 26, 2026, 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 and (iii) references to “San Mateo” refer to San Mateo Midstream, LLC, collectively with its subsidiaries. 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. All statements, other than statements of historical fact, included in this Quarterly Report regarding our strategy, future operations, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. 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,” “seek,” “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, including the effects of inflation and interest rates; tariffs and trade tensions; 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 acquisition of third-party businesses 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 or the construction, expansion or operation of our midstream assets; 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, capital markets, available borrowing capacity under our revolving credit facilities and otherwise; our ability to make acquisitions on economically acceptable terms; disruption from our acquisitions, including the Cardinal Acquisition and the Paloma Acquisition (each as defined below), making it more difficult to maintain business and operational relationships; significant transaction costs associated with our acquisitions, including the Cardinal Acquisition and the Paloma Acquisition; evolving cybersecurity risks; the risk of litigation and/or regulatory actions related to our acquisitions, including the Cardinal Acquisition and the Paloma 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;
•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;
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•the availability of drilling and production equipment;
•the availability of oil storage capacity;
•the availability and cost 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 Cardinal Acquisition and the Paloma Acquisition, with our business;
•government regulation and taxation of the oil and natural gas industry;
•tariffs and trade restrictions;
•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 Cardinal Acquisition and the Paloma Acquisition, including the benefits thereof;
•the impact of the One Big Beautiful Bill Act of 2025 (the “OBBBA”); 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.
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 have operations in the Haynesville shale and Cotton Valley plays in Northwest Louisiana. Additionally, we conduct midstream operations in support of, and to provide flow assurance for, 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.
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Third Quarter Highlights
For the three months ended September 30, 2026, our total oil equivalent production was 21.2 million BOE, and our average daily oil equivalent production was 230,470 BOE per day, of which 132,019 Bbl per day, or 57%, was oil and 590.7 MMcf per day, or 43%, was natural gas. Our average daily oil production of 132,019 Bbl per day for the three months ended September 30, 2026 increased 10% year-over-year from 119,556 Bbl per day for the three months ended September 30, 2025. Our average daily natural gas production of 590.7 MMcf per day for the three months ended September 30, 2026 increased 10% year-over-year from 537.8 MMcf per day for the three months ended September 30, 2025. The Delaware Basin contributed 100% of our daily oil production and 97% of our daily natural gas production in the third quarter of 2026, as compared to 100% of our daily oil production and 94% of our daily natural gas production in the third quarter of 2025.
For the third quarter of 2026, we reported net income attributable to Matador shareholders of $172.1 million, or $1.39 per diluted common share, on a GAAP basis, as compared to net income attributable to Matador shareholders of $176.4 million, or $1.42 per diluted common share, for the third quarter of 2025. For the third quarter of 2026, our Adjusted EBITDA, a non‑GAAP financial measure, was $738.3 million, as compared to Adjusted EBITDA of $566.5 million during the third quarter of 2025.
For the nine months ended September 30, 2026, we reported net income attributable to Matador shareholders of $526.9 million, or $4.24 per diluted common share, on a GAAP basis, as compared to net income attributable to Matador shareholders of $566.7 million, or $4.54 per diluted common share, for the nine months ended September 30, 2025. For the nine months ended September 30, 2026, our Adjusted EBITDA, a non‑GAAP financial measure, was $2.10 billion, as compared to Adjusted EBITDA of $1.80 billion for the nine months ended September 30, 2025.
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, 2026, see “—Results of Operations” below.
Acquisitions
In May 2026, we completed the acquisition of 5,154 net undeveloped acres in the core of the Delaware Basin in Southeast New Mexico for approximately $1.16 billion as part of the Bureau of Land Management Oil and Gas Lease Sale (the “BLM Acquisition”). The acquired acreage complements our existing acreage position, and as a result, includes proved undeveloped reserves in addition to unproved and unevaluated reserves.
In July 2026, San Mateo completed the acquisition of the operating subsidiaries of Cardinal Midstream Partners, LLC (“Cardinal”), a portfolio company of EnCap Flatrock Midstream, for total cash consideration of $761.0 million, subject to certain customary post-closing purchase price adjustments (the “Cardinal Acquisition”).
Subsequent to the end of the reporting period, on October 1, 2026, we completed the acquisition of Paloma Permian, LLC (“Paloma”) from a portfolio company of EnCap Investments L.P., including certain proved undeveloped acreage and oil and natural gas producing properties located in Eddy and Lea Counties, New Mexico (the “Paloma Acquisition”). The Paloma Acquisition has an effective date of June 1, 2026 and an aggregate as-adjusted closing purchase price of approximately $1.255 billion, subject to customary post-closing adjustments, including for working capital and for title defects.
For discussion of the funding for these acquisitions, see “—Liquidity and Capital Resources” in Part I, Item 2 of this Quarterly Report.
2026 Capital Expenditure Budget
On November 3, 2026, we adjusted our estimated drilling, completing and equipping (“D/C/E”) capital expenditures for 2026 to a range of $1.50 to $1.54 billion from a range of $1.48 to $1.56 billion, which includes our expected D/C/E capital expenditures on acreage acquired in the BLM Acquisition and Paloma Acquisition.
On November 3, 2026, we also adjusted our estimated midstream capital expenditures for 2026 to a range of $170.0 to $190.0 million from a range of $145.0 to $165.0 million, which includes our proportionate share of San Mateo’s estimated 2026 capital expenditures as well as the estimated 2026 capital expenditures for other wholly-owned midstream projects. More specifically, the $25 million increase in estimated midstream capital expenditures is to fund initial work on a new natural gas processing train at San Mateo’s Marlan Plant complex and associated gathering assets. This expansion is underwritten by a new agreement with a large Delaware Basin producer expected to add meaningful long-term volumes across San Mateo’s existing gathering and processing footprint as well as anticipated increased volumes from Matador production.
Critical Accounting Policies and Estimates
As of September 30, 2026, there have been no changes to our critical accounting policies and estimates from those set forth in the Annual Report except as noted below.
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The Cardinal Acquisition was accounted for under the acquisition method of accounting as a business combination in accordance with Accounting Standards Codification 805, Business Combinations (“ASC 805”). Under ASC 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. The Cardinal Acquisition purchase price allocation resulted in customer relationship intangible assets and goodwill. See Note 3, Acquisitions, to the unaudited condensed consolidated financial statements in this Quarterly Report for additional information on the Cardinal Acquisition including the preliminary allocation of the total purchase price and the inputs, estimates and judgments used in the valuation.
Intangibles
Amortization of intangibles with definite lives is calculated using the straight-line method, which is reflective of the benefit pattern in which the estimated economic benefit is expected to be received over the estimated useful life of the intangible asset. Intangibles subject to amortization are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of the intangible may not be recoverable. If the sum of the expected undiscounted future cash flows related to the asset is less than the carrying amount of the asset, an impairment loss is recognized based on the fair value of the asset.
Goodwill
Goodwill represents the excess of the purchase price over the estimated fair value of the net assets acquired in the acquisition of a business. Goodwill is not amortized, but rather is tested for impairment at the reporting unit level annually and when events or changes in circumstances indicate that the fair value of a reporting unit with goodwill has been reduced below carrying value. If we determine, based on a qualitative assessment, that it is not more likely than not that a reporting unit’s fair value is less than its carrying amount, no further impairment testing is required. If we do not perform a qualitative assessment or if that assessment indicates that further impairment testing is required, the fair value of each reporting unit is determined using an income and market approach which is compared to the carrying value of the reporting unit. If the carrying amount of the reporting unit exceeds its fair value, an impairment loss would be recognized in an amount equal to that excess, limited to the total amount of goodwill allocated to that reporting unit. The fair value under the income approach is calculated using the expected present value of future cash flows method. Significant assumptions used in the cash flow forecasts include future net operating margins, future volumes, discount rates and future capital requirements.
Recent Accounting Pronouncements
There are no recent accounting pronouncements that are expected to have a material impact on our financial statements.
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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, | |||||||||||||||||||||||||||||||||||
| 2026 | 2025 | $ Change | % Change | ||||||||||||||||||||||||||||||||
| Operating Data | |||||||||||||||||||||||||||||||||||
Revenues (in thousands)(1) | |||||||||||||||||||||||||||||||||||
| Oil | $ | 1,059,685 | $ | 713,947 | $ | 345,738 | 48 | % | |||||||||||||||||||||||||||
| Natural gas | 162,436 | 96,294 | 66,142 | 69 | % | ||||||||||||||||||||||||||||||
| Total oil and natural gas revenues | 1,222,121 | 810,241 | 411,880 | 51 | % | ||||||||||||||||||||||||||||||
| Third-party midstream services revenues | 56,334 | 43,833 | 12,501 | 29 | % | ||||||||||||||||||||||||||||||
| Sales of purchased natural gas | 112,085 | 61,043 | 51,042 | 84 | % | ||||||||||||||||||||||||||||||
| Realized (loss) gain on derivatives | (160,170) | 3,946 | (164,116) | (4,159) | % | ||||||||||||||||||||||||||||||
| Unrealized (loss) gain on derivatives | (67,727) | 19,952 | (87,679) | (439) | % | ||||||||||||||||||||||||||||||
| Total revenues | $ | 1,162,643 | $ | 939,015 | $ | 223,628 | 24 | % | |||||||||||||||||||||||||||
Net Production Volumes(1) | |||||||||||||||||||||||||||||||||||
| Oil (MBbl) | 12,146 | 10,999 | 1,147 | 10 | % | ||||||||||||||||||||||||||||||
| Natural gas (Bcf) | 54.3 | 49.5 | 4.8 | 10 | % | ||||||||||||||||||||||||||||||
Total oil equivalent (MBOE)(2) | 21,203 | 19,245 | 1,958 | 10 | % | ||||||||||||||||||||||||||||||
Average daily production (BOE/d)(2) | 230,470 | 209,184 | 21,286 | 10 | % | ||||||||||||||||||||||||||||||
| Average Sales Prices | |||||||||||||||||||||||||||||||||||
| Oil, without realized derivatives (per Bbl) | $ | 87.25 | $ | 64.91 | $ | 22.34 | 34 | % | |||||||||||||||||||||||||||
| Oil, with realized derivatives (per Bbl) | $ | 74.84 | $ | 64.91 | $ | 9.93 | 15 | % | |||||||||||||||||||||||||||
| Natural gas, without realized derivatives (per Mcf) | $ | 2.99 | $ | 1.95 | $ | 1.04 | 53 | % | |||||||||||||||||||||||||||
| Natural gas, with realized derivatives (per Mcf) | $ | 2.81 | $ | 2.03 | $ | 0.78 | 38 | % | |||||||||||||||||||||||||||
_________________
(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)Estimated using a conversion ratio of one Bbl of oil per six Mcf of natural gas.
Three Months Ended September 30, 2026 as Compared to Three Months Ended September 30, 2025
Oil and natural gas revenues. The increase in oil revenues resulted from the 34% increase in the weighted average oil price realized and the 10% increase in oil production. The increase in natural gas revenues primarily resulted from the 53% increase in the weighted average natural gas price realized and the 10% increase in natural gas production. For further discussion of factors impacting commodity prices, see “—General Outlook and Trends.”
Third-party midstream services revenues. Third-party midstream services revenues are those revenues from midstream operations related to third parties, including working interest owners in our operated wells. The increase in third-party midstream services revenues was primarily attributable to a $9.7 million increase in our third-party natural gas gathering and processing revenues, which was mostly driven by the Cardinal Acquisition, and a $3.8 million increase in our third-party water disposal revenues.
Sales of purchased natural gas. The increase in sales of purchased natural gas was primarily the result of a 50% increase in natural gas price realized and a 22% increase in purchased natural gas volumes sold. 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 San Mateo’s cryogenic natural gas processing plants 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 operations.
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Realized (loss) gain on derivatives. Our realized loss on derivatives was $160.2 million for the three months ended September 30, 2026, as compared to a realized gain of $3.9 million for the three months ended September 30, 2025. For the three months ended September 30, 2026, we recorded a net loss of $150.7 million related to our oil costless collars and deferred calls, resulting primarily from oil prices that were above the ceiling of certain of our oil costless collar contracts and the deferred call premiums on certain of our purchased oil call contracts. For the three months ended September 30, 2026, we recorded a net loss of $17.1 million related to our natural gas 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 and natural gas prices that were above the fixed prices of certain of our natural gas swap contracts. This loss was partially offset by a net gain of $7.5 million related to our natural gas costless collar contracts, resulting primarily from natural gas prices that were below the floor of our natural gas costless collar contracts. For the three months ended September 30, 2025, we recorded a net gain of $3.9 million related to our natural gas basis differential swap contracts, resulting primarily from natural gas basis differentials that were below the fixed prices of certain of our natural gas basis differential swap contracts. We realized an average loss on our oil derivatives of approximately $12.41 per Bbl produced during the three months ended September 30, 2026, as compared to no realized gains or losses from oil derivatives during the three months ended September 30, 2025. We realized an average loss on our natural gas derivatives of approximately $0.18 per Mcf produced during the three months ended September 30, 2026, as compared to an average gain of approximately $0.08 per Mcf produced during the three months ended September 30, 2025. See Note 9, Derivative Financial Instruments, for further details on our derivatives.
Unrealized gain (loss) on derivatives. During the three months ended September 30, 2026, the aggregate net fair value of our open oil and natural gas costless collar, oil price call, natural gas swap and natural gas basis differential swap contracts changed to a net liability of $203.7 million from a net liability of $136.0 million at June 30, 2026, resulting in an unrealized loss on derivatives of $67.7 million for the three months ended September 30, 2026. During the three months ended September 30, 2025, the aggregate net fair value of our open oil and natural gas costless collar and natural gas basis differential swap contracts changed to a net asset of $3.7 million from a net liability of $16.3 million at June 30, 2025, resulting in an unrealized gain on derivatives of $20.0 million for the three months ended September 30, 2025. See Note 9, Derivative Financial Instruments, for further details on our derivatives.
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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, | |||||||||||||||||||||||||||||||||||
| (In thousands, except expenses per BOE) | 2026 | 2025 | $ Change | % Change | |||||||||||||||||||||||||||||||
| Expenses | |||||||||||||||||||||||||||||||||||
Lease operating | $ | 120,076 | $ | 104,181 | $ | 15,895 | 15 | % | |||||||||||||||||||||||||||
| Transportation and processing | 22,980 | 18,814 | 4,166 | 22 | % | ||||||||||||||||||||||||||||||
| Midstream operating | 82,442 | 49,337 | 33,105 | 67 | % | ||||||||||||||||||||||||||||||
| Purchased natural gas | 90,900 | 47,658 | 43,242 | 91 | % | ||||||||||||||||||||||||||||||
| Depletion, depreciation and amortization | 342,961 | 305,354 | 37,607 | 12 | % | ||||||||||||||||||||||||||||||
| Taxes other than income | 100,762 | 68,754 | 32,008 | 47 | % | ||||||||||||||||||||||||||||||
| Accretion of asset retirement obligations | 3,995 | 2,148 | 1,847 | 86 | % | ||||||||||||||||||||||||||||||
| General and administrative | 44,645 | 36,790 | 7,855 | 21 | % | ||||||||||||||||||||||||||||||
| Total expenses | 808,761 | 633,036 | 175,725 | 28 | % | ||||||||||||||||||||||||||||||
| Operating income | 353,882 | 305,979 | 47,903 | 16 | % | ||||||||||||||||||||||||||||||
| Other income (expense) | |||||||||||||||||||||||||||||||||||
| Interest expense | (79,982) | (50,641) | (29,341) | 58 | % | ||||||||||||||||||||||||||||||
| Loss on asset sales | — | (589) | 589 | (100) | % | ||||||||||||||||||||||||||||||
| Other income | 2,747 | 5,003 | (2,256) | (45) | % | ||||||||||||||||||||||||||||||
| Total other expense | (77,235) | (46,227) | (31,008) | 67 | % | ||||||||||||||||||||||||||||||
| Income before income taxes | 276,647 | 259,752 | 16,895 | 7 | % | ||||||||||||||||||||||||||||||
| Income tax provision (benefit) | |||||||||||||||||||||||||||||||||||
| Current | 578 | (39,335) | 39,913 | (101) | % | ||||||||||||||||||||||||||||||
| Deferred | 80,970 | 98,463 | (17,493) | (18) | % | ||||||||||||||||||||||||||||||
| Total income tax provision | 81,548 | 59,128 | 22,420 | 38 | % | ||||||||||||||||||||||||||||||
| Net income | 195,099 | 200,624 | (5,525) | (3) | % | ||||||||||||||||||||||||||||||
| Net income attributable to non-controlling interest in subsidiaries | (22,979) | (24,260) | 1,281 | (5) | % | ||||||||||||||||||||||||||||||
| Net income attributable to Matador Resources Company shareholders | $ | 172,120 | $ | 176,364 | $ | (4,244) | (2) | % | |||||||||||||||||||||||||||
| Expenses per BOE | |||||||||||||||||||||||||||||||||||
| Lease operating | $ | 5.66 | $ | 5.42 | $ | 0.24 | 4 | % | |||||||||||||||||||||||||||
| Transportation and processing | $ | 1.08 | $ | 0.98 | $ | 0.10 | 10 | % | |||||||||||||||||||||||||||
| Midstream operating | $ | 3.89 | $ | 2.56 | $ | 1.33 | 52 | % | |||||||||||||||||||||||||||
| Depletion, depreciation and amortization | $ | 16.18 | $ | 15.87 | $ | 0.31 | 2 | % | |||||||||||||||||||||||||||
| Taxes other than income | $ | 4.75 | $ | 3.57 | $ | 1.18 | 33 | % | |||||||||||||||||||||||||||
| General and administrative | $ | 2.11 | $ | 1.91 | $ | 0.20 | 10 | % | |||||||||||||||||||||||||||
Three Months Ended September 30, 2026 as Compared to Three Months Ended September 30, 2025
Lease operating. The increase in lease operating expense was primarily attributable to the increased number of wells being operated by us and other operators (where we own a working interest).
Transportation and processing. The increase in transportation and processing expenses was primarily due to the 10% increase in our total oil equivalent production and a change in the mix of revenue contracts between the periods.
Midstream operating. The increase in midstream operating expense was primarily attributable to a $20.1 million increase in pipeline operation expenses as a result of increased inlet connections and a $9.0 million increase in plant processing expenses as a result of increased gas gathering and processing volumes, as well as the Cardinal Acquisition.
Purchased natural gas. The increase in purchased natural gas expense was primarily due to an increase of approximately 167% in average Waha pricing during the current period and a 93% increase in volumes purchased.
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Depletion, depreciation and amortization. The increase in depletion, depreciation and amortization expense was primarily a result of the 10% increase in our total oil equivalent production and the addition of $248.1 million of proved reserves to the full cost pool as a result of the BLM Acquisition.
Taxes other than income. The increase in taxes other than income was primarily due to a $34.0 million increase in production taxes as a result of the increase in oil and natural gas revenues.
General and administrative. The increase in general and administrative expense was largely attributable to $3.1 million in transaction costs associated with the Cardinal Acquisition, a $1.1 million increase in rent expense and $0.8 million in transaction costs associated with the Paloma Acquisition.
Interest expense. The increase in interest expense was primarily due to a $607.5 million increase in average debt outstanding under the Credit Agreement, a $160.0 million increase in average debt outstanding under the San Mateo Revolving Credit Facility and a $250.0 million increase in the weighted average of senior notes outstanding between the periods, as well as the new $650.0 million San Mateo Term Loan (see “—Liquidity and Capital Resources” below for further discussion). These increases were partially offset by lower interest rates.
Income tax provision. The decrease in the current income tax benefit and the decrease in the deferred income tax provision were primarily the result of the enactment of the OBBBA during the third quarter of 2025, which resulted in the recognition of the impacts of the OBBBA for the first two quarters of 2025 in the third quarter of 2025. There were no such legislation changes in the third quarter of 2026. See Note 8, Income Taxes, of our Annual Report for further details of the provisions of the OBBBA that most significantly affect our income taxes. Additionally, the increase in the total income tax provision resulted from higher income before income taxes. Our effective income tax rate of 32% for the three months ended September 30, 2026 differed from the U.S. federal statutory rate primarily due to state taxes in New Mexico and the impact of permanent differences between book and tax income recognized discretely in the current period.
Revenues
The following table summarizes our unaudited revenues and production data for the periods indicated:
| Nine Months Ended September 30, | |||||||||||||||||||||||
| 2026 | 2025 | $ Change | % Change | ||||||||||||||||||||
| Operating Data | |||||||||||||||||||||||
Revenues (in thousands)(1) | |||||||||||||||||||||||
| Oil | $ | 2,974,459 | $ | 2,182,648 | $ | 791,811 | 36 | % | |||||||||||||||
| Natural gas | 153,977 | 353,285 | (199,308) | (56) | % | ||||||||||||||||||
| Total oil and natural gas revenues | 3,128,436 | 2,535,933 | 592,503 | 23 | % | ||||||||||||||||||
| Third-party midstream services revenues | 143,018 | 119,339 | 23,679 | 20 | % | ||||||||||||||||||
| Sales of purchased natural gas | 234,113 | 191,696 | 42,417 | 22 | % | ||||||||||||||||||
| Realized (loss) gain on derivatives | (247,151) | 13,607 | (260,758) | (1,916) | % | ||||||||||||||||||
| Unrealized loss on derivatives | (237,744) | (12,290) | (225,454) | 1,834 | % | ||||||||||||||||||
| Total revenues | $ | 3,020,672 | $ | 2,848,285 | $ | 172,387 | 6 | % | |||||||||||||||
Net Production Volumes(1) | |||||||||||||||||||||||
| Oil (MBbl) | 34,446 | 32,534 | 1,912 | 6 | % | ||||||||||||||||||
| Natural gas (Bcf) | 150.4 | 141.7 | 8.7 | 6 | % | ||||||||||||||||||
Total oil equivalent (MBOE)(2) | 59,508 | 56,142 | 3,366 | 6 | % | ||||||||||||||||||
Average daily production (BOE/d)(2) | 217,982 | 205,648 | 12,334 | 6 | % | ||||||||||||||||||
| Average Sales Prices | |||||||||||||||||||||||
| Oil, without realized derivatives (per Bbl) | $ | 86.35 | $ | 67.09 | 19.26 | 29 | % | ||||||||||||||||
| Oil, with realized derivatives (per Bbl) | $ | 75.48 | $ | 67.09 | $ | 8.39 | 13 | % | |||||||||||||||
| Natural gas, without realized derivatives (per Mcf) | $ | 1.02 | $ | 2.49 | $ | (1.47) | (59) | % | |||||||||||||||
| Natural gas, with realized derivatives (per Mcf) | $ | 1.87 | $ | 2.59 | $ | (0.72) | (28) | % | |||||||||||||||
_________________
(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.
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(2)Estimated using a conversion ratio of one Bbl of oil per six Mcf of natural gas.
Nine Months Ended September 30, 2026 as Compared to Nine Months Ended September 30, 2025
Oil and natural gas revenues. The increase in oil revenues resulted from the 29% increase in the weighted average oil price realized and the 6% increase in our oil production. The decrease in natural gas revenues primarily resulted from the 59% decrease in the weighted average natural gas price realized, which was partially offset by the 6% increase in our natural gas production. For further discussion of factors impacting commodity prices, see “—General Outlook and Trends.”
Third-party midstream services revenues. Third-party midstream services revenues are those revenues from midstream operations related to third parties, including working interest owners in our operated wells. The increase in third-party midstream services revenues was primarily attributable to a $21.7 million increase in our third-party natural gas gathering and processing revenues, $8.9 million of which was driven by the Cardinal Acquisition, and a $2.4 million increase in our third-party water disposal revenues.
Sales of purchased natural gas. The increase in sales of purchased natural gas was primarily the result of a 37% increase in purchased natural gas volumes sold, which was partially offset by a 11% 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 San Mateo’s cryogenic natural gas processing plants 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 operations.
Realized (loss) gain on derivatives. Our realized loss on derivatives was $247.2 million for the nine months ended September 30, 2026, as compared to a realized gain of $13.6 million for the nine months ended September 30, 2025. For the nine months ended September 30, 2026, we recorded a net loss of $374.3 million related to our oil costless collars and deferred calls, resulting primarily from oil prices that were above the ceiling of certain of our oil costless collar contracts and the deferred call premiums on certain of our purchased oil call contracts. This loss was partially offset by a net gain of $127.1 million related to our natural gas costless collar and swap contracts, resulting primarily from natural gas prices that were below the floor of our natural gas costless collar contracts, natural gas prices that were below the fixed prices of certain of our natural gas swap contracts and natural gas basis differentials that were below the fixed prices of certain of our natural gas basis differential swap contracts. For the nine months ended September 30, 2025, we recorded a net gain of $13.6 million related to our natural gas basis differential swap contracts, resulting primarily from natural gas basis differentials that were below the fixed prices of certain of our natural gas basis differential swap contracts. We realized an average loss on our oil derivatives of approximately $10.87 per Bbl produced during the nine months ended September 30, 2026, as compared to no realized gains or losses from oil derivatives during the nine months ended September 30, 2025. We realized an average gain on our natural gas derivatives of approximately $0.85 and $0.10 per Mcf produced during the nine months ended September 30, 2026 and 2025, respectively. See Note 9, Derivative Financial Instruments, for further details on our derivatives.
Unrealized loss on derivatives. During the nine months ended September 30, 2026, the aggregate net fair value of our open oil and natural gas costless collar, oil price call and natural gas basis differential swap contracts changed to a net liability of $203.7 million from a net asset of $34.1 million at December 31, 2025, resulting in an unrealized loss on derivatives of $237.7 million for the nine months ended September 30, 2026. During the nine months ended September 30, 2025, the aggregate net fair value of our open oil and natural gas costless collar and natural gas basis differential swap contracts changed to a net asset of $3.7 million from a net asset of $16.0 million at December 31, 2024, resulting in an unrealized loss on derivatives of $12.3 million for the nine months ended September 30, 2025. See Note 9, Derivative Financial Instruments, for further details on our derivatives.
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Expenses
The following table summarizes our unaudited operating expenses and other income (expense) for the periods indicated:
| Nine Months Ended September 30, | |||||||||||||||||||||||
| (In thousands, except expenses per BOE) | 2026 | 2025 | $ Change | % Change | |||||||||||||||||||
| Expenses | |||||||||||||||||||||||
| Lease operating | $ | 334,550 | $ | 313,822 | $ | 20,728 | 7 | % | |||||||||||||||
| Transportation and processing | 56,756 | 55,326 | 1,430 | 3 | % | ||||||||||||||||||
| Midstream operating | 198,205 | 145,597 | 52,608 | 36 | % | ||||||||||||||||||
| Purchased natural gas | 94,323 | 137,735 | (43,412) | (32) | % | ||||||||||||||||||
| Depletion, depreciation and amortization | 950,809 | 889,847 | 60,962 | 7 | % | ||||||||||||||||||
| Taxes other than income | 274,447 | 213,813 | 60,634 | 28 | % | ||||||||||||||||||
| Accretion of asset retirement obligations | 8,615 | 5,642 | 2,973 | 53 | % | ||||||||||||||||||
| General and administrative | 124,942 | 102,709 | 22,233 | 22 | % | ||||||||||||||||||
| Total expenses | 2,042,647 | 1,864,491 | 178,156 | 10 | % | ||||||||||||||||||
| Operating income | 978,025 | 983,794 | (5,769) | (1) | % | ||||||||||||||||||
| Other income (expense) | |||||||||||||||||||||||
| Interest expense | (192,326) | (153,475) | (38,851) | 25 | % | ||||||||||||||||||
| Loss on debt extinguishment | (15,587) | — | (15,587) | 100 | % | ||||||||||||||||||
| Loss on asset sales | (578) | (589) | 11 | (2) | % | ||||||||||||||||||
| Other income | 11,100 | 14,011 | (2,911) | (21) | % | ||||||||||||||||||
| Total other expense | (197,391) | (140,053) | (57,338) | 41 | % | ||||||||||||||||||
| Income before income taxes | 780,634 | 843,741 | (63,107) | (7) | % | ||||||||||||||||||
| Income tax provision (benefit) | |||||||||||||||||||||||
| Current | 804 | 6,735 | (5,931) | (88) | % | ||||||||||||||||||
| Deferred | 186,897 | 191,776 | (4,879) | (3) | % | ||||||||||||||||||
| Total income tax provision | 187,701 | 198,511 | (10,810) | (5) | % | ||||||||||||||||||
| Net income | 592,933 | 645,230 | (52,297) | (8) | % | ||||||||||||||||||
| Net income attributable to non-controlling interest in subsidiaries | (66,033) | (78,556) | 12,523 | (16) | % | ||||||||||||||||||
| Net income attributable to Matador Resources Company shareholders | $ | 526,900 | $ | 566,674 | $ | (39,774) | (7) | % | |||||||||||||||
| Expenses per BOE | |||||||||||||||||||||||
| Lease operating | $ | 5.62 | $ | 5.59 | $ | 0.03 | 1 | % | |||||||||||||||
| Transportation and processing | $ | 0.95 | $ | 0.99 | $ | (0.04) | (4) | % | |||||||||||||||
| Midstream operating | $ | 3.33 | $ | 2.59 | $ | 0.74 | 29 | % | |||||||||||||||
| Depletion, depreciation and amortization | $ | 15.98 | $ | 15.85 | $ | 0.13 | 1 | % | |||||||||||||||
| Taxes other than income | $ | 4.61 | $ | 3.81 | $ | 0.80 | 21 | % | |||||||||||||||
| General and administrative | $ | 2.10 | $ | 1.83 | $ | 0.27 | 15 | % | |||||||||||||||
Nine Months Ended September 30, 2026 as Compared to Nine Months Ended September 30, 2025
Lease operating. The increase in lease operating expense was primarily attributable to the increased number of wells being operated by us and other operators (where we own a working interest).
Transportation and processing. The increase in transportation and processing expenses was primarily due to a change in the mix of revenue contracts between the periods.
Midstream operating. The increase in midstream operating expense was primarily attributable to a $29.6 million increase in pipeline operation expenses as a result of increased inlet connections and a $20.2 million increase in plant processing expenses as a result of increased gas gathering and processing volumes, as well as the Cardinal Acquisition.
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Purchased natural gas. The decrease in purchased natural gas expense was primarily due to a decline of approximately 291% in average Waha pricing, partially offset by a 85% increase in volumes purchased due to the weaker market pricing.
Depletion, depreciation and amortization. The increase in depletion, depreciation and amortization expense was primarily a result of the 6% increase in our total oil equivalent production and the addition of $248.1 million of proved reserves to the full cost pool as a result of the BLM Acquisition.
Taxes other than income. The increase in taxes other than income was primarily due to a $59.2 million increase in production taxes as a result of the increase in oil revenues, partially offset by the decrease in natural gas revenues.
Accretion of asset retirement obligations. The increase in accretion of asset retirement obligations was primarily due to an increase in estimated future costs.
General and administrative. The increase in general and administrative expense was largely attributable to a $13.4 million increase in employee compensation costs, as a result of increased headcount and a $5.5 million increase in stock-based compensation expense primarily associated with our cash-settled stock awards, the values of which are remeasured at each reporting period. Additionally, the increase in general and administrative expense was due to approximately $4.1 million in transaction costs associated with the Cardinal Acquisition, a $1.9 million increase in rent expense, a $1.3 million increase in director and officer insurance and $0.8 million in transaction costs associated with the Paloma Acquisition. These increases were partially offset by a $3.5 million increase in capitalized general and administrative expenses.
Interest expense. The increase in interest expense for the nine months ended September 30, 2026 compared to the nine months ended September 30, 2025 was primarily due to a $234.3 million increase in average debt outstanding under the Credit Agreement, a $227.5 million increase in average debt outstanding under the San Mateo Revolving Credit Facility and a $189.6 million increase in the weighted average of senior notes outstanding between the periods, as well as the new $650.0 million San Mateo Term Loan (see “—Liquidity and Capital Resources” below for further discussion). These increases were partially offset by lower interest rates.
Loss on debt extinguishment. In connection with the 2028 Notes Tender Offer and 2028 Notes Redemption, both of which as defined in “—Liquidity and Capital Resources” below, we incurred a loss on debt extinguishment of $15.6 million, including a $9.7 million cash prepayment premium and a $5.9 million write-off of remaining unamortized deferred issuance costs and discounts.
Income tax provision. The decreases in the current, deferred and total income tax provisions were primarily the result of lower income before income taxes. Our effective income tax rate of 26% for the nine months ended September 30, 2026 differed from the U.S. federal statutory rate primarily due to state taxes in New Mexico and the impact of permanent differences between book and tax income recognized discretely in the current period.
Liquidity and Capital Resources
Our primary use of capital has been, and we expect will continue to be during the remainder of 2026 and for the foreseeable future, for the acquisition, exploration and development of oil and natural gas properties and for midstream investments. We expect to fund our 2026 capital expenditures through a combination of cash on hand, operating cash flows and performance incentives paid to us by Five Point or its affiliates. If capital expenditures were to exceed these sources of cash during the remainder of 2026, we expect to fund any such excess capital expenditures, including for significant acquisitions, through borrowings under our secured revolving credit facility (the “Credit Agreement”) or the San Mateo Revolving 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.
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The table below reflects our sources and availability of liquidity at September 30, 2026.
| (In thousands) | Total Balance | Availability | |||||||||||||||
| Cash | $ | 11,756 | $ | 11,756 | |||||||||||||
| Credit Agreement | $ | 951,000 | $ | 1,745,941 | (1) | ||||||||||||
| San Mateo Revolving Credit Facility | $ | 1,002,000 | $ | 75,132 | (2) | ||||||||||||
| San Mateo Term Loan | $ | 650,000 | $ | — | |||||||||||||
6.500% senior notes due 2032 (the “2032 Notes”) | $ | 900,000 | (3) | ||||||||||||||
6.250% senior notes due 2033 (the “2033 Notes”) | $ | 750,000 | (3) | ||||||||||||||
| 6.000% senior notes due 2034 (the “2034 Notes”) | $ | 750,000 | (3) | ||||||||||||||
(1)Reduced by approximately $53.1 million in outstanding letters of credit issued pursuant to the Credit Agreement.
(2)Reduced by approximately $22.9 million in outstanding letters of credit issued pursuant to the San Mateo Revolving Credit Facility.
(3)We believe we have access to additional financing and refinancing, if needed, although we can make no assurances as to the form or terms of such financing.
In March 2026, we completed the repurchase of an aggregate principal amount of $419.8 million of the $500.0 million of outstanding senior notes due 2028 (the “2028 Notes”) as part of our cash tender offer announced on February 26, 2026 (the “2028 Notes Tender Offer”). Additionally, in March 2026, we irrevocably deposited funds with the trustee to redeem the remaining aggregate principal amount of $80.2 million of 2028 Notes outstanding on April 15, 2026 (the “2028 Notes Redemption”), and as a result of such deposit, to satisfy and discharge our obligations under the indenture governing the 2028 Notes.
Additionally, in March 2026, we completed the sale of $750.0 million in aggregate principal amount of our 2034 Notes. We used the net proceeds from the sale of the 2034 Notes (the “2034 Notes Offering”) of $737.1 million, after deducting initial purchasers’ discounts and estimated offering expenses, to fund the 2028 Notes Tender Offer and 2028 Notes Redemption and for general corporate purposes.
In June 2026, in connection with the regularly scheduled May 1 redetermination, the borrowing base of the Credit Agreement was reaffirmed at $3.25 billion. Additionally, we elected to, and the lenders agreed to, increase the borrowing commitments from $2.25 billion to $2.75 billion.
The BLM Acquisition and the Paloma Acquisition were each funded through cash on hand and borrowings under our Credit Agreement, for which the elected commitment level was increased to $2.75 billion as discussed above.
Between September 30, 2026 and November 3, 2026, our borrowings increased $1.30 billion under the Credit Agreement primarily in connection with the Paloma Acquisition, and at November 3, 2026, we had $2.25 billion in borrowings outstanding under the Credit Agreement. We expect to repay between $350 and $400 million in borrowings under the Credit Agreement based on market conditions as of November 3, 2026, funded by free cash flow generation, in the fourth quarter of 2026 following the closing of the Paloma Acquisition, of which $150 million has been repaid as of November 3, 2026.
In connection with the Cardinal Acquisition, on July 31, 2026, San Mateo amended the San Mateo Credit Facility (as defined in Note 6, Debt) to include a $650.0 million incremental senior secured term loan (the “San Mateo Term Loan”), and fully drew on that term loan on the same date. In addition to the San Mateo Term Loan, the Cardinal Acquisition was funded through capital contributions by Matador and Five Point to San Mateo of $51.0 million and $49.0 million, respectively, and cash on hand. As of September 30, 2026, the San Mateo Term Loan is due within twelve months and has therefore been presented as a current liability in our interim unaudited condensed consolidated balance sheet. San Mateo’s management is evaluating the refinancing of the San Mateo Term Loan and presently believes the measures being taken will enable San Mateo to successfully refinance the balance on a long-term basis prior to its maturity, although no assurance can be given. In the absence of being able to refinance the San Mateo Term Loan on a long-term basis, San Mateo believes it could satisfy the obligation through a combination of cash on hand, cash flows from operations, borrowings under the San Mateo Revolving Credit Facility (as defined in Note 6, Debt) and contributions from its members.
See Note 6, Debt, for further details of the debt transactions.
As further described in the Annual Report, we maintain a share repurchase program (the “Share Repurchase Program”) authorizing the repurchase of up to $400.0 million of common stock. During the three and nine months ended September 30, 2026, we repurchased 253,603 and 496,305 shares of common stock, respectively, under the Share Repurchase Program at a weighted average price of $47.64 and $48.25 per common share, respectively, for a total cost of $12.1 million and $24.0 million, respectively.
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Matador’s Board of Directors (the “Board”) declared and paid quarterly cash dividends of $0.375 per share of common stock in each of the first, second and third quarters of 2026. On October 21, 2026, the Board amended our dividend policy to increase the quarterly dividend to $0.4375 per share of common stock for future dividend payments and also declared a quarterly cash dividend of $0.4375 per share of common stock payable on December 4, 2026 to shareholders of record as of November 10, 2026.
We expect that development of our Delaware Basin assets will be the primary focus of our operations and capital expenditures for the remainder of 2026. 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 November 3, 2026, we adjusted our estimated drilling, completing and equipping (“D/C/E”) capital expenditures for 2026 to a range of $1.50 to $1.54 billion from a range of $1.48 to $1.56 billion, which includes our expected D/C/E capital expenditures on acreage acquired in the BLM Acquisition and Paloma Acquisition. Substantially all of these 2026 estimated capital expenditures are expected to be allocated to (i) the further delineation and development of our leasehold position and (ii) our participation in certain non-operated well opportunities. Our Delaware Basin operated drilling program for the remainder of 2026 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. At November 3, 2026, we have established an acreage position in what we believe is the core of the Woodford play of approximately 50,000 net acres, acquired at an average cost of $4,000 per acre across more than 400 separate transactions, including acquisitions in the fourth quarter of 2026. We drilled our first horizontal well in the Woodford formation during 2026 and plan to begin drilling two additional wells in the fourth quarter of 2026 to further delineate the play as we transition into an active 2027 development schedule.
On November 3, 2026, we also adjusted our estimated midstream capital expenditures for 2026 to a range of $170.0 to $190.0 million from a range of $145.0 to $165.0 million, which includes our proportionate share of San Mateo’s estimated 2026 capital expenditures as well as the estimated 2026 capital expenditures for other wholly-owned midstream projects. Substantially all of these 2026 estimated capital expenditures are expected to be allocated to the construction, installation and maintenance of midstream assets. More specifically, the $25 million increase in estimated midstream capital expenditures is to fund initial work on a new natural gas processing train at San Mateo’s Marlan Plant complex and associated gathering assets. This expansion is underwritten by a new agreement with a large Delaware Basin producer expected to add meaningful long-term volumes across San Mateo’s existing gathering and processing footprint as well as anticipated increased volumes from Matador production estimates.
We intend to continue evaluating the opportunistic acquisition of producing properties, acreage and mineral interests and midstream assets, principally in the Delaware Basin. 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 capital expenditures with any degree of certainty; therefore, we have not provided estimated capital expenditures related to acquiring producing properties, acreage and mineral interests and midstream assets for 2026.
As we have done in recent years, we may divest portions of our non-core assets as well as consider monetizing other assets, such as certain midstream assets and mineral and royalty interests, as value-creating opportunities arise. Divestitures and other types of monetizations are difficult to estimate with any degree of certainty. Therefore, we have not provided estimated proceeds related to divestitures or monetizations for 2026.
Our 2026 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.
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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 2026 is expected to come from producing wells and development activities on currently proved properties in the Delaware Basin. 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 2026 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 9, Derivative Financial Instruments, in this Quarterly Report for a summary of our open derivative financial instruments.
Cash Flows
Our unaudited cash flows for the nine months ended September 30, 2026 and 2025 are presented below:
| Nine Months Ended September 30, | |||||||||||||||||||||||
| (In thousands) | 2026 | 2025 | $ Change | % Change | |||||||||||||||||||
| Net cash provided by operating activities | $ | 2,002,106 | $ | 1,950,566 | $ | 51,540 | 3 | % | |||||||||||||||
| Net cash used in investing activities | (3,384,997) | (1,569,635) | (1,815,362) | 116 | % | ||||||||||||||||||
| Net cash provided by (used in) financing activities | 1,373,527 | (379,286) | 1,752,813 | (462) | % | ||||||||||||||||||
| Net change in cash and restricted cash | $ | (9,364) | $ | 1,645 | $ | (11,009) | (669) | % | |||||||||||||||
Adjusted EBITDA attributable to Matador Resources Company shareholders(1) | $ | 2,096,455 | $ | 1,804,983 | $ | 291,472 | 16 | % | |||||||||||||||
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(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
Excluding changes in operating assets and liabilities, net cash provided by operating activities increased $255.7 million to $2.03 billion for the nine months ended September 30, 2026 from $1.77 billion for the nine months ended September 30, 2025. This increase was primarily attributable to higher realized oil prices and increased oil and natural gas production for the nine months ended September 30, 2026, as compared to the nine months ended September 30, 2025, partially offset by lower realized natural gas prices. Changes in our operating assets and liabilities between the periods resulted in a $204.1 million decrease in net cash provided by operating activities for the nine months ended September 30, 2026, as compared to the nine months ended September 30, 2025.
Net Cash Used in Investing Activities
The increase in net cash used in investing activities between the periods was primarily due to (i) a $1.02 billion increase in expenditures related to the acquisition of oil and natural gas properties, primarily the BLM Acquisition, (ii) $761.0 million in expenditures related to the Cardinal Acquisition, (iii) an $84.7 million increase in D/C/E capital expenditures primarily attributable to our operated and non-operated drilling, completion and equipping activities in the Delaware Basin, (iv) a $63.8 million cash deposit related to the Paloma Acquisition and (v) a $21.6 million decrease in proceeds from the sale of assets; partially offset by a $141.4 million decrease in midstream capital expenditures.
Net Cash Provided by (Used in) Financing Activities
The decrease in net cash used in financing activities between the periods was primarily due to (i) an $863.5 million increase in net borrowings under the Credit Agreement, (ii) $737.1 million of net proceeds received from the 2034 Notes Offering, (iii) $650.0 million of proceeds from the San Mateo Term Loan, (iv) a $49.0 million contribution from non-controlling interest owners of less-than-wholly-owned subsidiaries in connection with the Cardinal Acquisition, (v) a $26.5 million decrease in repurchases of common stock, (vi) $23.3 million of net proceeds from a sale-leaseback financing obligation, (vii) an $8.3 million decrease in distributions to non-controlling interest owners and (viii) a $7.9 million increase in performance incentives received from Five Point; partially offset by (i) $509.7 million used to repurchase the principal amount of the 2028 Notes, (ii) an $81.0 million decrease in net borrowings under the San Mateo Revolving Credit Facility and (iii) a $22.7 million increase in dividends paid.
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See Note 6, Debt, in this Quarterly Report for a summary of our debt, including the Credit Agreement, the San Mateo Revolving Credit Facility, the San Mateo Term Loan, the 2032 Notes, the 2033 Notes and the 2034 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, unrealized derivative gains and losses, non-recurring transaction costs for certain acquisitions, non-cash stock-based compensation expense, loss on debt extinguishment, net gain or loss on asset sales and impairments and certain other non-cash items. 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 useful 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.
| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| (In thousands) | 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||
| Unaudited Adjusted EBITDA Reconciliation to Net Income | |||||||||||||||||||||||
| Net income attributable to Matador Resources Company shareholders | $ | 172,120 | $ | 176,364 | $ | 526,900 | $ | 566,674 | |||||||||||||||
| Net income attributable to non-controlling interest in subsidiaries | 22,979 | 24,260 | 66,033 | 78,556 | |||||||||||||||||||
| Net income | 195,099 | 200,624 | 592,933 | 645,230 | |||||||||||||||||||
| Interest expense | 79,982 | 50,641 | 192,326 | 153,475 | |||||||||||||||||||
| Total income tax provision | 81,548 | 59,128 | 187,701 | 198,511 | |||||||||||||||||||
| Depletion, depreciation and amortization | 342,961 | 305,354 | 950,809 | 889,847 | |||||||||||||||||||
| Accretion of asset retirement obligations | 3,995 | 2,148 | 8,615 | 5,642 | |||||||||||||||||||
| Unrealized loss (gain) on derivatives | 67,727 | (19,952) | 237,744 | 12,290 | |||||||||||||||||||
| Non-cash stock-based compensation expense | 6,912 | 6,181 | 17,529 | 14,641 | |||||||||||||||||||
| Loss on debt extinguishment | — | — | 15,587 | — | |||||||||||||||||||
| Loss on asset sales | — | 589 | 578 | 589 | |||||||||||||||||||
| Other non-recurring expense (income) | 6,115 | (1,866) | 10,339 | (7,452) | |||||||||||||||||||
| Consolidated Adjusted EBITDA | 784,339 | 602,847 | 2,214,161 | 1,912,773 | |||||||||||||||||||
| Adjusted EBITDA attributable to non-controlling interest in subsidiaries | (46,062) | (36,332) | (117,706) | (107,790) | |||||||||||||||||||
| Adjusted EBITDA attributable to Matador Resources Company shareholders | $ | 738,277 | $ | 566,515 | $ | 2,096,455 | $ | 1,804,983 | |||||||||||||||
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| Three Months Ended September 30, | Nine Months Ended September 30, | ||||||||||||||||||||||
| (In thousands) | 2026 | 2025 | 2026 | 2025 | |||||||||||||||||||
| Unaudited Adjusted EBITDA Reconciliation to Net Cash Provided by Operating Activities | |||||||||||||||||||||||
| Net cash provided by operating activities | $ | 594,432 | $ | 721,660 | $ | 2,002,106 | $ | 1,950,566 | |||||||||||||||
| Net change in operating assets and liabilities | 107,874 | (123,282) | 27,019 | (177,127) | |||||||||||||||||||
| Interest expense, net of non-cash portion | 75,673 | 46,948 | 180,949 | 142,446 | |||||||||||||||||||
| Current income tax provision | 578 | (39,335) | 804 | 6,735 | |||||||||||||||||||
| Other non-cash and non-recurring expense (income) | 5,782 | (3,144) | 3,283 | (9,847) | |||||||||||||||||||
| Adjusted EBITDA attributable to non-controlling interest in subsidiaries | (46,062) | (36,332) | (117,706) | (107,790) | |||||||||||||||||||
| Adjusted EBITDA attributable to Matador Resources Company shareholders | $ | 738,277 | $ | 566,515 | $ | 2,096,455 | $ | 1,804,983 | |||||||||||||||
Net income attributable to Matador shareholders decreased $4.2 million for the three months ended September 30, 2026, as compared to the three months ended September 30, 2025. The decrease in net income attributable to Matador shareholders primarily resulted from (i) a $251.8 million decrease in net gain on realized and unrealized derivatives, (ii) a $37.6 million increase in depletion, depreciation and amortization expense, (iii) a $33.1 million increase in midstream operating expenses, (iv) a $32.0 million increase in taxes other than income, (v) a $29.3 million increase in interest expense, (vi) a $22.4 million increase in the income tax provision, (vii) a $15.9 million increase in lease operating expenses and (viii) a $7.9 million increase in general and administrative expenses. These decreases were partially offset by (i) higher realized oil and natural gas prices, (ii) increased oil and natural gas production, (iii) a $12.5 million increase in third-party midstream services revenues and (iv) a $7.8 million increase in net sales of purchased natural gas. See “—Results of Operations” for the three months ended September 30, 2026 as compared to the three months ended September 30, 2025 above for further discussion and analysis of these individual changes within net income.
Net income attributable to Matador shareholders decreased $39.8 million for the nine months ended September 30, 2026, as compared to the nine months ended September 30, 2025. The decrease in net income attributable to Matador shareholders primarily resulted from (i) lower realized natural gas prices, (ii) a $486.2 million decrease in net gain on realized and unrealized derivatives, (iii) a $60.6 million increase in taxes other than income, (iv) a $61.0 million increase in depletion, depreciation and amortization expense, (v) a $52.6 million increase in midstream operating expenses, (vi) a $38.9 million increase in interest expense, (vii) a $22.2 million increase in general and administrative expenses, (viii) a $20.7 million increase in lease operating expenses and (ix) a $15.6 million loss on debt extinguishment. These decreases were partially offset by (i) higher realized oil prices, (ii) increased oil and natural gas production, (iii) an $85.8 million increase in net sales of purchased natural gas, (iv) a $23.7 million increase in third-party midstream services revenues and (v) a $10.8 million decrease in the income tax provision. See “—Results of Operations” for the nine months ended September 30, 2026, as compared to the nine months ended September 30, 2025, above for further discussion and analysis of these individual changes within net income.
Adjusted EBITDA, a non-GAAP financial measure, increased $171.8 million for the three months ended September 30, 2026 compared to the three months ended September 30, 2025. This increase was primarily attributable to (i) higher realized oil and natural gas prices, (ii) increased oil and natural gas production, (iii) a $12.5 million increase in third-party midstream services revenues and (iv) a $7.8 million increase in net sales of purchased natural gas. These increases were partially offset by (i) a $164.1 million decrease in realized gain on derivatives, (ii) a $33.1 million increase in midstream operating expenses, (iii) a $32.0 million increase in taxes other than income, (iv) a $15.9 million increase in lease operating expenses and (v) a $7.9 million increase in general and administrative expenses.
Adjusted EBITDA, a non-GAAP financial measure, increased $291.5 million for the nine months ended September 30, 2026 compared to the nine months ended September 30, 2025. This increase was primarily attributable to (i) higher realized oil prices, (ii) increased oil and natural gas production, (iii) an $85.8 million increase in net sales of purchased natural gas and (iv) a $23.7 million increase in third-party midstream services revenues. These increases were partially offset by (i) lower realized natural gas prices, (ii) a $260.8 million decrease in realized gain on derivatives, (iii) a $60.6 million increase in taxes other than income, (iv) a $52.6 million increase in midstream operating expenses, (v) a $22.2 million increase in general and administrative expenses and (vi) a $20.7 million increase in lease operating expenses.
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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, 2026, 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 11, Commitments and Contingencies, 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, 2026:
| Payments Due by Period | |||||||||||||||||||||||||||||
| (In thousands) | Total | Less Than 1 Year | 1 - 3 Years | 3 - 5 Years | More Than 5 Years | ||||||||||||||||||||||||
| Contractual Obligations | |||||||||||||||||||||||||||||
Borrowings, including letters of credit(1) | $ | 2,028,927 | $ | — | $ | 1,004,059 | $ | 1,024,868 | $ | — | |||||||||||||||||||
San Mateo Term Loan under San Mateo Credit Facility(2) | 650,000 | 650,000 | — | — | — | ||||||||||||||||||||||||
Senior unsecured notes(3) | 2,400,000 | — | — | — | 2,400,000 | ||||||||||||||||||||||||
| Office leases | 101,897 | 5,999 | 12,961 | 13,752 | 69,185 | ||||||||||||||||||||||||
Non-operated drilling commitments(4) | 48,582 | 48,582 | — | — | — | ||||||||||||||||||||||||
Drilling rig contracts(5) | 21,174 | 21,174 | — | — | — | ||||||||||||||||||||||||
Asset retirement obligations(6) | 263,091 | 4,469 | 18,416 | 3,137 | 237,069 | ||||||||||||||||||||||||
Transportation, gathering, processing and disposal agreements with non-affiliates(7) | 2,497,074 | 325,207 | 547,119 | 458,835 | 1,165,913 | ||||||||||||||||||||||||
Transportation, gathering, processing and disposal agreements with San Mateo(8) | 590,088 | 76,127 | 206,860 | 204,659 | 102,442 | ||||||||||||||||||||||||
Midstream contracts(9) | 111,378 | 55,068 | 56,310 | — | — | ||||||||||||||||||||||||
| Seismic data contracts | 10,500 | 10,500 | — | — | — | ||||||||||||||||||||||||
| Total contractual cash obligations | $ | 8,722,711 | $ | 1,197,126 | $ | 1,845,725 | $ | 1,705,251 | $ | 3,974,609 | |||||||||||||||||||
__________________
(1)The amounts included in the table above represent principal maturities only. At September 30, 2026, we had $951.0 million in borrowings outstanding under the Credit Agreement and approximately $53.1 million in outstanding letters of credit issued pursuant to the Credit Agreement. The outstanding borrowings under the Credit Agreement mature on March 22, 2029. At September 30, 2026, San Mateo had $1.00 billion of borrowings outstanding under the San Mateo Revolving Credit Facility and approximately $22.9 million in outstanding letters of credit issued pursuant to the San Mateo Revolving Credit Facility. The outstanding borrowings under the San Mateo Revolving Credit Facility mature on November 26, 2029. Assuming the amounts outstanding and interest rates of 5.75% and 6.91%, respectively, for the Credit Agreement and the San Mateo Revolving Credit Facility at September 30, 2026, the interest expense for such facilities is expected to be approximately $55.4 million and $70.2 million, respectively, each year until maturity.
(2)The amount included in the table above represents principal only. The borrowings outstanding under the San Mateo Term Loan mature on July 30, 2027. Assuming the amount outstanding and interest rate of 6.91% at September 30, 2026, the interest expense for the San Mateo Term Loan is expected to be approximately $37.8 million until maturity.
(3)The amounts included in the table above represent principal maturities only. Interest expense on the $900.0 million of outstanding 2032 Notes as of September 30, 2026 is expected to be approximately $58.5 million each year until maturity. Interest expense on the $750.0 million of outstanding 2033 Notes as of September 30, 2026 is expected to be approximately $46.9 million each year until maturity. Interest expense on the $750.0 million of outstanding 2034 Notes as of September 30, 2026 is expected to be approximately $45.0 million each year until maturity.
(4)At September 30, 2026, we had outstanding commitments to participate in the drilling and completion of various non-operated wells.
(5)We do not own or operate our own drilling rigs, but instead we enter into contracts with third parties for such drilling rigs.
(6)The amounts included in the table above represent discounted cash flow estimates for future asset retirement obligations at September 30, 2026.
(7)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
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minimum volume commitments, including contracts related to firm transportation on Energy Transfer’s Hugh Brinson Pipeline. If we do not meet the minimum volume commitments under these agreements, we would be required to pay certain deficiency fees. See Note 11, Commitments and Contingencies, in this Quarterly Report for more information about these contractual commitments.
(8)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. We also dedicated to San Mateo certain of our current and future leasehold interests in the Ranger and Antelope Ridge asset areas pursuant to 15-year, fixed-fee natural gas gathering, compression, treating and processing agreements with San Mateo, whereby San Mateo will gather, compress, treat and process natural gas produced from our operated wells in northern Lea County, New Mexico. See Note 11, Commitments and Contingencies, in this Quarterly Report for more information about these contractual commitments.
(9)At September 30, 2026, we had outstanding commitments for capital expenditures to be utilized in San Mateo’s 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 current administration and Congress have altered, and may continue to alter, our current regulatory framework and may 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, including ongoing military conflicts between Russia and Ukraine and in the Middle East, political instability, particularly in China and in the Middle East, geopolitical tensions involving Iran (including the potential for stricter U.S. sanctions on Iranian oil exports, regional conflicts and potential disruptions to shipping routes in the Strait of Hormuz), the actions of Organization of Petroleum Exporting Countries, Russia and certain other oil-exporting countries, 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, the payment of cash dividends, if any, and the repurchase of common stock, 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 higher in the third quarter of 2026, as compared to the third quarter of 2025. For the three months ended September 30, 2026, oil prices averaged $85.68 per Bbl, ranging from a low of $68.55 per Bbl in early July to a high of $105.83 per Bbl in mid-September, based upon the West Texas Intermediate (“WTI”) oil futures contract price for the earliest delivery date. Oil prices averaged $64.97 per Bbl for the three months ended September 30, 2025. We realized a weighted average oil price of $87.25 per Bbl ($74.84 per Bbl with realized losses from oil derivatives) for our oil production for the three months ended September 30, 2026, as compared to $64.91 per Bbl (with no realized gains or losses from oil derivatives) for our oil production for the three months ended September 30, 2025. Oil prices have remained volatile since September 30, 2026. At November 3, 2026, the WTI oil futures contract for the earliest delivery date had increased from the average price for the third quarter of 2026 of $85.68 per Bbl, settling at $96.09 per Bbl.
Natural gas prices were lower in the third quarter of 2026, as compared to the third quarter of 2025. For the three months ended September 30, 2026, natural gas prices averaged $2.89 per MMBtu, ranging from a low of $2.64 per MMBtu in early August to a high of $3.30 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 $3.07 per MMBtu for the three months ended September 30, 2025. We report production volumes in two streams, oil and natural gas (which includes both dry gas and NGLs). We realized a weighted average natural gas price of $2.99 per Mcf ($2.81 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, 2026, as compared to $1.95 per Mcf ($2.03 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, 2025. 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 November 3, 2026, 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 2026 of $2.89 per MMBtu to $2.90 per MMBtu.
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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. Historically, 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. At September 30, 2026, we have significantly reduced our exposure to prices at the Waha hub, particularly for our operated natural gas production, as we secured 500,000 MMBtu per day of firm natural gas transportation on Energy Transfer’s new Hugh Brinson pipeline, which began flowing natural gas during the second quarter of 2026 and was fully in-service as of September 1, 2026. The Hugh Brinson pipeline provides Matador access to Henry Hub markets along the Louisiana Gulf Coast and to other opportunities such as liquefied natural gas (LNG) plants and export terminals along this pipeline route that have historically experienced more favorable pricing to the Waha hub.
Certain volumes of our Delaware Basin natural gas production have historically been, and could again be, exposed to the Waha-Henry Hub basis differential, which has also been highly volatile in recent years. In recent years, concerns about natural gas pipeline takeaway capacity out of the Delaware Basin began to increase and as a result, the Waha-Henry Hub basis differential began to widen. The Waha-Henry Hub basis differential averaged ($4.38) per MMBtu for the nine months ended September 30, 2026. Between September 30, 2026 and November 3, 2026, this natural gas price differential narrowed to approximately ($1.29) per MMBtu. A significant portion of our Delaware Basin natural gas production, however, is sold at either Houston Ship Channel or Henry Hub pricing, subsequent to the recent commissioning of the Hugh Brinson pipeline, and is not exposed to Waha pricing. 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 3% of our reported natural gas production for the nine months ended September 30, 2026 was attributable to the Haynesville shale play, which is not exposed to Waha pricing. In addition, 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 2026, we recorded a net loss of $374.3 million related to our oil costless collars, resulting primarily from oil prices that were above the ceiling of certain of our oil costless collar contracts and the deferred call premiums on certain of our purchased oil call contracts. This loss was partially offset by a net gain of $127.1 million related to our natural gas costless collar and swap contracts, resulting primarily from natural gas prices that were below the floor of our natural gas costless collar contracts, natural gas prices that were below the fixed prices of certain of our natural gas swap contracts and natural gas basis differentials that were below the fixed prices of certain of our natural gas basis differential swap contracts.
We have at times, including in 2025 and 2026, 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 have experienced historically, including in 2025 and 2026, we may again 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 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, tariffs and trade restrictions 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.
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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.
Regulatory Matters
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.
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, 2025, 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.
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. At times we have also purchased calls to mitigate potential losses associated with our costless collar contracts in a rising oil price environment.
We record all derivative financial instruments at fair value, which is determined using purchase and sale information available for similarly traded securities. Additionally, we have considered the credit standing of the counterparties in determining the fair value of our derivative financial instruments.
At September 30, 2026, we had various costless collar contracts open and in place to mitigate our exposure to oil and natural gas price volatility, each with an established price floor and ceiling. At September 30, 2026, we had oil price call contracts open and in place to mitigate our exposure to oil price volatility with an established strike price. At September 30, 2026, 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. We had no open contracts associated with NGL prices at September 30, 2026.
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See Note 9, Derivative Financial Instruments, 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, 2026 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, 2026, 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, 2026, there were no material changes regarding the legal proceedings we have disclosed in “Part I—Item 3. Legal Proceedings” in the Annual Report or in “Part II—Item 1. Legal Proceedings” in our Quarterly Report on Form 10-Q for the quarter ended June 30, 2026.
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. During the three months ended September 30, 2026, there were no material changes to the risk factors we have disclosed in the Annual Report.
Item 2. Repurchase of Equity by the Company or Affiliates
The following table contains information about our acquisition of equity securities during the quarter ended September 30, 2026:
| Period | Total Number of Shares Purchased(1)(2) | Average Price Paid Per Share | Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs(2) | Maximum Number (or Approximate Dollar Value in thousands) of Shares that May Yet Be Purchased under the Plans or Programs(2) | ||||||||||||||||||||||
| July 1, 2026 to July 31, 2026 | 200,729 | $ | 47.65 | 200,000 | $ | 322,751 | ||||||||||||||||||||
| August 1, 2026 to August 31, 2026 | 53,603 | $ | 47.66 | 53,603 | $ | 320,195 | ||||||||||||||||||||
| September 1, 2026 to September 30, 2026 | 51 | $ | 61.05 | — | $ | 320,195 | ||||||||||||||||||||
| Total | 254,383 | $ | 47.66 | 253,603 | ||||||||||||||||||||||
_________________
(1)During the third quarter of 2026, the Company re-acquired 780 shares of common stock from certain employees in order to satisfy the employees’ tax liability in connection with the vesting of restricted stock.
(2)In April 2025, the Board authorized the Share Repurchase Program covering up to $400.0 million of common stock. During the third quarter of 2026, we repurchased 253,603 shares of our common stock under the Share Repurchase Program at a weighted average price of $47.64 per common share for a total cost of $12.1 million.
Item 5. Other Information
Insider Trading Plans
During the three months ended September 30, 2026, no director or officer (as defined in Rule 16a-1(f) under the Exchange Act) of the Company adopted terminated
49
Item 6. Exhibits
| Exhibit Number | Description | ||||||||||
| 2.1* | |||||||||||
| 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, 2026, formatted in Inline XBRL (Inline eXtensible Business Reporting Language): (i) the Condensed Consolidated Balance Sheets - Unaudited, (ii) the Condensed Consolidated Statements of Operations - 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). | ||||||||||
| 104 | Cover 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 Company agrees to furnish supplementally to the SEC upon request; provided, however, that the Company 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. | ||||||||||
50
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: November 6, 2026 | By: | /s/ Joseph Wm. Foran | |||||||||
| Joseph Wm. Foran | |||||||||||
| Chairman and Chief Executive Officer | |||||||||||
| Date: November 6, 2026 | By: | /s/ Christopher P. Calvert | |||||||||
| Christopher P. Calvert | |||||||||||
| Executive Vice President and Chief Financial Officer | |||||||||||
51
Exhibit 4.1
MATADOR RESOURCES COMPANY
FIRST SUPPLEMENTAL INDENTURE
(6.000% Senior Notes due 2034)
FIRST SUPPLEMENTAL INDENTURE (this “Supplemental Indenture”), dated as of November 3, 2026, among MRC Ranger, LLC, a Delaware limited liability company, Paloma Permian, LLC, a Delaware limited liability company, Paloma Permian AssetCo, LLC, a Delaware limited liability company and Paloma Permian Nominee Corporation, a Delaware corporation (each a “New Guarantor” and collectively the “New Guarantors”), each a subsidiary of Matador Resources Company, a Texas corporation (the “Company”), the existing Guarantors (as defined in the Indenture referred to herein), the Company and U.S. Bank Trust Company, National Association, as trustee under the Indenture referred to herein (the “Trustee”). The New Guarantors and the existing Guarantors are sometimes referred to collectively herein as the “Guarantors,” or individually as a “Guarantor.”
W I T N E S S E T H
WHEREAS, the Company and the existing Guarantors have heretofore executed and delivered to the Trustee an indenture (the “Indenture”), dated as of March 5, 2026, relating to the 6.000% Senior Notes due 2034 (the “Securities”) of the Company;
WHEREAS, Section 4.9 of the Indenture in certain circumstances requires the Company to cause a newly acquired or created Restricted Subsidiary (i) to become a Guarantor by executing a supplemental indenture and (ii) to deliver an Opinion of Counsel to the Trustee as provided in such Section; and
WHEREAS, pursuant to Section 9.1 of the Indenture, the Company, the Guarantors and the Trustee are authorized to execute and deliver this Supplemental Indenture to amend or supplement the Indenture without the consent of any Holder;
NOW THEREFORE, to comply with the provisions of the Indenture and in consideration of the foregoing and for other good and valuable consideration, the receipt of which is hereby acknowledged, the New Guarantors, the other Guarantors, the Company and the Trustee mutually covenant and agree for the equal and ratable benefit of the Holders of the Securities as follows:
1. Capitalized Terms. Capitalized terms used herein without definition shall have the meanings assigned to them in the Indenture.
2. Agreement to Guarantee. Each New Guarantor hereby agrees, jointly and severally, with all other Guarantors, to unconditionally Guarantee to each Holder and to the Trustee the Obligations, to the extent set forth in the Indenture and subject to the provisions in the Indenture. The obligations of the Guarantors to the Holders of Securities and to the Trustee pursuant to the Subsidiary Guarantees and the Indenture are expressly set forth in Article X of
the Indenture and reference is hereby made to the Indenture for the precise terms of the Subsidiary Guarantees.
3. Execution and Delivery. Each New Guarantor agrees that its Subsidiary Guarantee shall remain in full force and effect notwithstanding any failure to endorse on each Security a notation of such Subsidiary Guarantee.
4. NEW YORK LAW TO GOVERN. THE LAWS OF THE STATE OF NEW YORK SHALL GOVERN AND BE USED TO CONSTRUE AND ENFORCE THIS SUPPLEMENTAL INDENTURE.
5. Counterparts. The parties may sign any number of copies of this Supplemental Indenture. Each signed copy shall be an original, but all of them together represent the same agreement. This Supplemental Indenture may be executed in multiple counterparts which, when taken together, shall constitute one instrument. This Supplemental Indenture (or any documents executed in connection with this Supplemental Indenture) shall be valid, binding and enforceable against a party when executed and delivered by an authorized individual on behalf of the party by means of (i) an original manual signature, (ii) a faxed, scanned, or photocopied manual signature, or (iii) any other electronic signature permitted by the federal Electronic Signatures in Global and National Commerce Act, state enactments of Uniform Electronic Transactions Act, and/or any relevant electronic signature law, including any relevant provisions of the Uniform Commercial Code (collectively, “Signature Law”), in each case to the extent applicable. Each faxed, scanned or photocopied manual signature, or other electronic signature, shall for all purposes have the same validity, legal effect, and admissibility in evidence as an original manual signature. Each party hereto shall be entitled to conclusively rely upon, and shall have no liability with respect to, any faxed, scanned, or photocopied manual signature, or other electronic signature, of any other party and shall have no duty to investigate, confirm or otherwise verify the validity or authenticity thereof. For the avoidance of doubt, original manual signatures shall be used for the execution or indorsement of writings when required under the Uniform Commercial Code or other Signature Law due to the character or intended character of the writings.
6. Effect of Headings. The Section headings herein are for convenience only and shall not affect the construction hereof.
7. The Trustee. Except as otherwise expressly provided herein, no duties, responsibilities or liabilities are assumed, or shall be construed to be assumed, by the Trustee by reason of this Supplemental Indenture. This Supplemental Indenture is executed and accepted by the Trustee subject to all the terms and conditions set forth in the Indenture with the same force and effect as if those terms and conditions were repeated at length herein and made applicable to the Trustee with respect hereto.
[Remainder of Page Intentionally Left Blank; Signature Pages Follow]
IN WITNESS WHEREOF, the parties hereto have caused this Supplemental Indenture to be duly executed and attested, all as of the date first above written.
MATADOR RESOURCES COMPANY
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
MRC RANGER, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
PALOMA PERMIAN, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
PALOMA PERMIAN ASSETCO, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
PALOMA PERMIAN NOMINEE CORPORATION
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
[Signature Page to First Supplemental Indenture]
(6.000% Senior Notes due 2034)
DELAWARE WATER MANAGEMENT COMPANY, LLC
LONGWOOD GATHERING AND DISPOSAL SYSTEMS, LLC
LONGWOOD MIDSTREAM HOLDINGS, LLC
LONGWOOD MIDSTREAM SOUTH TEXAS, LLC
LONGWOOD MIDSTREAM SOUTHEAST, LLC
LONGWOOD MIDSTREAM DELAWARE, LLC
MATADOR PRODUCTION COMPANY
MRC ENERGY COMPANY
MRC DELAWARE RESOURCES, LLC
MRC ENERGY SOUTHEAST COMPANY, LLC
MRC ENERGY SOUTH TEXAS COMPANY, LLC
MRC PERMIAN COMPANY
MRC PERMIAN LKE COMPANY, LLC
MRC ROCKIES COMPANY
SOUTHEAST WATER MANAGEMENT COMPANY, LLC
WR PERMIAN, LLC
MRC HAT MESA, LLC
MRC TORO, LLC
MRC ROYALTIES, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
[Signature Page to First Supplemental Indenture]
(6.000% Senior Notes due 2034)
U.S. BANK TRUST COMPANY, NATIONAL ASSOCIATION, as Trustee
By: /s/ James H. Byrnes
Name: James H. Byrnes
Title: Vice President
[Signature Page to First Supplemental Indenture]
(6.000% Senior Notes due 2034)
Exhibit 4.2
MATADOR RESOURCES COMPANY
SECOND SUPPLEMENTAL INDENTURE
(6.250% Senior Notes due 2033)
SECOND SUPPLEMENTAL INDENTURE (this “Supplemental Indenture”), dated as of November 3, 2026, among MRC Ranger, LLC, a Delaware limited liability company, Paloma Permian, LLC, a Delaware limited liability company, Paloma Permian AssetCo, LLC, a Delaware limited liability company and Paloma Permian Nominee Corporation, a Delaware corporation (each a “New Guarantor” and collectively the “New Guarantors”), each a subsidiary of Matador Resources Company, a Texas corporation (the “Company”), the existing Guarantors (as defined in the Indenture referred to herein), the Company and U.S. Bank Trust Company, National Association, as trustee under the Indenture referred to herein (the “Trustee”). The New Guarantors and the existing Guarantors are sometimes referred to collectively herein as the “Guarantors,” or individually as a “Guarantor.”
W I T N E S S E T H
WHEREAS, the Company and the existing Guarantors have heretofore executed and delivered to the Trustee an indenture (as supplemented by the First Supplemental Indenture dated as of March 18, 2025, the “Indenture”), dated as of September 25, 2024, relating to the 6.250% Senior Notes due 2033 (the “Securities”) of the Company;
WHEREAS, Section 4.9 of the Indenture in certain circumstances requires the Company to cause a newly acquired or created Restricted Subsidiary (i) to become a Guarantor by executing a supplemental indenture and (ii) to deliver an Opinion of Counsel to the Trustee as provided in such Section; and
WHEREAS, pursuant to Section 9.1 of the Indenture, the Company, the Guarantors and the Trustee are authorized to execute and deliver this Supplemental Indenture to amend or supplement the Indenture without the consent of any Holder;
NOW THEREFORE, to comply with the provisions of the Indenture and in consideration of the foregoing and for other good and valuable consideration, the receipt of which is hereby acknowledged, the New Guarantors, the other Guarantors, the Company and the Trustee mutually covenant and agree for the equal and ratable benefit of the Holders of the Securities as follows:
1. Capitalized Terms. Capitalized terms used herein without definition shall have the meanings assigned to them in the Indenture.
2. Agreement to Guarantee. Each New Guarantor hereby agrees, jointly and severally, with all other Guarantors, to unconditionally Guarantee to each Holder and to the Trustee the Obligations, to the extent set forth in the Indenture and subject to the provisions in the Indenture. The obligations of the Guarantors to the Holders of Securities and to the Trustee
pursuant to the Subsidiary Guarantees and the Indenture are expressly set forth in Article X of the Indenture and reference is hereby made to the Indenture for the precise terms of the Subsidiary Guarantees.
3. Execution and Delivery. Each New Guarantor agrees that its Subsidiary Guarantee shall remain in full force and effect notwithstanding any failure to endorse on each Security a notation of such Subsidiary Guarantee.
4. NEW YORK LAW TO GOVERN. THE LAWS OF THE STATE OF NEW YORK SHALL GOVERN AND BE USED TO CONSTRUE AND ENFORCE THIS SUPPLEMENTAL INDENTURE.
5. Counterparts. The parties may sign any number of copies of this Supplemental Indenture. Each signed copy shall be an original, but all of them together represent the same agreement. This Supplemental Indenture may be executed in multiple counterparts which, when taken together, shall constitute one instrument. This Supplemental Indenture (or any documents executed in connection with this Supplemental Indenture) shall be valid, binding and enforceable against a party when executed and delivered by an authorized individual on behalf of the party by means of (i) an original manual signature, (ii) a faxed, scanned, or photocopied manual signature, or (iii) any other electronic signature permitted by the federal Electronic Signatures in Global and National Commerce Act, state enactments of Uniform Electronic Transactions Act, and/or any relevant electronic signature law, including any relevant provisions of the Uniform Commercial Code (collectively, “Signature Law”), in each case to the extent applicable. Each faxed, scanned or photocopied manual signature, or other electronic signature, shall for all purposes have the same validity, legal effect, and admissibility in evidence as an original manual signature. Each party hereto shall be entitled to conclusively rely upon, and shall have no liability with respect to, any faxed, scanned, or photocopied manual signature, or other electronic signature, of any other party and shall have no duty to investigate, confirm or otherwise verify the validity or authenticity thereof. For the avoidance of doubt, original manual signatures shall be used for the execution or indorsement of writings when required under the Uniform Commercial Code or other Signature Law due to the character or intended character of the writings.
6. Effect of Headings. The Section headings herein are for convenience only and shall not affect the construction hereof.
7. The Trustee. Except as otherwise expressly provided herein, no duties, responsibilities or liabilities are assumed, or shall be construed to be assumed, by the Trustee by reason of this Supplemental Indenture. This Supplemental Indenture is executed and accepted by the Trustee subject to all the terms and conditions set forth in the Indenture with the same force and effect as if those terms and conditions were repeated at length herein and made applicable to the Trustee with respect hereto.
[Remainder of Page Intentionally Left Blank; Signature Pages Follow]
IN WITNESS WHEREOF, the parties hereto have caused this Supplemental Indenture to be duly executed and attested, all as of the date first above written.
MATADOR RESOURCES COMPANY
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
MRC RANGER, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
PALOMA PERMIAN, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
PALOMA PERMIAN ASSETCO, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
PALOMA PERMIAN NOMINEE CORPORATION
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
[Signature Page to Second Supplemental Indenture]
(6.250% Senior Notes due 2033)
DELAWARE WATER MANAGEMENT COMPANY, LLC
LONGWOOD GATHERING AND DISPOSAL SYSTEMS, LLC
LONGWOOD MIDSTREAM HOLDINGS, LLC
LONGWOOD MIDSTREAM SOUTH TEXAS, LLC
LONGWOOD MIDSTREAM SOUTHEAST, LLC
LONGWOOD MIDSTREAM DELAWARE, LLC
MATADOR PRODUCTION COMPANY
MRC ENERGY COMPANY
MRC DELAWARE RESOURCES, LLC
MRC ENERGY SOUTHEAST COMPANY, LLC
MRC ENERGY SOUTH TEXAS COMPANY, LLC
MRC PERMIAN COMPANY
MRC PERMIAN LKE COMPANY, LLC
MRC ROCKIES COMPANY
SOUTHEAST WATER MANAGEMENT COMPANY, LLC
WR PERMIAN, LLC
MRC HAT MESA, LLC
MRC TORO, LLC
MRC ROYALTIES, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
[Signature Page to Second Supplemental Indenture]
(6.250% Senior Notes due 2033)
U.S. BANK TRUST COMPANY, NATIONAL ASSOCIATION, as Trustee
By: /s/ James H. Byrnes
Name: James H. Byrnes
Title: Vice President
[Signature Page to Second Supplemental Indenture]
(6.250% Senior Notes due 2033)
Exhibit 4.3
MATADOR RESOURCES COMPANY
THIRD SUPPLEMENTAL INDENTURE
(6.500% Senior Notes due 2032)
THIRD SUPPLEMENTAL INDENTURE (this “Supplemental Indenture”), dated as of November 3, 2026, among MRC Ranger, LLC, a Delaware limited liability company, Paloma Permian, LLC, a Delaware limited liability company, Paloma Permian AssetCo, LLC, a Delaware limited liability company and Paloma Permian Nominee Corporation, a Delaware corporation (each a “New Guarantor” and collectively the “New Guarantors”),each a subsidiary of Matador Resources Company, a Texas corporation (the “Company”), the existing Guarantors (as defined in the Indenture referred to herein), the Company and U.S. Bank Trust Company, National Association, as trustee under the Indenture referred to herein (the “Trustee”). The New Guarantors and the existing Guarantors are sometimes referred to collectively herein as the “Guarantors,” or individually as a “Guarantor.”
W I T N E S S E T H
WHEREAS, the Company and the existing Guarantors have heretofore executed and delivered to the Trustee an indenture (as supplemented by the First Supplemental Indenture dated as of September 20, 2024 and the Second Supplemental Indenture dated as of March 18, 2025, the “Indenture”), dated as of April 2, 2024, relating to the 6.500% Senior Notes due 2032 (the “Securities”) of the Company;
WHEREAS, Section 4.9 of the Indenture in certain circumstances requires the Company to cause a newly acquired or created Restricted Subsidiary (i) to become a Guarantor by executing a supplemental indenture and (ii) to deliver an Opinion of Counsel to the Trustee as provided in such Section; and
WHEREAS, pursuant to Section 9.1 of the Indenture, the Company, the Guarantors and the Trustee are authorized to execute and deliver this Supplemental Indenture to amend or supplement the Indenture without the consent of any Holder;
NOW THEREFORE, to comply with the provisions of the Indenture and in consideration of the foregoing and for other good and valuable consideration, the receipt of which is hereby acknowledged, the New Guarantors, the other Guarantors, the Company and the Trustee mutually covenant and agree for the equal and ratable benefit of the Holders of the Securities as follows:
1. Capitalized Terms. Capitalized terms used herein without definition shall have the meanings assigned to them in the Indenture.
2. Agreement to Guarantee. Each New Guarantor hereby agrees, jointly and severally, with all other Guarantors, to unconditionally Guarantee to each Holder and to the Trustee the Obligations, to the extent set forth in the Indenture and subject to the provisions in
the Indenture. The obligations of the Guarantors to the Holders of Securities and to the Trustee pursuant to the Subsidiary Guarantees and the Indenture are expressly set forth in Article X of the Indenture and reference is hereby made to the Indenture for the precise terms of the Subsidiary Guarantees.
3. Execution and Delivery. Each New Guarantor agrees that its Subsidiary Guarantee shall remain in full force and effect notwithstanding any failure to endorse on each Security a notation of such Subsidiary Guarantee.
4. NEW YORK LAW TO GOVERN. THE LAWS OF THE STATE OF NEW YORK SHALL GOVERN AND BE USED TO CONSTRUE AND ENFORCE THIS SUPPLEMENTAL INDENTURE.
5. Counterparts. The parties may sign any number of copies of this Supplemental Indenture. Each signed copy shall be an original, but all of them together represent the same agreement. This Supplemental Indenture may be executed in multiple counterparts which, when taken together, shall constitute one instrument. This Supplemental Indenture (or any documents executed in connection with this Supplemental Indenture) shall be valid, binding and enforceable against a party when executed and delivered by an authorized individual on behalf of the party by means of (i) an original manual signature, (ii) a faxed, scanned, or photocopied manual signature, or (iii) any other electronic signature permitted by the federal Electronic Signatures in Global and National Commerce Act, state enactments of Uniform Electronic Transactions Act, and/or any relevant electronic signature law, including any relevant provisions of the Uniform Commercial Code (collectively, “Signature Law”), in each case to the extent applicable. Each faxed, scanned or photocopied manual signature, or other electronic signature, shall for all purposes have the same validity, legal effect, and admissibility in evidence as an original manual signature. Each party hereto shall be entitled to conclusively rely upon, and shall have no liability with respect to, any faxed, scanned, or photocopied manual signature, or other electronic signature, of any other party and shall have no duty to investigate, confirm or otherwise verify the validity or authenticity thereof. For the avoidance of doubt, original manual signatures shall be used for the execution or indorsement of writings when required under the Uniform Commercial Code or other Signature Law due to the character or intended character of the writings.
6. Effect of Headings. The Section headings herein are for convenience only and shall not affect the construction hereof.
7. The Trustee. Except as otherwise expressly provided herein, no duties, responsibilities or liabilities are assumed, or shall be construed to be assumed, by the Trustee by reason of this Supplemental Indenture. This Supplemental Indenture is executed and accepted by the Trustee subject to all the terms and conditions set forth in the Indenture with the same force and effect as if those terms and conditions were repeated at length herein and made applicable to the Trustee with respect hereto.
[Remainder of Page Intentionally Left Blank; Signature Pages Follow]
IN WITNESS WHEREOF, the parties hereto have caused this Supplemental Indenture to be duly executed and attested, all as of the date first above written.
MATADOR RESOURCES COMPANY
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
MRC RANGER, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
PALOMA PERMIAN, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
PALOMA PERMIAN ASSETCO, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
PALOMA PERMIAN NOMINEE CORPORATION
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
[Signature Page to Third Supplemental Indenture]
(6.500% Senior Notes due 2032)
DELAWARE WATER MANAGEMENT COMPANY, LLC
LONGWOOD GATHERING AND DISPOSAL SYSTEMS, LLC
LONGWOOD MIDSTREAM HOLDINGS, LLC
LONGWOOD MIDSTREAM SOUTH TEXAS, LLC
LONGWOOD MIDSTREAM SOUTHEAST, LLC
LONGWOOD MIDSTREAM DELAWARE, LLC
MATADOR PRODUCTION COMPANY
MRC ENERGY COMPANY
MRC DELAWARE RESOURCES, LLC
MRC ENERGY SOUTHEAST COMPANY, LLC
MRC ENERGY SOUTH TEXAS COMPANY, LLC
MRC PERMIAN COMPANY
MRC PERMIAN LKE COMPANY, LLC
MRC ROCKIES COMPANY
SOUTHEAST WATER MANAGEMENT COMPANY, LLC
WR PERMIAN, LLC
MRC HAT MESA, LLC
MRC TORO, LLC
MRC ROYALTIES, LLC
By: /s/ Michael D. Frenzel
Name: Michael D. Frenzel
Title: Executive Vice President and Treasurer
[Signature Page to Third Supplemental Indenture]
(6.500% Senior Notes due 2032)
U.S. BANK TRUST COMPANY, NATIONAL ASSOCIATION, as Trustee
By: /s/ James H. Byrnes
Name: James H. Byrnes
Title: Vice President
[Signature Page to Third Supplemental Indenture]
(6.500% Senior Notes due 2032)
Exhibit 31.1
CERTIFICATION
I, Joseph Wm. Foran, certify that:
1. I have reviewed this quarterly report on Form 10-Q of Matador Resources Company;
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c. Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
d. Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
| November 6, 2026 | /s/ Joseph Wm. Foran | |||||||
| Joseph Wm. Foran | ||||||||
| Chairman and Chief Executive Officer (Principal Executive Officer) | ||||||||
Exhibit 31.2
CERTIFICATION
I, Christopher P. Calvert, certify that:
1. I have reviewed this quarterly report on Form 10-Q of Matador Resources Company;
2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;
3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
a. Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;
b. Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;
c. Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
d. Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
a. All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
b. Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.
| November 6, 2026 | /s/ Christopher P. Calvert | |||||||
| Christopher P. Calvert | ||||||||
| Executive Vice President and Chief Financial Officer (Principal Financial Officer) | ||||||||
Exhibit 32.1
CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO SECTION 906
OF THE SARBANES-OXLEY ACT OF 2002
In connection with the quarterly report of Matador Resources Company (the “Company”) on Form 10-Q for the period ended September 30, 2026 as filed with the Securities and Exchange Commission on the date hereof (the “Form 10-Q”), I, Joseph Wm. Foran, hereby certify in my capacity as Chairman and Chief Executive Officer of the Company, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge:
(1) The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2) The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.
| November 6, 2026 | /s/ Joseph Wm. Foran | |||||||
| Joseph Wm. Foran | ||||||||
| Chairman and Chief Executive Officer (Principal Executive Officer) | ||||||||
Exhibit 32.2
CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO SECTION 906
OF THE SARBANES-OXLEY ACT OF 2002
In connection with the quarterly report of Matador Resources Company (the “Company”) on Form 10-Q for the period ended September 30, 2026 as filed with the Securities and Exchange Commission on the date hereof (the “Form 10-Q”), I, Christopher P. Calvert, hereby certify in my capacity as Executive Vice President and Chief Financial Officer of the Company, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that to the best of my knowledge:
(1) The Form 10-Q fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2) The information contained in the Form 10-Q fairly presents, in all material respects, the financial condition and results of operations of the Company.
| November 6, 2026 | /s/ Christopher P. Calvert | |||||||
| Christopher P. Calvert | ||||||||
| Executive Vice President and Chief Financial Officer (Principal Financial Officer) | ||||||||