UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
_________________________________
FORM 8-K
_________________________________
CURRENT REPORT
Pursuant to Section 13 or 15(d)
of the Securities Exchange Act of 1934
Date of Report (Date of Earliest Event Reported) February 22, 2022
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(Exact name of registrant as specified in its charter)
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| (State or other jurisdiction of incorporation) | (Commission File Number) | (IRS Employer Identification No.) | ||||||||||||
| (Address of principal executive offices) | (Zip Code) | |||||||
Registrant’s telephone number, including area code: (972 ) 371-5200
Not Applicable
(Former name or former address, if changed since last report)
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Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
| Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425) | |||||
| Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12) | |||||
| Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b)) | |||||
| Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c)) | |||||
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 is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter).
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. ☐
| Item 2.02 | Results of Operations and Financial Condition. | ||||
Attached hereto as Exhibit 99.1 is a press release (the “Earnings Press Release”) issued by Matador Resources Company (the “Company”) on February 22, 2022, announcing its financial results for the three and twelve months ended December 31, 2021. The Earnings Press Release includes an operational update at February 22, 2022. The Earnings Press Release is incorporated by reference into this Item 2.02, and the foregoing description of the Earnings Press Release is qualified in its entirety by reference to this exhibit.
The information furnished pursuant to this Item 2.02, including Exhibit 99.1, shall not be deemed to be “filed” for the purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and will not be incorporated by reference into any filing under the Securities Act of 1933, as amended (the “Securities Act”), unless specifically identified therein as being incorporated therein by reference.
In the Earnings Press Release, the Company has included certain “non-GAAP financial measures,” as defined in Item 10 of Regulation S-K of the Exchange Act, including (i) earnings before interest expense, income taxes, depletion, depreciation and amortization, accretion of asset retirement obligations, property impairments, unrealized derivative gains and losses, certain other non-cash items and non-cash stock-based compensation expense, and net gain or loss on asset sales and impairment (“Adjusted EBITDA”) attributable to Matador Resources Company shareholders, (ii) the Adjusted EBITDA of San Mateo Midstream, LLC, the Company’s midstream affiliate (“San Mateo”), (iii) adjusted net income (loss) attributable to Matador Resources Company shareholders, (iv) adjusted earnings (loss) per diluted common share attributable to Matador Resources Company shareholders, (v) adjusted free cash flow of both the Company and San Mateo and (vi) present value discounted at 10% (pre-tax) of estimated total proved reserves. In the Earnings Press Release, the Company has provided reconciliations of the non-GAAP financial measures to the most directly comparable financial measures calculated and presented in accordance with generally-accepted accounting principles (“GAAP”) in the United States. In addition, in the Earnings Press Release, the Company has provided the reasons why the Company believes such non-GAAP financial measures provide useful information to investors.
| Item 7.01 | Regulation FD Disclosure. | ||||
Item 2.02 above is incorporated herein by reference.
Attached hereto as Exhibit 99.2 is a press release (the “Guidance Press Release”) issued by the Company on February 22, 2022, announcing its 2022 operating plan and market guidance.
In connection with the Earnings Press Release and the Guidance Press Release, the Company released accompanying presentations summarizing the highlights of each press release (the “Presentations”). The Presentations are available on the Company’s website, www.matadorresources.com, on the Events and Presentations page under the Investor Relations tab.
The information furnished pursuant to this Item 7.01, including Exhibits 99.1 and 99.2, shall not be deemed to be “filed” for the purposes of Section 18 of the Exchange Act and will not be incorporated by reference into any filing under the Securities Act unless specifically identified therein as being incorporated therein by reference.
| Item 9.01 | Financial Statements and Exhibits. | ||||
(d) Exhibits
| Exhibit No. | Description of Exhibit | |||||||
| 99.1 | ||||||||
| 99.2 | ||||||||
| 104 | Cover Page Interactive Data File, formatted in Inline XBRL (included as Exhibit 101). | |||||||
SIGNATURE
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 hereunto duly authorized.
| MATADOR RESOURCES COMPANY | ||||||||||||||||||||
| Date: February 22, 2022 | By: | /s/ Craig N. Adams | ||||||||||||||||||
| Name: | Craig N. Adams | |||||||||||||||||||
| Title: | Executive Vice President | |||||||||||||||||||
Exhibit 99.1
MATADOR RESOURCES COMPANY REPORTS FOURTH QUARTER AND
FULL YEAR 2021 FINANCIAL RESULTS AND PROVIDES OPERATIONAL UPDATE
DALLAS, Texas, February 22, 2022 -- Matador Resources Company (NYSE: MTDR) (“Matador” or the “Company”) today reported financial and operating results for the fourth quarter and full year 2021. A slide presentation summarizing the highlights of Matador’s fourth quarter and full year 2021 earnings release is also included on the Company’s website at www.matadorresources.com on the Events and Presentations page under the Investor Relations tab. In a separate press release issued today, Matador also provided its 2022 operating plan and 2022 market guidance.
Management Summary Comments
Joseph Wm. Foran, Matador’s Founder, Chairman and CEO, commented, “On both our website and the webcast planned for tomorrow’s earnings conference call is a set of six slides identified as ‘Chairman’s Remarks’ (Slides A through F) to add color and detail to my remarks. We invite you to review these slides in conjunction with my comments below, which are intended to provide context for Matador’s outstanding results for the fourth quarter and full year 2021.
“The year 2021 was a tremendous year for Matador, including record total oil and natural gas production of 31.5 million barrels of oil equivalent, record oil and natural gas revenues of $1.7 billion, record net income of $585 million, record earnings per diluted common share of $4.91 and record Adjusted EBITDA of $1.05 billion, among other milestones (see Slide A). San Mateo also had a record year in 2021, including all-time high throughput volumes for natural gas gathering and processing, oil gathering and transportation and water handling, as well as record net income of $113.6 million and record Adjusted EBITDA of $154.3 million. In 2021, both Matador and San Mateo generated free cash flow in all four quarters, and we instituted and then raised our dividend to begin returning additional cash to our shareholders. We also aggressively paid down debt and ended the year with a leverage ratio of 1.1x, the lowest we have achieved since mid-2014. As you will see throughout this earnings release, Matador finished 2021 strong and entered 2022 in the best shape it has ever been, having accomplished all five of its primary goals for 2021—to reduce debt, to increase shareholder returns, to reduce drilling and completions costs per lateral foot, to increase capital efficiency and to achieve record operational results! The Board and I would like to once again acknowledge and express our sincere appreciation to all Matador and San Mateo employees and contractors for their continued strong execution and teamwork, which made these record results possible.
Fourth Quarter 2021 Highlights and Achievements
“The fourth quarter of 2021 was another excellent quarter for Matador yielding strong production and financial results that contributed significantly to our record results for full year 2021. During the fourth quarter, Matador achieved better-than-expected oil, natural gas and total oil equivalent production and record oil and natural gas revenues, net income and Adjusted EBITDA (see Slide B). San Mateo also finished 2021 on a high note, including better-than-expected financial results (see Slide C).
“Net cash provided by operating activities in the fourth quarter was $334.5 million, a 15% sequential increase, leading to fourth quarter 2021 adjusted free cash flow of $119.3 million. This adjusted free cash flow included $11.0 million in performance incentives received by Matador from our midstream joint venture partner, Five Point Energy LLC, for the 11 Boros wells turned to sales and connected to San Mateo during the second half of 2021. Matador repaid $20 million in borrowings outstanding under its reserves based revolving credit facility in the fourth quarter of 2021 and reduced the borrowings outstanding under its reserves-based revolving credit facility to $100 million at December 31, 2021 from $440 million at year-end 2020. Matador expects to repay another $25 million in
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borrowings outstanding by the end of February 2022, and as a result of these repayments, Matador expects to reduce the borrowings outstanding under the reserves-based revolving credit facility to $75 million, a reduction of $400 million, when compared to $475 million at the end of the third quarter of 2020. Matador’s leverage ratio under the reserves-based revolving credit facility declined to 1.1x at year-end 2021, a significant reduction from 2.9x at year-end 2020, and, again, marking Matador’s lowest leverage ratio since mid-2014 (see Slide D).
Key 2021 Milestones Achieved, Along with Record Capital Efficiency
“Matador’s 2021 priorities and milestones are summarized in Slide E, and we executed very well on this operating and capital efficiency plan throughout 2021. During the fourth quarter of 2021, we achieved our final key operational milestone when we turned to sales nine new wells in our Greater Stebbins Area in December. Overall, we believe Matador’s 2021 operating program was a tremendous success and made significant progress in all these areas. Drilling and completion costs averaged $670 per completed lateral foot for 2021, an all-time low on an annual basis, and a year-over-year decrease of 21% from $850 per completed lateral foot in 2020, our previous all-time low (see Slide F). During 2021, Matador turned to sales 47 gross (44.2 net) operated horizontal wells in the Delaware Basin with an average lateral length of approximately 10,500 feet, all but one of which had a lateral length of two miles or longer. Notably, these 47 wells, in aggregate, including the costs of the nine new Greater Stebbins Area wells we turned to sales in December, had already achieved payout by the end of the year. Obviously, these wells should continue to provide Matador with strong operating cash flows for many years to come.
2022 Operating Plan and Market Guidance
“Finally, in conjunction with this earnings release, we have also released today our 2022 operating plan and market guidance. As you will see in that companion release, we believe that 2022 should again be exciting for Matador and all of its stakeholders, as we continue developing our excellent Delaware Basin assets, generating significant free cash flow, paying down debt, evaluating potentially accretive acquisition opportunities and returning cash to shareholders through increases to the dividend as our performance allows. The Matador staff in both the office and in the field are growing in teamwork, expertise and experience and are due the credit for generating these results. We expect to have record production results again in 2022 and should oil and natural gas prices continue to remain strong throughout 2022, we believe our 2022 operating plan, in the capable hands of our office and field staff, should generate record financial results and cash flows as well, while generating substantial value growth for all our stakeholders in the year ahead and for years to come.”
Fourth Quarter 2021 Operational and Financial Highlights
Net Cash Provided by Operating Activities and Adjusted Free Cash Flow
•Fourth quarter 2021 net cash provided by operating activities was $334.5 million (GAAP basis), leading to fourth quarter 2021 adjusted free cash flow (a non-GAAP financial measure) of $119.3 million.
Net Income, Earnings Per Share and Adjusted EBITDA
•Fourth quarter 2021 net income (GAAP basis) was $214.8 million, or net income of $1.80 per diluted common share, a sequential increase from net income of $203.6 million in the third quarter of 2021, and a significant year-over-year increase from a net loss of $89.5 million in the fourth quarter of 2020.
•Fourth quarter 2021 adjusted net income (a non-GAAP financial measure) was $151.2 million, or adjusted net income of $1.26 per diluted common share, a sequential increase from adjusted net income of $148.6
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million in the third quarter of 2021, and a significant year-over-year increase from adjusted net income of $32.3 million in the fourth quarter of 2020.
•Fourth quarter 2021 adjusted earnings before interest expense, income taxes, depletion, depreciation and amortization and certain other items (“Adjusted EBITDA,” a non-GAAP financial measure) were $299.1 million, a sequential increase from $293.8 million in the third quarter of 2021, and a year-over-year increase from $150.1 million in the fourth quarter of 2020.
Oil, Natural Gas and Oil Equivalent Production
•As summarized in the table below, Matador’s fourth quarter 2021 average daily oil, natural gas and total oil equivalent production were all above the Company’s expectations. The majority of the higher-than-expected production resulted from the timing of shut-in operations in the Stateline asset area associated with hydraulic fracturing operations on the 11 Voni wells. The Company did not begin hydraulic fracturing operations on these 11 wells until the second week of November, as opposed to on November 1, allowing for approximately ten additional days of full production from the Stateline asset area prior to a significant number of these wells being shut in for the 11 Voni well completions as planned.
| Production Change (%) | |||||||||||||||||
| Production | Q4 2021 Average Daily Volume | Sequential(1) | Guidance(2) | Difference(3) | YoY(4) | ||||||||||||
| Total, BOE per day | 87,300 | -3% | -9% to -10% | +7% | +5% | ||||||||||||
| Oil, Bbl per day | 49,800 | -2% | -9% to -10% | +8% | +4% | ||||||||||||
| Natural Gas, MMcf per day | 225.2 | -4% | -9% to -11% | +6% | +7% | ||||||||||||
(2) Production change previously projected, as provided on October 26, 2021.
(3) As compared to midpoint of guidance provided on October 26, 2021.
(4) Represents year-over-year percentage change from the fourth quarter of 2020.
Capital Expenditures Below Expectations; Drilling and Completions Costs Per Foot In-Line
•Matador incurred capital expenditures for drilling, completing and equipping wells (“D/C/E capital expenditures”) of approximately $166 million in the fourth quarter of 2021, or 18% below the Company’s estimate of $202 million for D/C/E capital expenditures during the quarter. Matador estimates that approximately $15 million of these savings were directly attributable to continued improvement in operational efficiencies, while the remainder of the savings resulted primarily from the timing of both operated and non-operated drilling and completion activities, and most of these costs are currently expected to be incurred in the first quarter of 2022.
•For full year 2021, Matador’s D/C/E capital expenditures were approximately $513 million, or about 7% below the midpoint of Matador’s updated guidance of $550 million for full year 2021 D/C/E capital expenditures, as provided on October 26, 2021. These annual cost savings were achieved despite the increasing service cost inflation experienced in the second half of 2021 and despite pulling forward the most recent 11 Voni well completions into the fourth quarter of 2021.
•Drilling and completion costs for all operated horizontal wells turned to sales in the fourth quarter of 2021 averaged approximately $738 per completed lateral foot, a sequential increase of 14% from average drilling and completion costs of approximately $650 per completed lateral foot in the third quarter of 2021
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and in-line with the Company’s expectations for the fourth quarter. This increase was primarily attributable to the inflation in oilfield service costs associated with drilling and, in particular, completion operations, a trend that the Company expects to continue throughout 2022.
•For full year 2021, drilling and completion costs for all operated horizontal wells turned to sales averaged approximately $670 per completed lateral foot, a year-over-year decrease of 21% from average drilling and completion costs of $850 per completed lateral foot achieved in full year 2020.
Total Borrowings Continue to Decline
•At December 31, 2021, Matador’s leverage ratio, as defined in the Company’s reserves-based credit facility, was 1.1x, which was better than the Company’s expectations for year-end 2021. The leverage ratio of 1.1x marks Matador’s lowest leverage ratio since mid-2014. At December 31, 2021, total borrowings outstanding under Matador’s reserves-based credit facility were $100 million, a reduction of $20 million from total borrowings outstanding of $120 million at September 30, 2021.
•Matador expects to repay an additional $25 million in borrowings outstanding under the reserves-based credit facility before the end of February 2022. Total borrowings outstanding under the reserves-based credit facility at February 28, 2022 are expected to be $75 million.
Reserves-Based Credit Agreement Amended and Restated
•On November 18, 2021, Matador announced the closing of a new amended and restated credit agreement (the “Credit Agreement”). Under the Credit Agreement signed on November 18, 2021, (i) the maturity date was extended by three years to October 31, 2026, from October 31, 2023 previously; (ii) the borrowing base was increased by 50% to $1.35 billion, as compared to $900 million previously; (iii) the elected borrowing commitment was reaffirmed at $700 million; and (iv) the maximum facility amount was reaffirmed at $1.5 billion. Matador also added three new banks to its lending group under the Credit Agreement.
•Additional details regarding the new Credit Agreement were provided in the Company’s November 18, 2021 press release, and additional financial terms and covenants under the Credit Agreement were included in the Form 8-K filed with the U.S. Securities and Exchange Commission.
Credit Rating and Senior Notes Upgraded by S&P
•On January 27, 2022, as previously announced, S&P Global Ratings (“S&P”) upgraded Matador’s issuer credit rating from ‘B’ to ‘B+’ and upgraded Matador’s issue-level rating on Matador’s senior unsecured notes from ‘B+’ to ‘BB-’.
Note: All references to Matador’s net income (loss), adjusted net income (loss), Adjusted EBITDA and adjusted free cash flow reported throughout this earnings release are those values attributable to Matador Resources Company shareholders after giving effect to any net income (loss), Adjusted EBITDA or adjusted free cash flow, respectively, attributable to third-party non-controlling interests, including in San Mateo Midstream, LLC (“San Mateo”). Matador owns 51% of San Mateo. For a definition of adjusted net income (loss), adjusted earnings (loss) per diluted common share, Adjusted EBITDA, adjusted free cash flow and PV-10 and reconciliations of such non-GAAP financial metrics to their comparable GAAP metrics, please see “Supplemental Non-GAAP Financial Measures” below.
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Sequential and year-over-year quarterly comparisons of selected financial and operating items are shown in the following table:
| Three Months Ended | |||||||||||||||||||||||
| December 31, | September 30, | December 31, | |||||||||||||||||||||
| 2021 | 2021 | 2020 | |||||||||||||||||||||
Net Production Volumes:(1) | |||||||||||||||||||||||
Oil (MBbl)(2) | 4,578 | 4,669 | 4,419 | ||||||||||||||||||||
Natural gas (Bcf)(3) | 20.7 | 21.7 | 19.4 | ||||||||||||||||||||
Total oil equivalent (MBOE)(4) | 8,030 | 8,283 | 7,653 | ||||||||||||||||||||
Average Daily Production Volumes:(1) | |||||||||||||||||||||||
Oil (Bbl/d)(5) | 49,756 | 50,747 | 48,028 | ||||||||||||||||||||
Natural gas (MMcf/d)(6) | 225.2 | 235.7 | 210.9 | ||||||||||||||||||||
Total oil equivalent (BOE/d)(7) | 87,288 | 90,033 | 83,183 | ||||||||||||||||||||
| Average Sales Prices: | |||||||||||||||||||||||
| Oil, without realized derivatives (per Bbl) | $ | 76.82 | $ | 69.73 | $ | 40.99 | |||||||||||||||||
| Oil, with realized derivatives (per Bbl) | $ | 60.96 | $ | 58.43 | $ | 38.59 | |||||||||||||||||
Natural gas, without realized derivatives (per Mcf)(8) | $ | 7.68 | $ | 6.27 | $ | 2.97 | |||||||||||||||||
| Natural gas, with realized derivatives (per Mcf) | $ | 6.64 | $ | 6.05 | $ | 2.97 | |||||||||||||||||
| Revenues (millions): | |||||||||||||||||||||||
| Oil and natural gas revenues | $ | 510.8 | $ | 461.5 | $ | 238.7 | |||||||||||||||||
| Third-party midstream services revenues | $ | 19.7 | $ | 20.5 | $ | 15.1 | |||||||||||||||||
| Realized loss on derivatives | $ | (94.2) | $ | (57.4) | $ | (10.6) | |||||||||||||||||
| Operating Expenses (per BOE): | |||||||||||||||||||||||
| Production taxes, transportation and processing | $ | 6.48 | $ | 5.90 | $ | 3.53 | |||||||||||||||||
| Lease operating | $ | 3.34 | $ | 3.31 | $ | 3.20 | |||||||||||||||||
| Plant and other midstream services operating | $ | 2.12 | $ | 2.06 | $ | 1.62 | |||||||||||||||||
| Depletion, depreciation and amortization | $ | 11.15 | $ | 10.75 | $ | 11.73 | |||||||||||||||||
General and administrative(9) | $ | 3.14 | $ | 2.97 | $ | 2.16 | |||||||||||||||||
Total(10) | $ | 26.23 | $ | 24.99 | $ | 22.24 | |||||||||||||||||
| Other (millions): | |||||||||||||||||||||||
Net sales of purchased natural gas(11) | $ | 1.8 | $ | 4.2 | $ | 1.2 | |||||||||||||||||
Net income (loss) (millions)(12) | $ | 214.8 | $ | 203.6 | $ | (89.5) | |||||||||||||||||
Earnings (loss) per common share (diluted)(12) | $ | 1.80 | $ | 1.71 | $ | (0.77) | |||||||||||||||||
Adjusted net income (millions)(12)(13) | $ | 151.2 | $ | 148.6 | $ | 32.3 | |||||||||||||||||
Adjusted earnings per common share (diluted)(12)(14) | $ | 1.26 | $ | 1.25 | $ | 0.27 | |||||||||||||||||
Adjusted EBITDA (millions)(12)(15) | $ | 299.1 | $ | 293.8 | $ | 150.1 | |||||||||||||||||
Net cash provided by operating activities (millions)(16) | $ | 334.5 | $ | 291.2 | $ | 157.6 | |||||||||||||||||
Adjusted free cash flow (millions)(12)(17) | $ | 119.3 | $ | 147.5 | $ | 60.7 | |||||||||||||||||
San Mateo net income (millions)(18) | $ | 33.6 | $ | 29.5 | $ | 26.2 | |||||||||||||||||
San Mateo adjusted EBITDA (millions)(15)(18) | $ | 43.6 | $ | 40.8 | $ | 35.4 | |||||||||||||||||
San Mateo net cash provided by operating activities (millions)(18) | $ | 33.1 | $ | 44.2 | $ | 26.1 | |||||||||||||||||
San Mateo adjusted free cash flow (millions)(17)(18) | $ | 28.9 | $ | 8.4 | $ | 21.4 | |||||||||||||||||
| D/C/E capital expenditures (millions) | $ | 165.7 | $ | 121.1 | $ | 63.4 | |||||||||||||||||
Midstream capital expenditures (millions)(19) | $ | 6.6 | $ | 14.7 | $ | 7.4 | |||||||||||||||||
(1) Production volumes and proved reserves reported in two streams: oil and natural gas, including both dry and liquids-rich natural gas.
(2) One thousand barrels of oil.
(3) One billion cubic feet of natural gas.
(4) One thousand barrels of oil equivalent, estimated using a conversion ratio of one barrel of oil per six thousand cubic feet of natural gas.
(5) Barrels of oil per day.
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(6) Millions of cubic feet of natural gas per day.
(7) Barrels of oil equivalent per day, estimated using a conversion ratio of one barrel of oil per six thousand cubic feet of natural gas.
(8) Per thousand cubic feet of natural gas.
(9) Includes approximately $0.43, $0.36 and $0.42 per BOE of non-cash, stock-based compensation expense in the fourth quarter of 2021, the third quarter of 2021 and the fourth quarter of 2020, respectively.
(10) Total does not include the impact of full-cost ceiling impairment charges, purchased natural gas or immaterial accretion expenses.
(11) Net sales of purchased natural gas reflect those natural gas purchase transactions that the Company periodically enters into with third parties whereby the Company purchases natural gas and (i) subsequently sells the natural gas to other purchasers or (ii) processes the natural gas at San Mateo’s cryogenic natural gas processing plant in Eddy County, New Mexico (the “Black River Processing Plant”) and subsequently sells the residue natural gas and natural gas liquids (“NGL”) to other purchasers. Such amounts reflect revenues from sales of purchased natural gas of $31.8 million, $38.8 million and $3.9 million less expenses of $30.1 million, $34.6 million and $2.6 million in the fourth quarter of 2021, the third quarter of 2021 and the fourth quarter of 2020, respectively.
(12) Attributable to Matador Resources Company shareholders.
(13) Adjusted net income is a non-GAAP financial measure. For a definition of adjusted net income and a reconciliation of adjusted net income (non-GAAP) to net income (loss) (GAAP), please see “Supplemental Non-GAAP Financial Measures.”
(14) Adjusted earnings per diluted common share is a non-GAAP financial measure. For a definition of adjusted earnings per diluted common share and a reconciliation of adjusted earnings per diluted common share (non-GAAP) to earnings (loss) per diluted common share (GAAP), please see “Supplemental Non-GAAP Financial Measures.”
(15) Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA (non-GAAP) to net income (loss) (GAAP) and net cash provided by operating activities (GAAP), please see “Supplemental Non-GAAP Financial Measures.”
(16) As reported for each period on a consolidated basis, including 100% of San Mateo’s net cash provided by operating activities.
(17) Adjusted free cash flow is a non-GAAP financial measure. For a definition of adjusted free cash flow and a reconciliation of adjusted free cash flow (non-GAAP) to net cash provided by operating activities (GAAP), please see “Supplemental Non-GAAP Financial Measures.”
(18) Represents 100% of San Mateo’s net income, adjusted EBITDA, net cash provided by operating activities or adjusted free cash flow for each period reported.
(19) Includes Matador’s 51% share of San Mateo’s capital expenditures plus 100% of other immaterial midstream capital expenditures not associated with San Mateo.
Recent Acquisitions and Divestitures
Acquisitions – Delaware Basin, Lea and Eddy Counties, New Mexico and Loving County, Texas
During the second half of 2021 and through February 22, 2022, Matador acquired both producing and non-producing properties in the Delaware Basin in Lea and Eddy Counties, New Mexico and Loving County, Texas as a result of both asset purchases and organic leasing activities for a total consideration of approximately $242 million, inclusive of customary purchase price adjustments, and did so without increasing total debt outstanding or the leverage ratio at year-end 2021. The majority of these properties are located between the Company’s Mallon and Rodney Robinson leasehold positions in Lea County, New Mexico, and a large portion of the acreage acquired includes “bolt-on” positions to the Company’s existing acreage in the western portion of its Ranger asset area. These properties also include a variety of smaller tracts acquired in several of the Company’s Delaware Basin asset areas in both New Mexico and Texas.
Approximately $217 million associated with these transactions was paid by Matador during the third and fourth quarters of 2021, which is reflected in the Company’s full year 2021 cash flow statements provided with this earnings release. The Company paid an additional $25 million upon closing the remaining properties associated with these transactions during January and February 2022. Matador has funded these acquisitions using free cash flow from its operations generated during the second half of 2021 and the first quarter of 2022.
Additional details regarding the acquired properties include the following:
•Approximately 3,750 BOE per day at the time of the various acquisitions, including flush production from three new wells turned to sales in November 2021, and for which Matador realized only about 50,000 BOE as part of its fourth quarter 2021 total production, or less than 1% of its fourth quarter 2021 total production, as a result of acquiring these properties late in the fourth quarter;
•Approximately 22,400 gross (12,700 net) acres acquired, including a mix of fee, state and federal acreage;
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•Approximately 206 gross (128.6 net) locations identified for future drilling, including prospective targets throughout the Wolfcamp, Bone Spring and Avalon intervals; and
•Production characterized by higher oil cut wells (70% or greater) and lower water production (water-oil ratios typically three-to-one or less).
Matador expects to add approximately 16.6 million BOE, including 12.1 million barrels of oil and 26.5 billion cubic feet of natural gas, associated with these properties to its estimated total proved oil and natural gas reserves, a portion of which was included in the Company’s proved oil and natural gas reserves at December 31, 2021 and the remainder of which will be included in the Company’s proved reserves as of March 31, 2022. The Standardized Measure and PV-10 (present value discounted at 10%, a non-GAAP financial measure) of these proved oil and natural gas reserves are approximately $186.1 million and $227.1 million, respectively, using an oil price of $63.04 per barrel and a natural gas price of $3.60 per MMBtu, which were the prices used to value the Company’s proved reserves at December 31, 2021. Matador expects to add future proved reserves, Standardized Measure and PV-10 as a result of the development of these properties going forward.
At February 22, 2022, Matador has contracted a sixth drilling rig to begin development of certain of these properties in Lea County, New Mexico. Matador expects to turn to sales seven gross (5.9 net) wells associated with these properties in 2022, all of which are anticipated to be turned to sales late in the fourth quarter.
Divestitures – Eagle Ford Shale, South Texas
Between September 2021 and January 2022, Matador divested approximately 9,800 gross (9,300 net) acres in Dewitt and Zavala Counties, Texas and received proceeds of approximately $14.3 million. At the time of these divestitures, the Company had minimal production and proved developed reserves attributable to these properties. Matador also had no proved undeveloped reserves attributable to these properties at the time of these divestitures.
Operations Update
Drilling and Completion Activity
Matador operated five drilling rigs in the Delaware Basin during the fourth quarter of 2021 as planned, and the Company expects to operate these five drilling rigs throughout its various asset areas in the Delaware Basin throughout 2022. In addition, at February 22, 2022, Matador had contracted a sixth operated drilling rig to begin drilling operations immediately on recently acquired acreage in western Lea County, New Mexico in Matador’s Ranger asset area (please see Recent Acquisitions and Divestitures discussion above). Matador expects to operate this sixth operated rig on the newly acquired acreage throughout the remainder of 2022. Accounting for the anticipated impact of service cost inflation in 2022, the six-rig drilling program results in only a small increase to the Company’s expected 2022 D/C/E capital expenditures, as compared to the four-rig drilling program Matador conducted for the majority of 2021, primarily as a result of lower working interests associated with many of the wells Matador expects to drill and complete in 2022. Additional details regarding Matador’s 2022 operating plans are provided in the Company’s 2022 Operating Plan and Market Guidance press release issued separately today.
Wells Completed and Turned to Sales
During the fourth quarter of 2021, Matador turned to sales a total of 39 gross (9.3 net) wells in its various operating areas as shown in the table below. This total was comprised of nine gross (8.0 net) operated wells and 30 gross (1.3 net) non-operated wells. All operated wells were two-mile laterals. The two gross (1.4 net) wells in the Ranger asset area originally scheduled to be turned to sales in late December were turned to sales in mid-January 2022. For
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full year 2021, Matador turned to sales 104 gross (48.2 net) wells in its various operating areas, including 47 gross (44.2 net) operated wells and 57 gross (4.0 net) non-operated wells.
| Operated | Non-Operated | Total | Gross Operated and Non-Operated | ||||||||||||||||||||||||||
| Asset/Operating Area | Gross | Net | Gross | Net | Gross | Net | Well Completion Intervals | ||||||||||||||||||||||
| Antelope Ridge | - | - | 9 | 0.5 | 9 | 0.5 | 5-1BS, 1-2BS, 3-WC A | ||||||||||||||||||||||
| Arrowhead | 9 | 8.0 | 11 | 0.5 | 20 | 8.5 | 6-2BS, 7-3BS, 6-WC A, 1-WC B | ||||||||||||||||||||||
| Ranger | - | - | 2 | 0.1 | 2 | 0.1 | 2-3BS | ||||||||||||||||||||||
| Rustler Breaks | - | - | 5 | 0.2 | 5 | 0.2 | 5-WC A | ||||||||||||||||||||||
| Stateline | - | - | - | - | - | - | No wells turned to sales in Q4 2021 | ||||||||||||||||||||||
| Twin Lakes | - | - | - | - | - | - | No wells turned to sales in Q4 2021 | ||||||||||||||||||||||
| Wolf/Jackson Trust | - | - | - | - | - | - | No wells turned to sales in Q4 2021 | ||||||||||||||||||||||
| Delaware Basin | 9 | 8.0 | 27 | 1.3 | 36 | 9.3 | |||||||||||||||||||||||
| South Texas | - | - | - | - | - | - | No wells turned to sales in Q4 2021 | ||||||||||||||||||||||
| Haynesville Shale | - | - | 3 | 0.0 | 3 | 0.0 | 3-HV | ||||||||||||||||||||||
| Total | 9 | 8.0 | 30 | 1.3 | 39 | 9.3 | |||||||||||||||||||||||
Note: WC = Wolfcamp; BS = Bone Spring. For example, 1-2BS indicates one Second Bone Spring completion and 3-WC A indicates three Wolfcamp A completions. Any “0.0” values in the table above reflect a net working interest of less than 5%, which does not round to 0.1.
Greater Stebbins Area
In December 2021, Matador turned to sales nine gross (8.0 net) wells in the southern portion of its Arrowhead asset area (the “Greater Stebbins Area”), all of which were two-mile laterals, including four Third Bone Spring, four Wolfcamp A-XY and one Wolfcamp B completion. The initial results from these wells were comparable to previous wells completed in these formations in the Greater Stebbins Area, with most wells exhibiting approximately 70% oil cut. As is customary for wells completed in this area, most of these wells are being equipped with artificial lift, some with gas lift and some with electrical submersible pumps (ESPs), and, as a result, several of these wells were shut-in during portions of the first quarter of 2022 pending the completion of these artificial lift operations. All nine of these wells are expected to be returned to production by the end of the first quarter.
Overall, Matador is quite pleased with its 13-well drilling program in the Greater Stebbins Area during 2021, which also included four gross (3.5 net) Second Bone Spring wells turned to sales in the third quarter of 2021. At February 22, 2022, these 13 wells are expected to achieve an average payout time of approximately 1.5 years, where payout is defined as net oil and natural gas revenues received less D/C/E capital expenditures and all associated operating expenses incurred since the wells were turned to sales. At February 22, 2022, these 13 wells are also projected to deliver a return on invested capital of approximately three-to-one, where invested capital is defined as all D/C/E capital expenditures incurred, based on long-term average commodity prices of $65 per barrel for oil and $3.00 per MMBtu for natural gas. Matador looks forward to resuming drilling operations in the Greater Stebbins Area in mid-to-late 2022.
Stateline Asset Area
During the fourth quarter of 2021, Matador was completing 11 new Voni wells on the western side of its Stateline asset area, and as a result, the Company did not turn to sales any wells in the Stateline asset area during the fourth quarter. At February 22, 2022, the 11 new Voni wells, including five Third Bone Spring completions, four Wolfcamp B completions and two First Bone Spring completions have been turned to sales as anticipated. In
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addition, most of the wells shut in during the fourth quarter of 2021 in the Stateline asset area have now been returned to production. Four Boros wells, which were not originally anticipated to be shut-in during the first quarter of 2022, have been shut in for most of the first quarter, however, to protect these wells during completion operations by an offset operator immediately east of the Stateline asset area. Matador anticipates these wells will be returned to production before the end of the first quarter of 2022.
Overall, Matador is extremely pleased with the results from the 26 Stateline wells turned to sales during 2021. These 26 wells were turned to sales at various times during the year, primarily during April and September 2021, and most of these wells achieved, or are expected to achieve, payout in six months or less. Drilling and completion costs averaged $628 per completed lateral foot, the lowest that Matador has achieved to date in any of its asset areas. The 26 wells in the Stateline asset area turned to sales during 2021 achieved payout, in aggregate, in October 2021, and at February 22, 2022, these wells are projected to deliver a return on invested capital of greater than six-to-one, based on long-term average commodity prices of $65 per barrel for oil and $3.00 per MMBtu for natural gas!
Realized Commodity Prices
Oil Prices
Matador’s weighted average realized oil price, excluding derivatives, was $76.82 per barrel in the fourth quarter of 2021, a 10% sequential increase from $69.73 per barrel in the third quarter of 2021, and an 87% year-over-year increase from $40.99 per barrel in the fourth quarter of 2020. Matador’s weighted average oil price differential relative to the West Texas Intermediate (“WTI”) benchmark, inclusive of the monthly roll and transportation costs, was ($0.43) per barrel in the fourth quarter of 2021, as compared to ($0.79) per barrel in the third quarter of 2021 and ($1.71) per barrel in the fourth quarter of 2020.
For the first quarter of 2022, Matador’s weighted average oil price differential relative to the WTI benchmark price, inclusive of the monthly roll and transportation costs, is anticipated to be in the range of $0.00 to ($1.00) per barrel.
At February 22, 2022, Matador had approximately 5.1 million barrels of oil hedged for full year 2022, or about 25% of its anticipated 2022 oil production, using costless collars with a weighted average floor price of approximately $60 per barrel and a weighted average ceiling price of approximately $83 per barrel. Please see the accompanying presentation for a more complete summary of Matador’s current oil derivatives positions.
Natural Gas Prices
Matador’s weighted average realized natural gas price, excluding derivatives, was $7.68 per thousand cubic feet in the fourth quarter of 2021, a 22% sequential increase from $6.27 per thousand cubic feet in the third quarter of 2021, and a 2.6-fold increase from $2.97 per thousand cubic feet in the fourth quarter of 2020. NGL prices, and especially propane prices, continued to be strong in the fourth quarter, which contributed to the Company’s weighted average natural gas price being above the Company’s expectations in the fourth quarter of 2021. For the fourth quarter of 2021, Matador’s weighted average natural gas price differential relative to the Henry Hub benchmark price was +$2.86 per thousand cubic feet, as compared to +$1.95 per thousand cubic feet in the third quarter of 2021 and +$0.21 per thousand cubic feet in the fourth quarter of 2020. Matador is a two-stream reporter, and the revenues associated with its NGL production are included in the weighted average realized natural gas price.
For the first quarter of 2022, Matador’s weighted average natural gas price differential relative to the Henry Hub benchmark price is anticipated to be positive in the range of +$2.00 to +$2.50 per thousand cubic feet, primarily attributable to improved natural gas price differentials at the Waha hub in West Texas, assuming NGL prices continue to remain strong throughout the first quarter.
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At February 22, 2022, Matador had approximately 54.7 billion cubic feet of natural gas hedged for full year 2022, or about 55 to 60% of its anticipated 2022 natural gas production, using costless collars with a weighted average floor price of approximately $3.07 per MMBtu and a weighted average ceiling price of approximately $5.81 per MMBtu. Please see the accompanying presentation for a more complete summary of Matador’s current natural gas derivatives positions.
Operating Expenses
On a unit of production basis:
•Production taxes, transportation and processing expenses increased 10% sequentially from $5.90 per BOE in the third quarter of 2021 to $6.48 per BOE in the fourth quarter of 2021. This increase was primarily attributable to increased production taxes associated with oil and natural gas revenues of $510.8 million, an all-time quarterly high, reported by Matador in the fourth quarter.
•Lease operating expenses remained relatively flat sequentially at $3.34 per BOE in the fourth quarter of 2021, as compared to $3.31 per BOE in the third quarter of 2021. Lease operating expenses decreased 9% year-over-year from $3.81 per BOE for the year ended December 31, 2020 to $3.46 per BOE for the year ended December 31, 2021, marking the lowest annual lease operating expenses on a unit of production basis in the Company’s history.
•General and administrative expenses increased 6% sequentially from $2.97 per BOE in the third quarter of 2021 to $3.14 per BOE in the fourth quarter of 2021. General and administrative expenses in the fourth quarter reflected the reinstatement of employee compensation beginning in March 2021, which had been previously reduced by the Board and staff in March 2020 in response to the significantly lower oil and natural gas price environment at that time. The increase also reflects increased year-end bonus payments made to Matador’s employees in 2021. No bonuses were awarded to Matador management and staff in 2020.
San Mateo Highlights and Update
Operating Highlights and Financial Results
San Mateo operations in the fourth quarter of 2021 were highlighted by better-than-expected operating and financial results. Operationally, water handling volumes were at an all-time high of 313,000 barrels per day, a 10% sequential increase from the third quarter of 2021, and natural gas gathering and processing volumes were both up about 2% sequentially during the fourth quarter as well. Fourth quarter 2021 volumes do not include the full quantity of volumes that would have otherwise been delivered by certain San Mateo customers subject to minimum volume commitments (although partial deliveries were made in the fourth quarter), but for which San Mateo recognized revenues during the fourth quarter of 2021.
Operating Highlights
During the fourth quarter of 2021, San Mateo:
•Gathered an average of 252 million cubic feet of natural gas per day, a 2% sequential increase, as compared to 248 million cubic feet per day in the third quarter of 2021, and a 17% year-over-year increase, as compared to 216 million cubic feet per day in the fourth quarter of 2020.
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•Processed an average of 236 million cubic feet of natural gas per day at the Black River Processing Plant, a 2% sequential increase, as compared to 232 million cubic feet per day in the third quarter of 2021, and a 35% year-over-year increase, as compared to 175 million cubic feet per day in the fourth quarter of 2020.
•Gathered and transported an average of 41,800 barrels of oil per day, a 2% decrease, as compared to 42,500 barrels per day in both the third quarter of 2021 and the fourth quarter of 2020.
•Handled an average of 313,000 barrels of produced water per day, a 10% sequential increase, as compared to 284,000 barrels per day in the third quarter of 2021, and a 20% year-over-year increase, as compared to 260,000 barrels per day in the fourth quarter of 2020.
Financial Results
During the fourth quarter of 2021, San Mateo achieved record financial results, including:
•Net income (GAAP basis) of $33.6 million, a 14% sequential increase from $29.5 million in the third quarter of 2021, and a 28% year-over-year increase from $26.2 million in the fourth quarter of 2020. This quarterly result was a record high for San Mateo and above the Company’s expectations for the fourth quarter, primarily resulting from stronger-than-expected throughput volumes.
•Adjusted EBITDA (a non-GAAP financial measure) of $43.6 million, a 7% sequential increase from $40.8 million in the third quarter of 2021, and a 23% year-over-year increase from $35.4 million in the fourth quarter of 2020. This quarterly result was a record high for San Mateo and above the Company’s expectations for the fourth quarter for the reasons noted above.
•Net cash provided by San Mateo operating activities (GAAP basis) of $33.1 million, leading to San Mateo adjusted free cash flow (a non-GAAP financial measure) of $28.9 million.
•In early 2022, San Mateo repaid $30 million in borrowings outstanding under its credit facility. Total borrowings outstanding under the San Mateo credit facility at February 22, 2022 were $355 million. The San Mateo credit facility is non-recourse with respect to Matador.
For the year ended December 31, 2021, San Mateo also achieved record financial results, including:
•Net income (GAAP basis) of $113.6 million, a 40% sequential increase from $80.9 million for full year 2020.
•Adjusted EBITDA (a non-GAAP financial measure) of $154.3 million, a 37% sequential increase from $112.7 million for full year 2020.
•Net cash provided by San Mateo operating activities (GAAP basis) of $143.7 million, leading to San Mateo adjusted free cash flow (a non-GAAP financial measure) of $87.0 million.
Capital Expenditures
Matador’s portion of San Mateo’s capital expenditures was approximately $7 million in the fourth quarter of 2021, about $9 million less than the Company’s estimate of $16 million for the fourth quarter, primarily attributable to both cost savings on completed projects and the timing of operations. For full year 2021, Matador’s portion of San Mateo’s capital expenditures was approximately $31 million, or about 23% below the midpoint of Matador’s guidance of $40 million for its portion of San Mateo’s full year 2021 capital expenditures.
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Environmental, Social and Governance (“ESG”) Update
Matador is committed to creating long-term value for its stakeholders in a responsible manner by pursuing sound growth and earnings objectives and exercising prudence in the use of its assets and resources. During 2021, Matador continued its efforts to highlight the Company’s commitment to ESG excellence. In May 2021, Matador published sustainability metrics aligned with standards developed by the Sustainability Accounting Standards Board (“SASB”), and in July 2021, Matador published an update providing supplemental information to the Company’s initial report on these SASB-aligned ESG metrics.
In December 2021, Matador was pleased to issue its inaugural Sustainability Report in an effort to further raise the profile of Matador’s ongoing ESG-related initiatives. This report highlights Matador’s continued progress and improvements in its operating practices, including the quantitative metrics aligned with the SASB standards noted above, and should provide Matador’s stakeholders and interested parties with a standardized platform for evaluating the Company’s recent performance and future progress. Matador’s inaugural Sustainability Report, including the SASB-aligned sustainability metrics, is available on the Company’s website at www.matadorresources.com/sustainability.
Matador is also pleased to report today on its continued commitment to safety throughout its operations. Once again, Matador incurred no employee lost time incidents during approximately 600,000 employee man-hours in 2021. The Company has not incurred a recordable employee injury since 2014, and, over the last five years, from 2017 through 2021, Matador has incurred no employee lost time incidents during approximately 2.7 million employee man-hours. Matador gratefully acknowledges the conscientious efforts of its Environmental, Health and Safety team and of the experienced field and office staff involved in the Company’s drilling, completions, production and midstream operations to proactively minimize environmental hazards and safety risks, address any potential areas of concern and continuously emphasize Matador’s “safety first” culture.
Conference Call Information
The Company will host a live conference call on Wednesday, February 23, 2022, at 9:00 a.m. Central Time to discuss its fourth quarter and full year 2021 financial and operational results, as well as its 2022 operating plan and market guidance. To access the live conference call, domestic participants should dial (855) 875-8781 and international participants should dial (720) 634-2925. The participant passcode is 5787287. The live conference call will also be available through the Company’s website at www.matadorresources.com on the Events and Presentations page under the Investor Relations tab. The replay of the event will also be available on the Company’s website through March 31, 2022.
About Matador Resources Company
Matador is an independent energy company engaged in the exploration, development, production and acquisition of oil and natural gas resources in the United States, with an emphasis on oil and natural gas shale and other unconventional plays. Its 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. Matador also operates in the Eagle Ford shale play in South Texas and the Haynesville shale and Cotton Valley plays in Northwest Louisiana. Additionally, Matador conducts midstream operations, primarily through its midstream joint venture, San Mateo, in support of its exploration, development and production operations and provides natural gas processing, oil transportation services, natural gas, oil and produced water gathering services and produced water disposal services to third parties.
For more information, visit Matador Resources Company at www.matadorresources.com.
Forward-Looking Statements
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This press release includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. “Forward-looking statements” are statements related to future, not past, events. Forward-looking statements are based on current expectations and include any statement that does not directly relate to a current or historical fact. In this context, forward-looking statements often address expected future business and financial performance, and often contain words such as “could,” “believe,” “would,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “should,” “continue,” “plan,” “predict,” “potential,” “project,” “hypothetical,” “forecasted” and similar expressions that are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Such forward-looking statements include, but are not limited to, statements about guidance, projected or forecasted financial and operating results, future liquidity, the payment of dividends, results in certain basins, objectives, project timing, expectations and intentions, regulatory and governmental actions and other statements that are not historical facts. Actual results and future events could differ materially from those anticipated in such statements, and such forward-looking statements may not prove to be accurate. These forward-looking statements involve certain risks and uncertainties, including, but not limited to, the following risks related to financial and operational performance: general economic conditions; the Company’s ability to execute its business plan, including whether its drilling program is successful; changes in oil, natural gas and natural gas liquids prices and the demand for oil, natural gas and natural gas liquids; its ability to replace reserves and efficiently develop current reserves; costs of operations; delays and other difficulties related to producing oil, natural gas and natural gas liquids; delays and other difficulties related to regulatory and governmental approvals and restrictions; impact on the Company’s operations due to seismic events; its ability to make acquisitions on economically acceptable terms; its ability to integrate acquisitions; availability of sufficient capital to execute its business plan, including from future cash flows, increases in its borrowing base and otherwise; weather and environmental conditions; the impact of the worldwide spread of the novel coronavirus, or COVID-19, on oil and natural gas demand, oil and natural gas prices and its business; the operating results of the Company’s midstream joint venture’s Black River cryogenic natural gas processing plant; the timing and operating results of the buildout by the Company’s midstream joint venture of oil, natural gas and water gathering and transportation systems and the drilling of any additional produced water disposal wells; and other important factors that could cause actual results to differ materially from those anticipated or implied in the forward-looking statements. For further discussions of risks and uncertainties, you should refer to Matador’s filings with the Securities and Exchange Commission (“SEC”), including the “Risk Factors” section of Matador’s most recent Annual Report on Form 10-K and any subsequent Quarterly Reports on Form 10-Q. Matador undertakes no obligation to update these forward-looking statements to reflect events or circumstances occurring after the date of this press release, except as required by law, including the securities laws of the United States and the rules and regulations of the SEC. You are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date of this press release. All forward-looking statements are qualified in their entirety by this cautionary statement.
Contact Information
Mac Schmitz
Capital Markets Coordinator
(972) 371-5225
investors@matadorresources.com
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Matador Resources Company and Subsidiaries
CONSOLIDATED BALANCE SHEETS - UNAUDITED
| (In thousands, except par value and share data) | December 31, | ||||||||||||||||
| 2021 | 2020 | ||||||||||||||||
| ASSETS | |||||||||||||||||
| Current assets | |||||||||||||||||
| Cash | $ | 48,135 | $ | 57,916 | |||||||||||||
| Restricted cash | 38,785 | 33,467 | |||||||||||||||
| Accounts receivable | |||||||||||||||||
| Oil and natural gas revenues | 164,242 | 85,098 | |||||||||||||||
| Joint interest billings | 48,366 | 34,823 | |||||||||||||||
| Other | 28,808 | 17,212 | |||||||||||||||
| Derivative instruments | 1,971 | 6,727 | |||||||||||||||
| Lease and well equipment inventory | 12,188 | 10,584 | |||||||||||||||
| Prepaid expenses and other current assets | 28,810 | 15,802 | |||||||||||||||
| Total current assets | 371,305 | 261,629 | |||||||||||||||
| Property and equipment, at cost | |||||||||||||||||
| Oil and natural gas properties, full-cost method | |||||||||||||||||
| Evaluated | 6,007,325 | 5,295,931 | |||||||||||||||
| Unproved and unevaluated | 964,714 | 902,133 | |||||||||||||||
| Midstream properties | 900,979 | 841,695 | |||||||||||||||
| Other property and equipment | 30,123 | 29,561 | |||||||||||||||
| Less accumulated depletion, depreciation and amortization | (4,046,456) | (3,701,551) | |||||||||||||||
| Net property and equipment | 3,856,685 | 3,367,769 | |||||||||||||||
| Other assets | |||||||||||||||||
| Derivative instruments | — | 2,570 | |||||||||||||||
| Other long-term assets | 34,163 | 55,312 | |||||||||||||||
| Total assets | $ | 4,262,153 | $ | 3,687,280 | |||||||||||||
| LIABILITIES AND SHAREHOLDERS’ EQUITY | |||||||||||||||||
| Current liabilities | |||||||||||||||||
| Accounts payable | $ | 26,256 | $ | 13,982 | |||||||||||||
| Accrued liabilities | 253,283 | 119,158 | |||||||||||||||
| Royalties payable | 94,359 | 66,049 | |||||||||||||||
| Amounts due to affiliates | 27,324 | 4,934 | |||||||||||||||
| Derivative instruments | 16,849 | 45,186 | |||||||||||||||
| Advances from joint interest owners | 18,074 | 4,191 | |||||||||||||||
| Other current liabilities | 28,692 | 37,436 | |||||||||||||||
| Total current liabilities | 464,837 | 290,936 | |||||||||||||||
| Long-term liabilities | |||||||||||||||||
| Borrowings under Credit Agreement | 100,000 | 440,000 | |||||||||||||||
| Borrowings under San Mateo Credit Facility | 385,000 | 334,000 | |||||||||||||||
| Senior unsecured notes payable | 1,042,580 | 1,040,998 | |||||||||||||||
| Asset retirement obligations | 41,689 | 37,919 | |||||||||||||||
| Deferred income taxes | 77,938 | — | |||||||||||||||
| Other long-term liabilities | 22,721 | 30,402 | |||||||||||||||
| Total long-term liabilities | 1,669,928 | 1,883,319 | |||||||||||||||
| Shareholders’ equity | |||||||||||||||||
| Common stock — $0.01 par value, 160,000,000 shares authorized; 117,861,923 and 116,847,003 shares issued; and 117,850,233 and 116,844,768 shares outstanding, respectively | 1,179 | 1,169 | |||||||||||||||
| Additional paid-in capital | 2,077,592 | 2,027,069 | |||||||||||||||
| Accumulated deficit | (171,318) | (741,705) | |||||||||||||||
| Treasury stock, at cost, 11,945 and 2,235 shares, respectively | (243) | (3) | |||||||||||||||
| Total Matador Resources Company shareholders’ equity | 1,907,210 | 1,286,530 | |||||||||||||||
| Non-controlling interest in subsidiaries | 220,178 | 226,495 | |||||||||||||||
| Total shareholders’ equity | 2,127,388 | 1,513,025 | |||||||||||||||
| Total liabilities and shareholders’ equity | $ | 4,262,153 | $ | 3,687,280 | |||||||||||||
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Matador Resources Company and Subsidiaries
CONSOLIDATED STATEMENTS OF OPERATIONS - UNAUDITED
| (In thousands, except per share data) | Three Months Ended December 31, | Year Ended December 31, | ||||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | |||||||||||||||||||||||
| Revenues | ||||||||||||||||||||||||||
| Oil and natural gas revenues | $ | 510,770 | $ | 238,676 | $ | 1,700,542 | $ | 744,461 | ||||||||||||||||||
| Third-party midstream services revenues | 19,725 | 15,071 | 75,499 | 64,932 | ||||||||||||||||||||||
| Sales of purchased natural gas | 31,836 | 3,859 | 86,034 | 41,742 | ||||||||||||||||||||||
| Lease bonus - mineral acreage | — | — | — | 4,062 | ||||||||||||||||||||||
| Realized (loss) gain on derivatives | (94,162) | (10,634) | (220,105) | 38,937 | ||||||||||||||||||||||
| Unrealized gain (loss) on derivatives | 98,189 | (22,737) | 21,011 | (32,008) | ||||||||||||||||||||||
| Total revenues | 566,358 | 224,235 | 1,662,981 | 862,126 | ||||||||||||||||||||||
| Expenses | ||||||||||||||||||||||||||
| Production taxes, transportation and processing | 52,074 | 26,985 | 178,987 | 93,338 | ||||||||||||||||||||||
| Lease operating | 26,840 | 24,489 | 108,964 | 104,953 | ||||||||||||||||||||||
| Plant and other midstream services operating | 17,007 | 12,371 | 61,459 | 41,500 | ||||||||||||||||||||||
| Purchased natural gas | 30,062 | 2,610 | 77,126 | 32,734 | ||||||||||||||||||||||
| Depletion, depreciation and amortization | 89,537 | 89,749 | 344,905 | 361,831 | ||||||||||||||||||||||
| Accretion of asset retirement obligations | 539 | 499 | 2,068 | 1,948 | ||||||||||||||||||||||
| Full-cost ceiling impairment | — | 109,579 | — | 684,743 | ||||||||||||||||||||||
| General and administrative | 25,178 | 16,533 | 96,396 | 62,578 | ||||||||||||||||||||||
| Total expenses | 241,237 | 282,815 | 869,905 | 1,383,625 | ||||||||||||||||||||||
| Operating income (loss) | 325,121 | (58,580) | 793,076 | (521,499) | ||||||||||||||||||||||
| Other income (expense) | ||||||||||||||||||||||||||
| Net loss on asset sales and impairment | (80) | (200) | (331) | (2,832) | ||||||||||||||||||||||
| Interest expense | (19,108) | (20,352) | (74,687) | (76,692) | ||||||||||||||||||||||
| Other (expense) income | (1,466) | 309 | (2,712) | 1,864 | ||||||||||||||||||||||
| Total other expense | (20,654) | (20,243) | (77,730) | (77,660) | ||||||||||||||||||||||
| Income (loss) before income taxes | 304,467 | (78,823) | 715,346 | (599,159) | ||||||||||||||||||||||
| Income tax provision (benefit) | ||||||||||||||||||||||||||
| Deferred | 73,222 | (2,230) | 74,710 | (45,599) | ||||||||||||||||||||||
| Total income tax provision (benefit) | 73,222 | (2,230) | 74,710 | (45,599) | ||||||||||||||||||||||
| Net income (loss) | 231,245 | (76,593) | 640,636 | (553,560) | ||||||||||||||||||||||
| Net income attributable to non-controlling interest in subsidiaries | (16,455) | (12,861) | (55,668) | (39,645) | ||||||||||||||||||||||
| Net income (loss) attributable to Matador Resources Company shareholders | $ | 214,790 | $ | (89,454) | $ | 584,968 | $ | (593,205) | ||||||||||||||||||
| Earnings (loss) per common share | ||||||||||||||||||||||||||
| Basic | $ | 1.83 | $ | (0.77) | $ | 5.00 | $ | (5.11) | ||||||||||||||||||
| Diluted | $ | 1.80 | $ | (0.77) | $ | 4.91 | $ | (5.11) | ||||||||||||||||||
| Weighted average common shares outstanding | ||||||||||||||||||||||||||
| Basic | 117,384 | 116,163 | 116,999 | 116,068 | ||||||||||||||||||||||
| Diluted | 119,575 | 116,163 | 119,163 | 116,068 | ||||||||||||||||||||||
15
Matador Resources Company and Subsidiaries
CONSOLIDATED STATEMENTS OF CASH FLOWS - UNAUDITED
| (In thousands) | Three Months Ended December 31, | Year Ended December 31, | ||||||||||||||||||||||||||||||
| 2021 | 2020 | 2021 | 2020 | |||||||||||||||||||||||||||||
| Operating activities | ||||||||||||||||||||||||||||||||
| Net income (loss) | $ | 231,245 | $ | (76,593) | $ | 640,636 | $ | (553,560) | ||||||||||||||||||||||||
| Adjustments to reconcile net income (loss) to net cash provided by operating activities | ||||||||||||||||||||||||||||||||
| Unrealized (gain) loss on derivatives | (98,189) | 22,737 | (21,011) | 32,008 | ||||||||||||||||||||||||||||
| Depletion, depreciation and amortization | 89,537 | 89,749 | 344,905 | 361,831 | ||||||||||||||||||||||||||||
| Accretion of asset retirement obligations | 539 | 499 | 2,068 | 1,948 | ||||||||||||||||||||||||||||
| Full-cost ceiling impairment | — | 109,579 | — | 684,743 | ||||||||||||||||||||||||||||
| Stock-based compensation expense | 3,422 | 3,176 | 9,039 | 13,625 | ||||||||||||||||||||||||||||
| Deferred income tax provision (benefit) | 73,222 | (2,230) | 74,710 | (45,599) | ||||||||||||||||||||||||||||
| Amortization of debt issuance cost | 1,216 | 718 | 3,659 | 2,832 | ||||||||||||||||||||||||||||
| Net loss on asset sales and impairment | 80 | 200 | 331 | 2,832 | ||||||||||||||||||||||||||||
| Changes in operating assets and liabilities | ||||||||||||||||||||||||||||||||
| Accounts receivable | 12,765 | 941 | (98,456) | 53,001 | ||||||||||||||||||||||||||||
| Lease and well equipment inventory | (358) | (23) | (1,537) | (655) | ||||||||||||||||||||||||||||
| Prepaid expenses and other current assets | (2,271) | (2,599) | (11,786) | (3,010) | ||||||||||||||||||||||||||||
| Other long-term assets | (581) | (103) | 56 | 1,681 | ||||||||||||||||||||||||||||
| Accounts payable, accrued liabilities and other current liabilities | 16,272 | 17,608 | 76,891 | (43,844) | ||||||||||||||||||||||||||||
| Royalties payable | 2,997 | (2,274) | 28,310 | (19,144) | ||||||||||||||||||||||||||||
| Advances from joint interest owners | 5,869 | (3,521) | 7,018 | (10,646) | ||||||||||||||||||||||||||||
| Other long-term liabilities | (1,236) | (241) | (1,478) | (461) | ||||||||||||||||||||||||||||
| Net cash provided by operating activities | 334,529 | 157,623 | 1,053,355 | 477,582 | ||||||||||||||||||||||||||||
| Investing activities | ||||||||||||||||||||||||||||||||
| Drilling, completion and equipping capital expenditures | (113,650) | (70,531) | (431,136) | (471,087) | ||||||||||||||||||||||||||||
| Acquisition of oil and natural gas properties | (208,889) | (7,374) | (238,609) | (72,809) | ||||||||||||||||||||||||||||
| Midstream capital expenditures | (23,137) | (36,417) | (63,359) | (234,359) | ||||||||||||||||||||||||||||
| Expenditures for other property and equipment | 89 | (404) | (376) | (2,200) | ||||||||||||||||||||||||||||
| Proceeds from sale of assets | — | 215 | 4,215 | 4,789 | ||||||||||||||||||||||||||||
| Net cash used in investing activities | (345,587) | (114,511) | (729,265) | (775,666) | ||||||||||||||||||||||||||||
| Financing activities | ||||||||||||||||||||||||||||||||
| Repayments of borrowings under Credit Agreement | (210,000) | (35,000) | (600,000) | (35,000) | ||||||||||||||||||||||||||||
| Borrowings under Credit Agreement | 190,000 | — | 260,000 | 220,000 | ||||||||||||||||||||||||||||
| Repayments of borrowings under San Mateo Credit Facility | (20,000) | — | (84,000) | — | ||||||||||||||||||||||||||||
| Borrowings under San Mateo Credit Facility | 47,500 | 7,600 | 135,000 | 46,000 | ||||||||||||||||||||||||||||
| Cost to enter into or amend credit facilities | (3,230) | — | (4,108) | (660) | ||||||||||||||||||||||||||||
| Proceeds from stock options exercised | 1,122 | — | 1,335 | 45 | ||||||||||||||||||||||||||||
| Dividends paid | (5,840) | — | (14,581) | — | ||||||||||||||||||||||||||||
| Contributions related to formation of San Mateo | 11,000 | — | 48,626 | 14,700 | ||||||||||||||||||||||||||||
| Contributions from non-controlling interest owners of less-than-wholly-owned subsidiaries | — | 20,678 | — | 119,700 | ||||||||||||||||||||||||||||
| Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries | (16,170) | (12,740) | (61,985) | (45,570) | ||||||||||||||||||||||||||||
| Taxes paid related to net share settlement of stock-based compensation | (4,050) | — | (8,211) | (1,556) | ||||||||||||||||||||||||||||
| Other | (145) | (170) | (629) | 6,680 | ||||||||||||||||||||||||||||
| Net cash (used in) provided by financing activities | (9,813) | (19,632) | (328,553) | 324,339 | ||||||||||||||||||||||||||||
| (Decrease) increase in cash and restricted cash | (20,871) | 23,480 | (4,463) | 26,255 | ||||||||||||||||||||||||||||
| Cash and restricted cash at beginning of period | 107,791 | 67,903 | 91,383 | 65,128 | ||||||||||||||||||||||||||||
| Cash and restricted cash at end of period | $ | 86,920 | $ | 91,383 | $ | 86,920 | $ | 91,383 | ||||||||||||||||||||||||
16
Supplemental Non-GAAP Financial Measures
Adjusted EBITDA
This press release includes the non-GAAP financial measure of Adjusted EBITDA. Adjusted EBITDA is a supplemental non-GAAP financial measure that is used by management and external users of the Company’s consolidated financial statements, such as securities analysts, investors, lenders and rating agencies. “GAAP” means Generally Accepted Accounting Principles in the United States of America. The Company believes Adjusted EBITDA helps it evaluate its operating performance and compare its results of operations from period to period without regard to its financing methods or capital structure. The Company defines, on a consolidated basis and for San Mateo, Adjusted EBITDA as earnings before interest expense, income taxes, depletion, depreciation and amortization, accretion of asset retirement obligations, property impairments, unrealized derivative gains and losses, certain other non-cash items and non-cash stock-based compensation expense and net gain or loss on asset sales and impairment. Adjusted EBITDA is not a measure of net income (loss), or net cash provided by operating activities as determined by GAAP. All references to Matador’s Adjusted EBITDA are those values attributable to Matador Resources Company shareholders after giving effect to Adjusted EBITDA attributable to third-party non-controlling interests, including in San Mateo.
Adjusted EBITDA should not be considered an alternative to, or more meaningful than, net income (loss) or net cash provided by operating activities as determined in accordance with GAAP or as an indicator of the Company’s 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. 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 the calculation of Adjusted EBITDA and the reconciliation of Adjusted EBITDA to the GAAP financial measures of net income (loss) and net cash provided by operating activities, respectively, that are of a historical nature. Where references are pro forma, forward-looking, preliminary or prospective in nature, and not based on historical fact, the table does not provide a reconciliation. The Company could not provide such reconciliation without undue hardship because such Adjusted EBITDA numbers are estimations, approximations and/or ranges. In addition, it would be difficult for the Company to present a detailed reconciliation on account of many unknown variables for the reconciling items, including future income taxes, full-cost ceiling impairments, unrealized gains or losses on derivatives and gains or losses on asset sales and impairment. For the same reasons, the Company is unable to address the probable significance of the unavailable information, which could be material to future results.
17
| Three Months Ended | Year Ended | |||||||||||||||||||||||||||||||
| (In thousands) | December 31, 2021 | September 30, 2021 | December 31, 2020 | December 31, 2021 | December 31, 2020 | |||||||||||||||||||||||||||
| Unaudited Adjusted EBITDA Reconciliation to Net Income (Loss): | ||||||||||||||||||||||||||||||||
| Net income (loss) attributable to Matador Resources Company shareholders | $ | 214,790 | $ | 203,628 | $ | (89,454) | $ | 584,968 | $ | (593,205) | ||||||||||||||||||||||
| Net income attributable to non-controlling interest in subsidiaries | 16,455 | 14,434 | 12,861 | 55,668 | 39,645 | |||||||||||||||||||||||||||
| Net income (loss) | 231,245 | 218,062 | (76,593) | 640,636 | (553,560) | |||||||||||||||||||||||||||
| Interest expense | 19,108 | 17,989 | 20,352 | 74,687 | 76,692 | |||||||||||||||||||||||||||
| Total income tax provision (benefit) | 73,222 | (6,701) | (2,230) | 74,710 | (45,599) | |||||||||||||||||||||||||||
| Depletion, depreciation and amortization | 89,537 | 89,061 | 89,749 | 344,905 | 361,831 | |||||||||||||||||||||||||||
| Accretion of asset retirement obligations | 539 | 518 | 499 | 2,068 | 1,948 | |||||||||||||||||||||||||||
| Full-cost ceiling impairment | — | — | 109,579 | — | 684,743 | |||||||||||||||||||||||||||
| Unrealized (gain) loss on derivatives | (98,189) | (9,049) | 22,737 | (21,011) | 32,008 | |||||||||||||||||||||||||||
| Non-cash stock-based compensation expense | 3,422 | 2,967 | 3,176 | 9,039 | 13,625 | |||||||||||||||||||||||||||
| Net loss on asset sales and impairment | 80 | 251 | 200 | 331 | 2,832 | |||||||||||||||||||||||||||
| Expense related to contingent consideration | 1,485 | — | — | 1,485 | — | |||||||||||||||||||||||||||
| Consolidated Adjusted EBITDA | 320,449 | 313,098 | 167,469 | 1,126,850 | 574,520 | |||||||||||||||||||||||||||
| Adjusted EBITDA attributable to non-controlling interest in subsidiaries | (21,382) | (19,273) | (17,350) | (74,877) | (55,243) | |||||||||||||||||||||||||||
| Adjusted EBITDA attributable to Matador Resources Company shareholders | $ | 299,067 | $ | 293,825 | $ | 150,119 | $ | 1,051,973 | $ | 519,277 | ||||||||||||||||||||||
| Three Months Ended | Year Ended | |||||||||||||||||||||||||||||||
| (In thousands) | December 31, 2021 | September 30, 2021 | December 31, 2020 | December 31, 2021 | December 31, 2020 | |||||||||||||||||||||||||||
| Unaudited Adjusted EBITDA Reconciliation to Net Cash Provided by Operating Activities: | ||||||||||||||||||||||||||||||||
| Net cash provided by operating activities | $ | 334,529 | $ | 291,231 | $ | 157,623 | $ | 1,053,355 | $ | 477,582 | ||||||||||||||||||||||
| Net change in operating assets and liabilities | (33,457) | 4,666 | (9,788) | 982 | 23,078 | |||||||||||||||||||||||||||
| Interest expense, net of non-cash portion | 17,892 | 17,201 | 19,634 | 71,028 | 73,860 | |||||||||||||||||||||||||||
| Expense related to contingent consideration | 1,485 | — | — | 1,485 | — | |||||||||||||||||||||||||||
| Adjusted EBITDA attributable to non-controlling interest in subsidiaries | (21,382) | (19,273) | (17,350) | (74,877) | (55,243) | |||||||||||||||||||||||||||
| Adjusted EBITDA attributable to Matador Resources Company shareholders | $ | 299,067 | $ | 293,825 | $ | 150,119 | $ | 1,051,973 | $ | 519,277 | ||||||||||||||||||||||
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Adjusted EBITDA – San Mateo (100%)
| Three Months Ended | Year Ended | ||||||||||||||||||||||||||||
| (In thousands) | December 31, 2021 | September 30, 2021 | December 31, 2020 | December 31, 2021 | December 31, 2020 | ||||||||||||||||||||||||
| Unaudited Adjusted EBITDA Reconciliation to Net Income: | |||||||||||||||||||||||||||||
| Net income | $ | 33,583 | $ | 29,454 | $ | 26,247 | $ | 113,607 | $ | 80,910 | |||||||||||||||||||
| Depletion, depreciation and amortization | 7,808 | 7,609 | 7,277 | 30,522 | 22,485 | ||||||||||||||||||||||||
| Interest expense | 2,180 | 2,208 | 1,827 | 8,434 | 7,884 | ||||||||||||||||||||||||
| Accretion of asset retirement obligations | 66 | 61 | 56 | 247 | 200 | ||||||||||||||||||||||||
| One-time plant payment and impairment | — | 1,500 | — | 1,500 | 1,261 | ||||||||||||||||||||||||
| Adjusted EBITDA | $ | 43,637 | $ | 40,832 | $ | 35,407 | $ | 154,310 | $ | 112,740 | |||||||||||||||||||
| Three Months Ended | Year Ended | ||||||||||||||||||||||||||||
| (In thousands) | December 31, 2021 | September 30, 2021 | December 31, 2020 | December 31, 2021 | December 31, 2020 | ||||||||||||||||||||||||
| Unaudited Adjusted EBITDA Reconciliation to Net Cash Provided by Operating Activities: | |||||||||||||||||||||||||||||
| Net cash provided by operating activities | $ | 33,121 | $ | 44,164 | $ | 26,131 | $ | 143,744 | $ | 96,334 | |||||||||||||||||||
| Net change in operating assets and liabilities | 8,585 | (6,798) | 7,716 | 1,689 | 9,206 | ||||||||||||||||||||||||
| Interest expense, net of non-cash portion | 1,931 | 1,966 | 1,560 | 7,377 | 7,200 | ||||||||||||||||||||||||
| One-time plant payment | — | 1,500 | — | 1,500 | — | ||||||||||||||||||||||||
| Adjusted EBITDA | $ | 43,637 | $ | 40,832 | $ | 35,407 | $ | 154,310 | $ | 112,740 | |||||||||||||||||||
Adjusted Net Income and Adjusted Earnings Per Diluted Common Share
This press release includes the non-GAAP financial measures of adjusted net income and adjusted earnings per diluted common share. These non-GAAP items are measured as net income (loss) attributable to Matador Resources Company shareholders, adjusted for dollar and per share impact of certain items, including unrealized gains or losses on derivatives, the impact of full cost-ceiling impairment charges, if any, and non-recurring transaction costs for certain acquisitions or other non-recurring expense items, along with the related tax effect for all periods. This non-GAAP financial information is provided as additional information for investors and is not in accordance with, or an alternative to, GAAP financial measures. Additionally, these non-GAAP financial measures may be different than similar measures used by other companies. The Company believes the presentation of adjusted net income and adjusted earnings per diluted common share provides useful information to investors, as it provides them an additional relevant comparison of the Company’s performance across periods and to the performance of the Company’s peers. In addition, these non-GAAP financial measures reflect adjustments for items of income and expense that are often excluded by industry analysts and other users of the Company’s financial statements in evaluating the Company’s performance. The table below reconciles adjusted net income and adjusted earnings per diluted common share to their most directly comparable GAAP measure of net income (loss) attributable to Matador Resources Company shareholders.
19
| Three Months Ended | |||||||||||||||||
| December 31, 2021 | September 30, 2021 | December 31, 2020 | |||||||||||||||
| (In thousands, except per share data) | |||||||||||||||||
| Unaudited Adjusted Net Income and Adjusted Earnings Per Common Share Reconciliation to Net Income (Loss): | |||||||||||||||||
| Net income (loss) attributable to Matador Resources Company shareholders | $ | 214,790 | $ | 203,628 | $ | (89,454) | |||||||||||
| Total income tax provision (benefit) | 73,222 | (6,701) | (2,230) | ||||||||||||||
Income (loss) attributable to Matador Resources shareholders before taxes (1) | 288,012 | 196,927 | (91,684) | ||||||||||||||
| Less non-recurring and unrealized charges to income (loss) before taxes: | |||||||||||||||||
| Full-cost ceiling impairment | — | — | 109,579 | ||||||||||||||
| Unrealized (gain) loss on derivatives | (98,189) | (9,049) | 22,737 | ||||||||||||||
| Net loss on asset sales and impairment | 80 | 251 | 200 | ||||||||||||||
| Expense related to contingent consideration | 1,485 | — | — | ||||||||||||||
| Adjusted income attributable to Matador Resources shareholders before taxes | 191,388 | 188,129 | 40,832 | ||||||||||||||
Income tax expense(1) | 40,191 | 39,507 | 8,575 | ||||||||||||||
| Adjusted net income attributable to Matador Resources Company shareholders (non-GAAP) | $ | 151,197 | $ | 148,622 | $ | 32,257 | |||||||||||
| Basic weighted average shares outstanding, without participating securities | 116,800 | 116,531 | 116,163 | ||||||||||||||
| Dilutive effect of participating securities | 584 | 477 | 677 | ||||||||||||||
| Weighted average shares outstanding, including participating securities - basic | 117,384 | 117,008 | 116,840 | ||||||||||||||
| Dilutive effect of options and restricted stock units | 2,191 | 2,189 | 704 | ||||||||||||||
| Weighted average common shares outstanding - diluted | 119,575 | 119,197 | 117,544 | ||||||||||||||
| Adjusted earnings per share attributable to Matador Resources shareholders (non-GAAP) | |||||||||||||||||
| Basic | $ | 1.29 | $ | 1.27 | $ | 0.28 | |||||||||||
| Diluted | $ | 1.26 | $ | 1.25 | $ | 0.27 | |||||||||||
(1)Estimated using federal statutory tax rate in effect for the period.
Adjusted Free Cash Flow
This press release includes the non-GAAP financial measure of adjusted free cash flow. This non-GAAP item is measured, on a consolidated basis for the Company and for San Mateo, as net cash provided by operating activities, adjusted for changes in working capital and cash performance incentives that are not included as operating cash flows, less cash flows used for capital expenditures, adjusted for changes in capital accruals. On a consolidated basis, these numbers are also adjusted for the cash flows related to non-controlling interest in subsidiaries that represent cash flows not attributable to Matador shareholders. Adjusted free cash flow should not be considered an alternative to, or more meaningful than, net cash provided by operating activities as determined in accordance with GAAP or an indicator of the Company’s liquidity. Adjusted free cash flow is used by the Company, securities analysts and investors as an indicator of the Company’s ability to manage its operating cash flow, internally fund its D/C/E capital expenditures, pay dividends and service or incur additional debt, without regard to the timing of settlement of either operating assets and liabilities or accounts payable related to capital expenditures. Additionally, this non-GAAP financial measure may be different than similar measures used by other companies. The Company believes the presentation of adjusted free cash flow provides useful information to investors, as it provides them an additional relevant comparison of the Company’s performance, sources and uses of capital associated with its operations across periods and to the performance of the Company’s peers. In addition, this non-GAAP financial measure reflects adjustments for items of cash flows that are often excluded by securities analysts and other users of the Company’s financial statements in evaluating the Company’s cash spend.
The table below reconciles adjusted free cash flow to its most directly comparable GAAP measure of net cash provided by operating activities. All references to Matador’s adjusted free cash flow are those values attributable to Matador shareholders after giving effect to adjusted free cash flow attributable to third-party non-controlling interests, including in San Mateo.
20
Adjusted Free Cash Flow – Matador Resources Company
| Three Months Ended | Year Ended | ||||||||||||||||||||||
| (In thousands) | December 31, 2021 | September 30, 2021 | December 31, 2020 | December 31, 2021 | |||||||||||||||||||
| Net cash provided by operating activities | $ | 334,529 | $ | 291,231 | $ | 157,623 | $ | 1,053,355 | |||||||||||||||
| Net change in operating assets and liabilities | (33,457) | 4,666 | (9,788) | 982 | |||||||||||||||||||
San Mateo discretionary cash flow attributable to non-controlling interest in subsidiaries(1) | (20,436) | (18,309) | (16,585) | (71,262) | |||||||||||||||||||
| Performance incentives received from Five Point | 11,000 | 6,000 | — | 48,626 | |||||||||||||||||||
| Total discretionary cash flow | 291,636 | 283,588 | 131,250 | 1,031,701 | |||||||||||||||||||
| Drilling, completion and equipping capital expenditures | 113,650 | 106,761 | 70,531 | 431,136 | |||||||||||||||||||
| Midstream capital expenditures | 23,137 | 15,130 | 36,417 | 63,359 | |||||||||||||||||||
| Expenditures for other property and equipment | (89) | 220 | 404 | 376 | |||||||||||||||||||
| Net change in capital accruals | 41,888 | 28,189 | (30,753) | 78,515 | |||||||||||||||||||
San Mateo accrual-based capital expenditures related to non-controlling interest in subsidiaries(2) | (6,261) | (14,185) | (6,083) | (28,614) | |||||||||||||||||||
Total accrual-based capital expenditures(3) | 172,325 | 136,115 | 70,516 | 544,772 | |||||||||||||||||||
| Adjusted free cash flow | $ | 119,311 | $ | 147,473 | $ | 60,734 | $ | 486,929 | |||||||||||||||
(1)Represents Five Point Energy LLC’s (“Five Point”) 49% interest in San Mateo discretionary cash flow, as computed below.
(2)Represents Five Point’s 49% interest in accrual-based San Mateo capital expenditures, as computed below.
(3)Represents drilling, completion and equipping costs, Matador’s share of San Mateo capital expenditures plus 100% of other immaterial midstream capital expenditures not associated with San Mateo.
Adjusted Free Cash Flow - San Mateo (100%)
| Three Months Ended | Year Ended | ||||||||||||||||||||||
| (In thousands) | December 31, 2021 | September 30, 2021 | December 31, 2020 | December 31, 2021 | |||||||||||||||||||
| Net cash provided by San Mateo operating activities | $ | 33,121 | $ | 44,164 | $ | 26,131 | $ | 143,744 | |||||||||||||||
| Net change in San Mateo operating assets and liabilities | 8,585 | (6,798) | 7,716 | 1,689 | |||||||||||||||||||
| Total San Mateo discretionary cash flow | 41,706 | 37,366 | 33,847 | 145,433 | |||||||||||||||||||
| San Mateo capital expenditures | 23,191 | 14,900 | 36,333 | 62,111 | |||||||||||||||||||
| Net change in San Mateo capital accruals | (10,413) | 14,048 | (23,919) | (3,716) | |||||||||||||||||||
| San Mateo accrual-based capital expenditures | 12,778 | 28,948 | 12,414 | 58,395 | |||||||||||||||||||
| San Mateo adjusted free cash flow | $ | 28,928 | $ | 8,418 | $ | 21,433 | $ | 87,038 | |||||||||||||||
PV-10
PV-10 is a non-GAAP financial measure and generally differs from Standardized Measure, the most directly comparable GAAP financial measure, because it does not include the effects of income taxes on future net revenues. PV-10 is not an estimate of the fair market value of the Company’s properties. Matador and others in the industry use PV-10 as a measure to compare the relative size and value of proved reserves held by companies and of the potential return on investment related to the companies’ properties without regard to the specific tax characteristics of such entities. PV-10 may be reconciled to the Standardized Measure of discounted future net cash flows at such dates by adding the discounted future income taxes associated with such reserves to the Standardized Measure.
21
The table below presents the reconciliation of PV-10 to Standardized Measure associated with the recently acquired properties referenced in the “Recent Acquisitions and Divestitures” section of this earnings release.
| (In millions) | At December 31, 2021 | |||||||
| Standardized Measure | $ | 186.1 | ||||||
| Discounted future income taxes | 41.0 | |||||||
| PV-10 | $ | 227.1 | ||||||
22
Exhibit 99.2
MATADOR RESOURCES COMPANY ANNOUNCES
2022 OPERATING PLAN AND MARKET GUIDANCE
DALLAS, Texas, February 22, 2022 -- Matador Resources Company (NYSE: MTDR) (“Matador” or the “Company”) today announced its full year 2022 operating plan and market guidance. A slide presentation summarizing Matador’s 2022 operating plan and market guidance is also included on the Company’s website at www.matadorresources.com on the Events and Presentations page under the Investor Relations tab. In a separate press release issued today, Matador also reported its financial and operating results for the fourth quarter and full year 2021.
Full Year 2022 Guidance Summary
Matador’s full year 2022 guidance estimates are summarized in the table below.
| Guidance Metric | Actual 2021 Results | 2022 Guidance Range | % YoY Change(1) | ||||||||
| Total Oil Production | 17.8 million Bbl(2) | 21.0 to 22.0 million Bbl | +21% | ||||||||
| Total Natural Gas Production | 81.7 Bcf(3) | 92.0 to 98.0 Bcf | +16% | ||||||||
| Total Oil Equivalent Production | 31.5 million BOE(4) | 36.3 to 38.3 million BOE | +19% | ||||||||
D/C/E CapEx(5) | $513 million | $640 to $710 million | +31% | ||||||||
Midstream CapEx(6) | $31 million | $50 to $60 million | +79% | ||||||||
| Total D/C/E and Midstream CapEx | $544 million | $690 to $770 million | +34% | ||||||||
(1) Represents percentage change from 2021 actual results to the midpoint of 2022 guidance range.
(2) One barrel of oil.
(3) One billion cubic feet of natural gas.
(4) One barrel of oil equivalent, estimated using a conversion factor of one barrel of oil per six thousand standard cubic feet of natural gas.
(5) Capital expenditures associated with drilling, completing and equipping wells.
(6) Primarily reflects Matador’s share of capital expenditures for San Mateo Midstream, LLC (“San Mateo”).
The full year 2022 guidance estimates presented in the table above are based upon the following key assumptions for 2022 drilling and completions activity and capital expenditures.
•Matador began 2022 operating five drilling rigs in the Delaware Basin. At February 22, 2022, the Company had contracted a sixth drilling rig to begin development of certain recently acquired properties in the western portion of its Ranger asset area in Lea County, New Mexico. The Company expects to operate these six drilling rigs across its various Delaware Basin asset areas throughout the remainder of 2022. Accounting for the anticipated impact of service cost inflation in 2022, the six-rig drilling program results in only a small increase to the Company’s expected 2022 capital expenditures for drilling, completing and equipping wells (“D/C/E capital expenditures”), as compared to the four-rig drilling program Matador conducted for the majority of 2021, primarily as a result of lower working interests associated with many of the wells Matador expects to drill and complete in 2022.
•Matador expects to turn to sales 80 gross (60.8 net) operated horizontal wells during 2022, all in the Delaware Basin, with an average completed lateral length of 9,850 feet. The Company estimates that 72 of these wells, or 90%, should have lateral lengths of two miles or greater.
•Matador expects to participate in 102 gross (8.9 net) non-operated wells that are anticipated to be turned to sales during 2022, almost all of which will be in the Delaware Basin, with an average completed lateral length of 9,000 feet. The Company estimates that 66 of these wells, or 65%, should have lateral lengths of two miles or greater and 98 of these wells, or 96%, should have lateral lengths greater than one mile.
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•Matador estimates 2022 D/C/E capital expenditures of $640 to $710 million, as further detailed in the table below. In preparing these estimates, Matador included a 10 to 15% inflationary increase in D/C/E capital expenditures from those incurred during the fourth quarter of 2021 in anticipation of further increases in oilfield service costs throughout 2022. As further noted in the table below, Matador also anticipates a significant increase in the non-operated component of its 2022 D/C/E capital expenditures, as compared to 2021, which is attributable to expected increases in non-operated drilling and completion activities on certain of its properties, as well as service cost inflation.
D/C/E CapEx(1) Components | Actual 2021 Results | 2022 CapEx Estimates | % YoY Change(2) | ||||||||
| Operated | $432 million | $510 to $550 million | +23% | ||||||||
| Non-Operated | $27 million | $70 to $80 million | +178% | ||||||||
| Artificial Lift / Other Production Related | $36 million | $40 to $50 million | +25% | ||||||||
| Capitalized G&A and Interest | $18 million | $20 to $30 million | +39% | ||||||||
| Total D/C/E CapEx | $513 million | $640 to $710 million | +32% | ||||||||
(1) Capital expenditures associated with drilling, completing and equipping wells.
(2) Represents percentage change from 2021 actual results to the midpoint of 2022 guidance range.
•Matador’s 2022 D/C/E capital expenditures include 29 gross (15.2 net) operated Delaware Basin wells expected to be in progress at year-end 2022, as compared to 33 gross (28.1 net) operated wells in progress at year-end 2021, and the capital expenditures associated with these wells in progress at year-end 2022 would not contribute to Matador’s production in 2022.
•Matador estimates 2022 midstream capital expenditures of $50 to $60 million. This estimate reflects Matador’s 51% share of San Mateo’s 2022 estimated capital expenditures of approximately $98 to $118 million. San Mateo’s 2022 capital expenditures include a variety of projects needed to provide service for newly drilled wells operated by Matador and other San Mateo customers. Should San Mateo be awarded new midstream contracts by customers other than Matador during 2022, additional capital expenditures may be required, and any necessary adjustments to San Mateo’s 2022 capital expenditures would be made at that time.
Management Comments Regarding 2022 Operating Plan
Joseph Wm. Foran, Matador’s Founder, Chairman and CEO, commented, “The Board, the staff and I are pleased today to provide our 2022 operating plan and market guidance. We believe that 2022 should again be rewarding for Matador and all of its stakeholders, as we continue developing our excellent Delaware Basin assets, generating significant free cash flow, paying down debt, evaluating potentially accretive acquisition opportunities and returning cash to shareholders through increases to the dividend as our performance allows. We were pleased to announce yesterday that Matador’s Board of Directors declared a quarterly cash dividend of $0.05 per share payable in March 2022, amounting to $0.20 per share on an annualized basis, and consistent with the doubling of our dividend in the fourth quarter of 2021, as compared to the first three quarters of 2021.
“We began 2022 operating five drilling rigs in the Delaware Basin but have recently contracted a sixth drilling rig to begin development of certain recently acquired assets in the western portion of our Ranger asset area in Lea County, New Mexico, which are ‘bolt on’ positions to the Company’s existing acreage. We plan to operate these six rigs across our various Delaware Basin asset areas throughout 2022, and the 2022 drilling program is expected to focus on opportunities throughout our various Delaware Basin assets. Although we expect to turn to sales 15 wells in the Stateline asset area and nine wells on the Rodney Robinson leasehold in 2022, we are also excited to return to the development of high-quality targets in the Antelope Ridge, Rustler Breaks and Ranger asset areas. As in recent
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years, Matador’s 2022 drilling program will continue to focus on longer laterals, with 90% of the operated horizontal wells we turn to sales in 2022 anticipated to have lateral lengths of two miles or greater.
“We are anticipating a number of key milestones in 2022, as we did in 2021, that are expected to add significant value, while also positioning Matador for continued growth and free cash flow in the coming years. The first of these milestones was recently accomplished when production was turned to sales from 11 new Voni wells in the Stateline asset area, all of which had completed lateral lengths of approximately 12,000 feet, or about 2.3 miles. The second milestone should be realized in mid-to-late March when we turn to sales production from nine new Rodney Robinson wells in the western portion of our Antelope Ridge asset area. During April and May, we expect to reach a third milestone when we turn to sales production from 11 new wells in the Rustler Breaks asset area. During the latter portion of the third quarter, we should realize our fourth key milestone for 2022, when we turn to sales production from 16 wells in the Antelope Ridge asset area outside of the Rodney Robinson leasehold. The fifth and final milestone for 2022 should occur in late November and December when we turn to sales production from 11 new wells in the Ranger asset area, including seven wells drilled on the recently acquired acreage in the Ranger asset area.
“San Mateo concluded a record financial quarter in the fourth quarter of 2021 and a record year in 2021 and is poised for additional growth in 2022 as well. San Mateo has become a very strategic component of Matador’s overall business strategy over the years, as well as a top provider of ‘three-pipe’ midstream services to its customers in the Delaware Basin. San Mateo expects to generate free cash flow again in 2022. As they did last year, the San Mateo team will be working hard in 2022 to add new customers and throughput volumes to its midstream system, which, if successful, may require additional capital expenditures in 2022, but should lead to additional economies of scale for its midstream system.
“The Board, the staff and I are confident in our abilities to efficiently execute this 2022 operating plan. We are excited about the 2022 milestones in front of us, and the year is off to a good start in that regard. As you will see in this release, we expect to have record production results again in 2022 and should oil and natural gas prices continue to remain strong throughout 2022, we believe our 2022 operating plan, in the capable hands of our office and field staff, should generate record financial results and free cash flow as well.”
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2022 Operating Plan
The table below provides Matador’s expectations for operated and non-operated wells to be turned to sales during 2022. Additional details regarding Matador’s drilling and completions program for 2022 are provided in the slide presentation accompanying this press release.
| Operated | Non-Operated | Total | Gross Operated | ||||||||||||||||||||||||||
| Asset/Operating Area | Gross | Net | Gross | Net | Gross | Net | Well Completion Intervals | ||||||||||||||||||||||
Western Antelope Ridge (Rodney Robinson) | 9 | 8.1 | - | - | 9 | 8.1 | 3-AVLN, 3-1BS, 2-2BS, 1-3BS | ||||||||||||||||||||||
Antelope Ridge (All Other) | 17 | 12.3 | 28 | 1.5 | 45 | 13.8 | 6-1BS, 8-2BS, 3-3BS | ||||||||||||||||||||||
| Arrowhead | 2 | 0.7 | 15 | 1.2 | 17 | 1.9 | 2-2BS | ||||||||||||||||||||||
| Ranger | 14 | 9.5 | 21 | 2.3 | 35 | 11.8 | 7-2BS, 4-3BS, 3-WC A | ||||||||||||||||||||||
| Rustler Breaks | 20 | 12.4 | 25 | 3.2 | 45 | 15.6 | 1-BYCN, 4-1BS, 7-2BS, 2-3BS, 2-WC A, 4-WC B | ||||||||||||||||||||||
| Stateline | 15 | 15.0 | - | - | 15 | 15.0 | 2-1BS, 5-3BS-Carb, 8-WC B | ||||||||||||||||||||||
| Wolf | 3 | 2.8 | - | - | 3 | 2.8 | 3-2BS | ||||||||||||||||||||||
| Delaware Basin | 80 | 60.8 | 89 | 8.2 | 169 | 69.0 | |||||||||||||||||||||||
| Eagle Ford Shale | - | - | - | - | - | - | No completions in 2022 | ||||||||||||||||||||||
| Haynesville Shale | - | - | 13 | 0.7 | 13 | 0.7 | No operated completions in 2022 | ||||||||||||||||||||||
| Total | 80 | 60.8 | 102 | 8.9 | 182 | 69.7 | |||||||||||||||||||||||
Note: AVLN = Avalon; BYCN = Brushy Canyon; BS = Bone Spring; BS-Carb = Bone Spring Carbonate; WC = Wolfcamp;. For example, 1-3BS indicates one Third Bone Spring completion and 3-WC A indicates three Wolfcamp A completions for full year 2022.
Matador expects to turn to sales 80 gross (60.8 net) operated wells in the Delaware Basin in 2022, as follows:
•25 gross (23.3 net) wells in the first quarter, including 11 wells in the Stateline asset area (the 11 Voni wells recently turned to sales), nine wells in the Rodney Robinson leasehold, two wells in the Ranger asset area and three wells in the Wolf asset area;
•12 gross (8.0 net) wells in the second quarter, including 11 wells in the Rustler Breaks asset area and one well in the Antelope Ridge asset area outside the Rodney Robinson leasehold;
•25 gross (19.0 net) wells in the third quarter, including 16 wells in the Antelope Ridge asset area outside the Rodney Robinson leasehold, four wells in the Stateline asset area (four Boros Wolfcamp B wells), four wells in the Rustler Breaks asset area and one well in the Ranger asset area; and
•18 gross (10.5 net) wells in the fourth quarter, including 11 wells in the Ranger asset area, five wells in the Rustler Breaks asset area and two wells in the southern portion of the Arrowhead asset area (the “Greater Stebbins Area”).
Additional important features of Matador’s 2022 Delaware Basin operating program are noted below.
•The average working interest of operated wells turned to sales in the Delaware Basin in 2022 is estimated to be 76%, as compared to 94% in 2021.
•Matador anticipates drilling and completion costs for operated horizontal wells turned to sales in 2022 to average approximately $845 per completed lateral foot. This represents a 14% increase in average drilling and
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completion costs per lateral foot, as compared to $738 per completed lateral foot in the fourth quarter of 2021, reflecting anticipated inflationary increases in service costs as well as fewer wells in the Stateline asset area. Although drilling and completion costs are expected to be higher in 2022, an average drilling and completion cost of $845 per completed lateral foot is approximately the same as the average of $850 per competed lateral foot that Matador achieved in 2020, and a 27% decline from $1,165 per completed lateral foot achieved in 2019. In fact, the average annual drilling and completion cost of $850 per completed lateral foot achieved in 2020 was the lowest average cost per completed lateral foot achieved by Matador until 2021, when the Company achieved its record-low average annual drilling and completion cost of $670 per completed lateral foot. Thus, while service costs have increased and may increase further in 2022, Matador still expects its 2022 drilling and completion program to be very capital efficient.
•Matador anticipates that it may be able to mitigate a portion of the anticipated service cost inflation expected during 2022 through continued improvements in its drilling and completion processes and further reducing the number of “days on well.” Utilization of next-generation shaped drill bit cutters combined with the increased performance and durability of downhole drilling motors has led to further drilling efficiencies resulting in several new area-specific drilling records as the Company has returned to drilling in its Antelope Ridge and Rustler Breaks asset areas in early 2022. Further, the Company continues to improve the efficiency of its hydraulic fracturing operations using new technologies and redefining conventional stimulation processes to achieve more effective pumping time and increase lateral footage completed per day. In the first quarter of 2021, Matador executed its first Simul-Frac completion resulting in a 40% increase in daily completed lateral footage on that well pad. Matador continued to use Simul-Frac wherever possible during 2021, increasing the daily completed lateral footage by an average of 50% on 23 of its wells, and the Company expects to continue using Simul-Frac in 2022. In addition, as Matador returns to previously drilled asset areas, the Company should benefit from the ability to use existing infrastructure, well pads and facilities, which should help to further mitigate increasing service costs.
Stateline Asset Area – Eddy County, New Mexico
At February 22, 2022, Matador had recently turned to sales the 11 Voni wells in the Stateline asset area as planned. Matador is not currently drilling in the Stateline asset area as the Company takes a planned pause from drilling and completion activities in that area for several months. Matador has turned to sales production from 50 wells in the Stateline asset area in the last 18 months and now plans to allow these wells to produce for several months before returning in May to drill and complete four additional Wolfcamp B wells. These four additional Boros wells are anticipated to be turned to sales late in the third quarter of 2022 and, consequently, will not contribute significantly to Matador’s production until the fourth quarter.
Antelope Ridge Asset Area – Lea County, New Mexico
Matador is currently completing nine wells on the Rodney Robinson leasehold in the western portion of the Antelope Ridge asset area, and these wells are expected to be turned to sales in mid-to-late March 2022. Matador also expects to actively drill other of its properties throughout the Antelope Ridge asset area in 2022 and especially during the first six months of 2022. The Company expects to turn to sales production from an additional 17 wells in the Antelope Ridge asset area outside the Rodney Robinson leasehold during 2022, with 16 of these wells anticipated to be turned to sales at various times during the latter half of the third quarter.
Rustler Breaks Asset Area – Eddy County, New Mexico
Matador expects to return to active development of its Rustler Breaks asset area in 2022 and anticipates operating one rig in this asset area throughout much of 2022. The 2022 drilling program in the Rustler Breaks asset area should be characterized by longer laterals with more focus on the development of primarily Bone Spring targets, as
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compared to most of the Company’s previous drilling campaigns in the Rustler Breaks asset area, which consisted primarily of one-mile laterals and Wolfcamp targets. Matador expects to turn to sales 20 wells in the Rustler Breaks asset area throughout the second, third and fourth quarters of 2022.
Ranger and Arrowhead Asset Areas – Lea and Eddy Counties, New Mexico
Matador plans increased activity in its Ranger asset area during 2022, resulting from the success of the four Uncle Ches wells turned to sales during 2021 and in early 2022, as well as the Company’s recent acquisition of “bolt on” properties to its existing leasehold in Lea County, New Mexico (please see the discussion of Recent Acquisitions and Divestitures in the Company’s Fourth Quarter 2021 earnings release issued on February 22, 2022 for additional details on the recently acquired properties). At February 22, 2022, Matador had contracted a sixth drilling rig to begin development of certain of these recently acquired properties in the Ranger asset area. Matador expects to turn to sales seven wells on these recently acquired properties at varying times during the fourth quarter of 2022.
Matador plans to drill and complete two additional wells in the Greater Stebbins Area beginning in May 2022, and these wells are expected to be turned to sales during the fourth quarter of 2022. The Company then expects to return to more active development of the Greater Stebbins Area in late 2022 and into 2023.
Wolf Asset Area – Loving County, Texas
At February 22, 2022, Matador had recently turned to sales production from three wells, all Second Bone Spring completions, in the Wolf asset area as anticipated. Matador plans to drill three additional wells in the Wolf asset area beginning in August 2022, but these wells are not expected to be turned to sales until early 2023.
2022 Production Estimates and Cadence
Oil, Natural Gas and Oil Equivalent Production Growth and Anticipated Cadence
Matador expects to continue drilling longer horizontal wells from multi-well pads in 2022, with 90% having lateral lengths of two miles or greater. This, in turn, is expected to result in an uneven cadence of wells being turned to sales in any given period, much like the Company has experienced over the last two years. As a result, Matador expects its production growth profile to continue to be uneven or “lumpy” from quarter to quarter.
The table below provides estimated ranges for Matador’s average daily oil, natural gas and total oil equivalent production on a quarterly basis throughout 2022, as compared to actual average daily oil, natural gas and total oil equivalent production in the fourth quarter of 2021. While the table below should provide a reasonable expectation of the Company’s production growth profile for 2022 as of February 22, 2022, the Company anticipates updating these quarterly estimates for the second quarter of 2022 and future periods throughout the year, as necessary to reflect its actual results and then-current estimates.
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2022 Quarterly Production Estimates | |||||||||||
| Period | Average Daily Total Production, BOE per day | Average Daily Oil Production, Bbl per day | Average Daily Natural Gas Production, MMcf per day | ||||||||
| Q4 2021 | 87,300 | 49,800 | 225.2 | ||||||||
| Q1 2022 | 91,500 to 92,500 | 52,000 to 52,600 | 236.0 to 240.0 | ||||||||
| Q2 2022 | 106,000 to 108,000 | 61,700 to 62,700 | 268.0 to 272.0 | ||||||||
| Q3 2022 | 100,000 to 102,000 | 58,000 to 59,000 | 254.0 to 258.0 | ||||||||
| Q4 2022 | 107,500 to 109,500 | 62,000 to 63,000 | 274.0 to 278.0 | ||||||||
Matador’s estimated 2022 total oil equivalent production of 37.3 million barrels of oil equivalent (“BOE”), or an average daily oil equivalent production of approximately 102,000 BOE per day (58% oil), at the midpoint of the 2022 guidance range, reflects a year-over-year increase of 19%, as compared to 31.5 million BOE (57% oil), or 86,200 BOE per day, produced in 2021. The Company anticipates its average daily oil equivalent production should increase 24% from 87,300 BOE per day in the fourth quarter of 2021 to approximately 108,500 BOE per day in the fourth quarter of 2022.
Matador’s estimated 2022 total oil production of 21.5 million barrels, or an average daily oil production of approximately 58,900 barrels of oil per day, at the midpoint of the 2022 guidance range, reflects an increase of 21%, as compared to 17.8 million barrels, or an average of 48,900 barrels of oil per day, produced in 2021. The Company anticipates its average daily oil production should increase 26% from 49,800 barrels of oil per day in the fourth quarter of 2021 to approximately 62,500 barrels of oil per day in the fourth quarter of 2022.
Matador’s estimated 2022 total natural gas production of 95.0 billion cubic feet, or an average daily natural gas production of approximately 260.3 million cubic feet per day, at the midpoint of the 2022 guidance range, reflects an increase of 16%, as compared to 81.7 billion cubic feet, or an average daily natural gas production of 223.8 million cubic feet per day, produced in 2021. The Company anticipates its average daily natural gas production should increase 23% from 225.2 million cubic feet per day in the fourth quarter of 2021 to approximately 276.0 million cubic feet per day in the fourth quarter of 2022.
Matador’s estimated 2022 total natural gas production of 95.0 billion cubic feet, or an average daily natural gas production of approximately 260.3 million cubic feet per day, at the midpoint of the 2022 guidance range, reflects an increase of 16%, as compared to 81.7 billion cubic feet, or an average daily natural gas production of 223.8 million cubic feet per day, produced in 2021. The Company anticipates its average daily natural gas production should increase 23% from 225.2 million cubic feet per day in the fourth quarter of 2021 to approximately 276.0 million cubic feet per day in the fourth quarter of 2022.
Delaware Basin Production Growth
Matador estimates total oil equivalent production of 35.6 million BOE (59% oil) from the Delaware Basin, or 97,500 BOE per day, at the midpoint of 2022 guidance, a year-over-year increase of 21% from 2021. The Company anticipates its total oil and natural gas production from the Delaware Basin should increase 22% and 20%, respectively, year-over-year, at the midpoint of 2022 production guidance.
First Quarter 2022 Production Estimates
As noted in the table above, Matador expects its average daily total production to increase 5% sequentially from 87,300 BOE per day in the fourth quarter of 2021 to approximately 92,000 BOE per day in the first quarter of 2022. The Company’s first quarter 2022 production volumes have been impacted by several factors that have deferred portions of its anticipated first quarter production into the second quarter of 2022, including (i) several Boros wells which were shut-in in the Stateline asset area while hydraulic fracturing operations were completed by another operator on offsetting wells; (ii) more wells than originally anticipated being shut-in on the Rodney Robinson leasehold while the Company conducts hydraulic fracturing operations on nine new wells there; (iii) periods of shut-in production in the Greater Stebbins Area attributable to artificial lift installations on several of the wells turned to
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sales in December 2021; and (iv) periods of shut-in production on certain of the recently acquired properties in the Ranger asset area resulting from the need to install and repair ESPs and to upgrade production facilities on these properties.
As a result of these factors, Matador’s average daily total production declined below fourth quarter 2021 levels in January and early February but increased sharply beginning in mid-February with the completion of certain of these operations and the initial production from a number of wells recently turned to sales, including the 11 new Voni wells. Matador’s average daily total production was approximately 84,000 BOE per day in January 2022 but is anticipated to be approximately 93,000 BOE per day in February and approach approximately 100,000 BOE per day in March, depending on when the nine Rodney Robinson wells are turned to sales. Further, as noted in the table above, Matador anticipates its second quarter 2022 average daily total production to increase sequentially by 15 to 17%, as compared to the first quarter of 2022, with average daily oil production anticipated to increase by 18 to 20%.
Conference Call Information
The Company will host a live conference call on Wednesday, February 23, 2022, at 9:00 a.m. Central Time to discuss its fourth quarter and full year 2021 financial and operational results, as well as its 2022 operating plan and market guidance. To access the live conference call, domestic participants should dial (855) 875-8781 and international participants should dial (720) 634-2925. The participant passcode is 5787287. The live conference call will also be available through the Company’s website at www.matadorresources.com on the Events and Presentations page under the Investor Relations tab. The replay of the event will also be available on the Company’s website through March 31, 2022.
About Matador Resources Company
Matador is an independent energy company engaged in the exploration, development, production and acquisition of oil and natural gas resources in the United States, with an emphasis on oil and natural gas shale and other unconventional plays. Its 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. Matador also operates in the Eagle Ford shale play in South Texas and the Haynesville shale and Cotton Valley plays in Northwest Louisiana. Additionally, Matador conducts midstream operations, primarily through its midstream joint venture, San Mateo, in support of its exploration, development and production operations and provides natural gas processing, oil transportation services, natural gas, oil and produced water gathering services and produced water disposal services to third parties.
For more information, visit Matador Resources Company at www.matadorresources.com.
Forward-Looking Statements
This press release includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended, and Section 21E of the Securities Exchange Act of 1934, as amended. “Forward-looking statements” are statements related to future, not past, events. Forward-looking statements are based on current expectations and include any statement that does not directly relate to a current or historical fact. In this context, forward-looking statements often address expected future business and financial performance, and often contain words such as “could,” “believe,” “would,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “should,” “continue,” “plan,” “predict,” “potential,” “project,” “hypothetical,” “forecasted” and similar expressions that are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. Such forward-looking statements include, but are not limited to, statements about guidance, projected or forecasted financial and operating results, future liquidity, the payment of dividends, results in certain basins, objectives, project timing, expectations and intentions, regulatory and governmental actions and other
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statements that are not historical facts. Actual results and future events could differ materially from those anticipated in such statements, and such forward-looking statements may not prove to be accurate. These forward-looking statements involve certain risks and uncertainties, including, but not limited to, the following risks related to financial and operational performance: general economic conditions; the Company’s ability to execute its business plan, including whether its drilling program is successful; changes in oil, natural gas and natural gas liquids prices and the demand for oil, natural gas and natural gas liquids; its ability to replace reserves and efficiently develop current reserves; costs of operations; delays and other difficulties related to producing oil, natural gas and natural gas liquids; delays and other difficulties related to regulatory and governmental approvals and restrictions; impact on the Company’s operations due to seismic events; its ability to make acquisitions on economically acceptable terms; its ability to integrate acquisitions; availability of sufficient capital to execute its business plan, including from future cash flows, increases in its borrowing base and otherwise; weather and environmental conditions; the impact of the worldwide spread of the novel coronavirus, or COVID-19, on oil and natural gas demand, oil and natural gas prices and its business; the operating results of the Company’s midstream joint venture’s Black River cryogenic natural gas processing plant; the timing and operating results of the buildout by the Company’s midstream joint venture of oil, natural gas and water gathering and transportation systems and the drilling of any additional produced water disposal wells; and other important factors that could cause actual results to differ materially from those anticipated or implied in the forward-looking statements. For further discussions of risks and uncertainties, you should refer to Matador’s filings with the Securities and Exchange Commission (“SEC”), including the “Risk Factors” section of Matador’s most recent Annual Report on Form 10-K and any subsequent Quarterly Reports on Form 10-Q. Matador undertakes no obligation to update these forward-looking statements to reflect events or circumstances occurring after the date of this press release, except as required by law, including the securities laws of the United States and the rules and regulations of the SEC. You are cautioned not to place undue reliance on these forward-looking statements, which speak only as of the date of this press release. All forward-looking statements are qualified in their entirety by this cautionary statement.
Contact Information
Mac Schmitz
Capital Markets Coordinator
(972) 371-5225
investors@matadorresources.com
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