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 23, 2021
_________________________________
(Exact name of registrant as specified in its charter)
_________________________________
| (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)
_________________________________
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 23, 2021, announcing its financial results for the three and twelve months ended December 31, 2020. The Earnings Press Release includes an operational update at February 23, 2021. The Earnings Press Release is incorporated by reference into this Item 2.02, and the foregoing description of the 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 and (v) adjusted free cash flow of both the Company and San Mateo. 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 23, 2021, announcing its 2021 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 23, 2021 | 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 2020 FINANCIAL RESULTS AND PROVIDES OPERATIONAL UPDATE
DALLAS, Texas, February 23, 2021 -- Matador Resources Company (NYSE: MTDR) (“Matador” or the “Company”) today reported financial and operating results for the fourth quarter and full year 2020. A slide presentation summarizing the highlights of Matador’s fourth quarter and full year 2020 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 2021 operating plan and 2021 market guidance.
Management Summary Comments
Joseph Wm. Foran, Matador’s Chairman and CEO, commented, “On both our website and the webcast planned for tomorrow’s earnings conference call is a set of five slides identified as ‘Chairman’s Remarks’ (Slides A through E) 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 from the fourth quarter and full year 2020. The year 2020 was a challenging and difficult year, but the Matador team came together to meet the challenges and, as a result, Matador finished 2020 as a bigger and better company. The Board and I would like to commend and thank the entire Matador team for their positive and professional response to the challenges we faced in 2020.
Fourth Quarter 2020 Highlights and Achievements
“The fourth quarter of 2020 was an excellent and significant quarter for Matador (see Slide A). Our primary goals in the fourth quarter were to (1) achieve free cash flow, (2) use a portion of that free cash flow to begin paying down debt, (3) grow production by at least 8 to 10% sequentially and (4) ramp-up operations from San Mateo’s newly expanded infrastructure and achieve increased volumes and revenues for San Mateo. As you will see throughout this release, Matador accomplished or exceeded all of these goals and achieved record quarterly highs for oil, natural gas and total oil equivalent production, as well as record quarterly lows for drilling and completion costs per lateral foot and per-unit lease operating and general and administrative expenses. In addition, as we announced on February 17, 2021, Matador’s proved oil and natural gas reserves increased 7% year-over-year to 270.3 million barrels of oil equivalent, an all-time high for Matador, despite the 31% decrease in oil price and the 23% decrease in natural gas price the Company was required to use in estimating proved reserves at December 31, 2020 as compared to the prior year (see Slide B).
“Matador was particularly pleased to achieve free cash flow for the first time in the fourth quarter of 2020. Net cash provided by operating activities in the fourth quarter was $157.6 million, leading to fourth quarter 2020 adjusted free cash flow of $60.7 million. Given this strong free cash flow, Matador repaid $35 million in borrowings outstanding under our reserves-based credit facility during the fourth quarter and then repaid an additional $10 million in January 2021 (see Slide C). Further, at year-end 2020, Matador’s leverage ratio under our reserves-based credit facility was 2.9x, well below the sole covenant under our credit facility to maintain this leverage ratio below 4.0x. Matador expects to generate adjusted free cash flow in aggregate for full year 2021 and plans to continue using a significant portion of this discretionary cash flow to continue reducing the borrowings outstanding under our credit facility.
“Matador’s total oil equivalent production grew 14% sequentially to 83,200 BOE per day in the fourth quarter of 2020, above our expectations for 8 to 10% production growth in the fourth quarter and an all-time quarterly high for Matador, as we enjoyed the first full quarter of production from our recently completed Boros wells in the Stateline asset area and Leatherneck wells in the Greater Stebbins Area. Our operations and asset teams also continued to achieve new milestones in their efforts to improve our capital efficiency and operating costs, achieving lower-than-
1
expected capital expenditures and operating expenses. Drilling and completion costs for all operated horizontal wells completed and turned to sales in the fourth quarter of 2020 averaged $625 per completed lateral foot, an all-time low for Matador (see Slide D). Lease operating expenses on a unit-of-production basis declined 8% sequentially to $3.20 per BOE, and general and administrative expenses on a unit-of production basis declined 4% sequentially to $2.16 per BOE—both were all time lows for Matador.
“San Mateo also achieved record quarterly results in the fourth quarter of 2020 (see Slide E). Natural gas gathering and processing, oil gathering and transportation and produced water handling volumes were all up significantly on a sequential basis in the fourth quarter of 2020, as San Mateo enjoyed the first full quarter of operations following the completion and successful startup of the expansion of the Black River Processing Plant and the related pipeline infrastructure and began gathering and processing natural gas and gathering, transporting and handling oil and produced water from Matador’s Stateline asset area and the Greater Stebbins Area. San Mateo also reported free cash flow in the fourth quarter of 2020, with net cash from operating activities of $26.1 million leading to adjusted free cash flow of $21.4 million. As a result, in January 2021, San Mateo repaid $11 million in borrowings outstanding under its credit facility. San Mateo expects to generate free cash flow throughout 2021 as well, given the current maintenance level of capital expenditures budgeted for 2021.
Dividend Initiation
“Given Matador’s strong finish to 2020 and our positive outlook for 2021 and beyond, Matador was very pleased to announce yesterday that the Board of Directors has adopted a dividend policy pursuant to which the Company intends to pay quarterly cash dividends on its common stock of $0.025 per share. Pursuant to this policy, the Board declared Matador’s first quarterly cash dividend of $0.025 per share of common stock payable on March 31, 2021 to shareholders of record as of March 24, 2021. The announcement of Matador’s first cash dividend marks another significant step for Matador in returning value to our shareholders and reflects our confidence in Matador’s financial strength and ability to generate sustained free cash flow going forward.
2021 Operating Plan and Market Guidance
“Finally, in conjunction with this earnings release, we have also released today our 2021 operating plan and market guidance. As you will see in that companion release, we believe that 2021 should be particularly exciting for Matador and its stakeholders, as we work to continue developing our excellent Delaware Basin assets, transition to free cash flow, continue to pay down debt and institute a dividend to augment our returns to shareholders. Our 2021 operating plan will focus on our federal properties, and in response to recent actions taken by the newly inaugurated Biden administration, we have elected to pick up a fourth operated drilling rig in March to ensure the orderly development of our federal leasehold in the Delaware Basin. We are off to a good start in 2021 and are certainly encouraged by the recent improvement in commodity prices. We are excited about the year ahead and believe our 2021 operating plan should generate substantial value growth for our stakeholders in the year ahead and for years to come.”
Fourth Quarter 2020 Operational and Financial Highlights
Adjusted Free Cash Flow Achieved in Fourth Quarter 2020
•Fourth quarter 2020 net cash provided by operating activities was $157.6 million (GAAP basis), leading to fourth quarter 2020 adjusted free cash flow (a non-GAAP financial measure) of $60.7 million. These cash flow measures were above Matador’s expectations for the fourth quarter and allowed the Company to repay $35 million in borrowings outstanding under its reserves-based revolving credit facility in the fourth quarter as noted below. Matador anticipates that it should generate positive adjusted free cash flow in aggregate for full year
2
2021, even in light of adding a fourth operated rig in March, given the current outlook for oil and natural gas prices in 2021.
Record Oil, Natural Gas and Oil Equivalent Production
•As summarized in the table below, Matador’s fourth quarter 2020 average daily oil, natural gas and total oil equivalent production were all record quarterly highs for the Company and above the Company’s expectations. The majority of the production increase resulted from better-than-expected performance from a number of wells completed and turned to sales during the first three quarters of 2020, including the first full quarter of production from the 13 Boros wells in the Stateline asset area that were turned to sales in September 2020. The Company also achieved better-than-expected results from several wells completed and turned to sales in the Rustler Breaks asset area during the fourth quarter.
| Production Change (%) | |||||||||||||||||
| Production | Q4 2020 Average Daily Volume | Sequential(1) | Guidance(2) | Difference(3) | YoY(4) | ||||||||||||
| Total, BOE per day | 83,200 | +14.0% | +8% to +10% | +5.0% | +12.8% | ||||||||||||
| Oil, Bbl per day | 48,000 | +13.4% | +8% to +10% | +4.4% | +14.1% | ||||||||||||
| Natural Gas, MMcf per day | 210.9 | +14.7% | +8% to +10% | +5.7% | +11.0% | ||||||||||||
(1) As compared to the third quarter of 2020.
(2) Production change previously projected, as provided on October 27, 2020.
(3) As compared to midpoint of guidance provided on October 27, 2020.
(4) Represents year-over-year percentage change from the fourth quarter of 2019.
Net Income, Earnings Per Share and Adjusted EBITDA
•Fourth quarter 2020 net loss (GAAP basis) was $89.5 million, or a net loss of $0.77 per diluted common share, a sequential increase from a net loss of $276.1 million in the third quarter of 2020, and a year-over-year decrease from net income of $24.0 million in the fourth quarter of 2019.
•Fourth quarter 2020 adjusted net income (a non-GAAP financial measure) was $32.3 million, or adjusted net income of $0.27 per diluted common share, a sequential increase from an adjusted net income of $11.6 million in the third quarter of 2020, and a year-over-year decrease from adjusted net income of $46.1 million in the fourth quarter of 2019.
•Fourth quarter 2020 adjusted earnings before interest expense, income taxes, depletion, depreciation and amortization and certain other items (“Adjusted EBITDA,” a non-GAAP financial measure) were $150.1 million, a sequential increase from $121.0 million in the third quarter of 2020, and a year-over-year decrease from $181.0 million in the fourth quarter of 2019.
Record-Low Lease Operating and General and Administrative Unit Costs
•Lease operating expenses (“LOE”) in the fourth quarter of 2020 were a Matador-record low of $3.20 per BOE, an 8% sequential decrease from $3.48 per BOE in the third quarter of 2020, and a 28% year-over-year decrease from $4.43 per BOE in the fourth quarter of 2019. This record low LOE per BOE in the fourth quarter resulted primarily from (1) the Company’s ongoing efforts to reduce costs and improve the efficiency of its operations, (2) the 14% increase in total oil and natural gas production during the fourth quarter of 2020, (3) additional
3
produced water being gathered by pipeline, including via San Mateo’s gathering systems, thereby reducing trucking costs, and (4) lower service costs.
•General and administrative (“G&A”) expenses in the fourth quarter of 2020 were a Matador-record low of $2.16 per BOE, a 4% sequential decrease from $2.25 per BOE in the third quarter of 2020, and a 32% year-over-year decrease from $3.17 per BOE in the fourth quarter of 2019. Matador’s G&A expenses continued to be positively impacted primarily by the G&A cost reductions initially implemented in the first quarter of 2020 and maintained throughout the remainder of the year. This record low G&A per BOE in the fourth quarter was also attributable to the 14% year-over-year increase in total oil and natural gas production during the fourth quarter.
Record-Low Drilling and Completion Costs of $625 per Completed Lateral Foot
•Drilling and completion costs for all operated horizontal wells completed and turned to sales in the fourth quarter of 2020 averaged $625 per completed lateral foot, a sequential decrease of 21% from average drilling and completion costs of $790 per completed lateral foot in the third quarter of 2020, and a decrease of 46% from average drilling and completion costs of $1,165 per completed lateral foot achieved in full year 2019. Drilling and completion costs of $625 per completed lateral foot were the lowest quarterly drilling and completion costs per completed lateral foot in Matador’s history.
•Matador incurred capital expenditures for drilling, completing and equipping wells (“D/C/E capital expenditures”) of approximately $63 million in the fourth quarter of 2020, or 21% below the Company’s estimate of $78 million for D/C/E capital expenditures during the quarter. For full year 2020, Matador’s D/C/E capital expenditures were approximately $450 million, or about 3% below the midpoint of Matador’s updated guidance of $465 million for full year 2020 D/C/E capital expenditures, as provided on October 27, 2020.
Total Borrowings and Leverage Ratio Below Expectations
•At December 31, 2020, total borrowings outstanding under Matador’s reserves-based credit facility were $440 million, a reduction of $35 million from total borrowings outstanding of $475 million at September 30, 2020. This reduction in borrowings outstanding of $35 million was $10 million more than the Company’s fourth quarter guidance for an anticipated repayment of $25 million under its reserves-based credit facility.
•At December 31, 2020, Matador’s leverage ratio, as defined in the Company’s reserves-based credit facility, was 2.9x, which was below the Company’s expectations for year-end 2020. The leverage ratio of 2.9x was also well below the sole covenant under the Company’s reserves-based credit facility to maintain this leverage ratio below 4.0x.
•In January 2021, Matador repaid an additional $10 million in borrowings outstanding under the reserves-based credit facility. Total borrowings outstanding under the reserves-based credit facility at February 23, 2021 were $430 million.
Dividend Initiation
•On February 22, 2021, Matador announced that its Board of Directors (the “Board”) adopted a dividend policy pursuant to which the Company intends to pay quarterly cash dividends on its common stock of $0.025 per share. Pursuant to this policy, the Board declared Matador’s first quarterly cash dividend of $0.025 per share of common stock payable on March 31, 2021 to shareholders of record as of March 24, 2021.
4
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 and adjusted free cash flow and reconciliations of such non-GAAP financial metrics to their comparable GAAP metrics, please see “Supplemental Non-GAAP Financial Measures” below.
5
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, | |||||||||||||||||||||
| 2020 | 2020 | 2019 | |||||||||||||||||||||
Net Production Volumes:(1) | |||||||||||||||||||||||
Oil (MBbl)(2) | 4,419 | 3,895 | 3,872 | ||||||||||||||||||||
Natural gas (Bcf)(3) | 19.4 | 16.9 | 17.5 | ||||||||||||||||||||
Total oil equivalent (MBOE)(4) | 7,653 | 6,715 | 6,785 | ||||||||||||||||||||
Average Daily Production Volumes:(1) | |||||||||||||||||||||||
Oil (Bbl/d)(5) | 48,028 | 42,340 | 42,087 | ||||||||||||||||||||
Natural gas (MMcf/d)(6) | 210.9 | 183.9 | 190.0 | ||||||||||||||||||||
Total oil equivalent (BOE/d)(7) | 83,183 | 72,989 | 73,749 | ||||||||||||||||||||
| Average Sales Prices: | |||||||||||||||||||||||
| Oil, without realized derivatives (per Bbl) | $ | 40.99 | $ | 38.67 | $ | 56.36 | |||||||||||||||||
| Oil, with realized derivatives (per Bbl) | $ | 38.59 | $ | 37.28 | $ | 56.78 | |||||||||||||||||
Natural gas, without realized derivatives (per Mcf)(8) | $ | 2.97 | $ | 2.27 | $ | 2.31 | |||||||||||||||||
| Natural gas, with realized derivatives (per Mcf) | $ | 2.97 | $ | 2.27 | $ | 2.31 | |||||||||||||||||
| Revenues (millions): | |||||||||||||||||||||||
| Oil and natural gas revenues | $ | 238.7 | $ | 189.1 | $ | 258.6 | |||||||||||||||||
| Third-party midstream services revenues | $ | 15.1 | $ | 19.4 | $ | 17.7 | |||||||||||||||||
| Realized gain (loss) on derivatives | $ | (10.6) | $ | (5.4) | $ | 1.7 | |||||||||||||||||
| Operating Expenses (per BOE): | |||||||||||||||||||||||
| Production taxes, transportation and processing | $ | 3.53 | $ | 3.85 | $ | 3.88 | |||||||||||||||||
| Lease operating | $ | 3.20 | $ | 3.48 | $ | 4.43 | |||||||||||||||||
| Plant and other midstream services operating | $ | 1.62 | $ | 1.40 | $ | 1.51 | |||||||||||||||||
| Depletion, depreciation and amortization | $ | 11.73 | $ | 13.11 | $ | 14.89 | |||||||||||||||||
General and administrative(9) | $ | 2.16 | $ | 2.25 | $ | 3.17 | |||||||||||||||||
Total(10) | $ | 22.24 | $ | 24.09 | $ | 27.88 | |||||||||||||||||
| Other (millions): | |||||||||||||||||||||||
Net sales of purchased natural gas(11) | $ | 1.2 | $ | 2.2 | $ | 0.7 | |||||||||||||||||
Net (loss) income (millions)(12) | $ | (89.5) | $ | (276.1) | $ | 24.0 | |||||||||||||||||
(Loss) earnings per common share (diluted)(12) | $ | (0.77) | $ | (2.38) | $ | 0.21 | |||||||||||||||||
Adjusted net income (millions)(12)(13) | $ | 32.3 | $ | 11.6 | $ | 46.1 | |||||||||||||||||
Adjusted earnings per common share (diluted)(12)(14) | $ | 0.27 | $ | 0.10 | $ | 0.39 | |||||||||||||||||
Adjusted EBITDA (millions)(12)(15) | $ | 150.1 | $ | 121.0 | $ | 181.0 | |||||||||||||||||
Net cash provided by operating activities (millions)(16) | $ | 157.6 | $ | 109.6 | $ | 198.9 | |||||||||||||||||
Adjusted free cash flow (millions)(12)(17) | $ | 60.7 | $ | (18.0) | $ | (3.0) | |||||||||||||||||
San Mateo net income (millions)(18) | $ | 26.2 | $ | 20.3 | $ | 19.6 | |||||||||||||||||
San Mateo adjusted EBITDA (millions)(15)(18) | $ | 35.4 | $ | 28.0 | $ | 26.5 | |||||||||||||||||
San Mateo net cash provided by operating activities (millions)(18) | $ | 26.1 | $ | 24.8 | $ | 23.8 | |||||||||||||||||
San Mateo adjusted free cash flow (millions)(16)(17)(18) | $ | 21.4 | $ | (28.6) | $ | (61.1) | |||||||||||||||||
| D/C/E capital expenditures (millions) | $ | 63.4 | $ | 94.5 | $ | 142.4 | |||||||||||||||||
Midstream capital expenditures (millions)(19) | $ | 7.4 | $ | 28.0 | $ | 25.4 | |||||||||||||||||
(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.
6
(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 $0.42, $0.50 and $0.70 per BOE of non-cash, stock-based compensation expense in the fourth quarter of 2020, the third quarter of 2020 and the fourth quarter of 2019, 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 refers to residue natural gas and natural gas liquids (“NGL”) that are purchased from customers and subsequently resold. Such amounts reflect revenues from sales of purchased natural gas of $3.9 million, $13.4 million and $34.7 million less expenses of $2.6 million, $11.1 million and $34.0 million in the fourth quarter of 2020, the third quarter of 2020 and the fourth quarter of 2019, 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 (loss) income (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 (loss) earnings 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 (loss) income (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, 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, net of the applicable portions of Five Point’s $50 million capital carry of Matador’s proportionate interest in San Mateo II, plus 100% of other immaterial midstream capital expenditures not associated with San Mateo.
Operations Update
Drilling and Completion Activity
Matador operated three drilling rigs in the Delaware Basin during the fourth quarter of 2020 and continues to do so at February 23, 2021. Two of these rigs are currently operating in Matador’s Stateline asset area and one rig is currently drilling two wells in the Wolf asset area in Loving County, Texas. As highlighted in the Company’s 2021 operating plan and market guidance also released today, Matador expects to add a fourth rig to its operated drilling program in March 2021 and currently plans to operate four rigs in the Delaware Basin throughout the remainder of 2021. Matador has elected to pick up a fourth operated drilling rig in March 2021 to ensure the orderly development of the Company’s federal leasehold in the Delaware Basin going forward in response to recent actions taken by the newly inaugurated Biden administration. Additional details regarding Matador’s 2021 operating plans are provided in the Company’s 2021 Operating Plan and Market Guidance press release issued separately today.
Wells Completed and Turned to Sales
During the fourth quarter of 2020, Matador completed and turned to sales a total of 14 gross (4.3 net) wells in its various operating areas as shown in the table below. This total was comprised of five gross (2.6 net) operated wells and nine gross (1.7 net) non-operated wells. All five operated wells were two-mile laterals.
7
| Operated | Non-Operated | Total | Gross Operated | ||||||||||||||||||||||||||
| Asset/Operating Area | Gross | Net | Gross | Net | Gross | Net | Well Completion Intervals | ||||||||||||||||||||||
| Antelope Ridge | - | - | - | - | - | - | No wells turned to sales in Q4 2020 | ||||||||||||||||||||||
| Arrowhead | - | - | - | - | - | - | No wells turned to sales in Q4 2020 | ||||||||||||||||||||||
| Ranger | - | - | - | - | - | - | No wells turned to sales in Q4 2020 | ||||||||||||||||||||||
| Rustler Breaks | 5 | 2.6 | 8 | 1.7 | 13 | 4.3 | 1-1BS, 1-2BS, 1-3BS, 2-WC A | ||||||||||||||||||||||
| Stateline | - | - | - | - | - | - | No wells turned to sales in Q4 2020 | ||||||||||||||||||||||
| Twin Lakes | - | - | - | - | - | - | No wells turned to sales in Q4 2020 | ||||||||||||||||||||||
| Wolf/Jackson Trust | - | - | - | - | - | - | No wells turned to sales in Q4 2020 | ||||||||||||||||||||||
| Delaware Basin | 5 | 2.6 | 8 | 1.7 | 13 | 4.3 | |||||||||||||||||||||||
| South Texas | - | - | - | - | - | - | No wells turned to sales in Q4 2020 | ||||||||||||||||||||||
| Haynesville Shale | - | - | 1 | 0.0 | 1 | 0.0 | No operated wells turned to sales in Q4 2020 | ||||||||||||||||||||||
| Total | 5 | 2.6 | 9 | 1.7 | 14 | 4.3 | |||||||||||||||||||||||
Note: WC = Wolfcamp; BS = Bone Spring. For example, 1-3BS indicates one Third Bone Spring completion and 2-WC A indicates two 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.
Significant Well Results
The following table highlights the 24-hour initial potential (“IP”) test results from the five wells completed and turned to sales in the Rustler Breaks asset area in Eddy County, New Mexico during the fourth quarter of 2020, all of which are two-mile laterals. All five wells were completed and turned to sales at varying times during October and November 2020 and were the only operated wells the Company completed and turned to sales during the fourth quarter of 2020.
| Completion | 24-hr IP | BOE/d / | Oil | ||||||||||||||
| Asset Area/Well Name | Interval | (BOE/d) | 1,000 ft.(1) | (%) | Comments | ||||||||||||
| Rustler Breaks, Eddy County, NM | |||||||||||||||||
| Ray State #113H | First Bone Spring | 2,038 | 206 | 74% | Tested 1,511 Bbl of oil per day and 3.2 MMcf of natural gas per day. | ||||||||||||
Ray State #123H | Second Bone Spring | 2,314 | 229 | 78% | Tested 1,814 Bbl of oil per day and 3.0 MMcf of natural gas per day. | ||||||||||||
Ace Stern Vegas #137H | Third Bone Spring | 3,032 | 302 | 75% | Tested 2,286 Bbl of oil per day and 4.5 MMcf of natural gas per day. | ||||||||||||
Ace Stern Vegas #203H | Wolfcamp A-XY | 2,219 | 225 | 73% | Tested 1,628 Bbl of oil per day and 3.5 MMcf of natural gas per day. | ||||||||||||
Ace Stern Vegas #204H | Wolfcamp A-XY | 2,163 | 220 | 72% | Tested 1,555 Bbl of oil per day and 3.7 MMcf of natural gas per day. | ||||||||||||
(1) 24-hr IP per 1,000 feet of completed lateral length.
As previously noted in this earnings release, drilling and completion costs for these five operated wells completed and turned to sales in the Rustler Breaks asset area in the fourth quarter of 2020 averaged approximately $625 per completed lateral foot. These costs were the lowest quarterly drilling and completion costs per lateral foot that Matador has achieved to date in the Delaware Basin.
8
Matador was very encouraged by the results from the Ray State #113H well, which was another successful test of the First Bone Spring formation moving north in the Rustler Breaks asset area. This well’s test result and strong initial production performance demonstrate yet again the potential for the First Bone Spring formation throughout the Rustler Breaks asset area.
Matador was also very pleased with the 24-hour IP test results from the Ace Stern Vegas wells, including the high oil cuts from each of these three wells. The Ace Stern Vegas #137H well was Matador’s first test of the Third Bone Spring formation this far north in the Rustler Breaks asset area, and the Company was very encouraged by the strong test results from this well, which bodes well for the further prospectivity of the Third Bone Spring formation in the northern portion of the Rustler Breaks asset area.
Realized Commodity Prices
Oil Prices
Matador’s weighted average realized oil price, excluding derivatives, increased 6% sequentially from $38.67 per barrel in the third quarter of 2020 to $40.99 per barrel in the fourth quarter of 2020. Matador’s weighted average oil price differential relative to the NYMEX West Texas Intermediate (WTI) benchmark, inclusive of the monthly roll and transportation costs, improved from ($2.25) per barrel in the third quarter of 2020 to ($1.71) per barrel in the fourth quarter of 2020.
For the first quarter of 2021, 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 ($1.00) to ($2.00) per barrel.
Matador’s realized loss on derivatives (commodity price hedges) of approximately $10.6 million in the fourth quarter of 2020 was primarily attributable to certain losses associated with its oil swaps with a strike price of $35.00 per barrel. The Company put these oil swaps in place when restructuring its oil hedges early in the second quarter of 2020 to protect the balance sheet and ensure it would remain in compliance with its sole reserves-based credit facility leverage covenant in 2020, which requires the Company to maintain a leverage ratio, as defined in the credit agreement, below 4.0x. Overall, this restructuring of the Company’s oil hedges proved effective, as Matador realized a net gain on derivatives of $38.9 million for the year ended December 31, 2020 and ended the year with a leverage ratio of 2.9x. Please see the accompanying slide presentation for a more complete summary of Matador’s current oil and natural gas derivative positions.
Natural Gas Prices
Matador’s weighted average realized natural gas price, excluding derivatives, increased 31% sequentially from $2.27 per thousand cubic feet in the third quarter of 2020 to $2.97 per thousand cubic feet in the fourth quarter of 2020. Matador realized a weighted average natural gas price differential of +$0.21 per thousand cubic feet above the average NYMEX Henry Hub natural gas price in the fourth quarter, as compared to a differential of +$0.15 per thousand cubic feet above the average NYMEX Henry Hub natural gas price in the third 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 2021, Matador’s weighted average natural gas price differential relative to the Henry Hub benchmark price is anticipated to be in the range of +$0.50 to +$1.00 per thousand cubic feet, primarily attributable to improved natural gas price differentials at the Waha hub in West Texas, as well as to recent improvements in prices for NGLs.
Matador realized no gains or losses on any of its natural gas hedges in place during the fourth quarter of 2020.
9
San Mateo Highlights and Update
Operating Highlights and Financial Results
During the fourth quarter of 2020, San Mateo, Matador’s midstream affiliate, enjoyed the first full quarter of operations following the completion and successful start-up of the expansion of its cryogenic natural gas processing plant in Eddy County, New Mexico (the “Black River Processing Plant”) in the third quarter. The expansion of the Black River Processing Plant added an incremental designed inlet capacity of 200 million cubic feet of natural gas per day to the previously designed inlet capacity of 260 million cubic feet per day for a total designed inlet capacity of 460 million cubic feet per day. The expanded Black River Processing Plant supports Matador’s exploration and development activities in the Delaware Basin and is currently gathering and processing natural gas from Matador’s Stateline asset area and from the Stebbins and surrounding leaseholds in the Arrowhead asset area (the “Greater Stebbins Area”). The Black River Processing Plant also processes natural gas from Matador’s Rustler Breaks asset area and provides natural gas processing services for other San Mateo customers in the area.
The fourth quarter of 2020 was also the first full quarter of operations for approximately 43 miles of large diameter natural gas gathering pipelines that San Mateo placed in service during the third quarter of 2020 between the Black River Processing Plant and Matador’s Stateline asset area (approximately 24 miles) and the Greater Stebbins Area (approximately 19 miles). In addition, San Mateo also enjoyed the first quarter of operations for approximately 19 miles of various diameter crude oil pipelines from certain points of origin in the Greater Stebbins Area to the existing San Mateo interconnect with a subsidiary of Plains All American Pipeline, L.P. in Eddy County, New Mexico. San Mateo is currently gathering or transporting Matador’s oil and natural gas production via pipeline in both the Stateline asset area and the Greater Stebbins Area, as well as in the Wolf and Rustler Breaks asset areas. San Mateo is handling Matador’s produced water in each of these areas as well.
San Mateo’s operations in the fourth quarter of 2020 were highlighted by sequential increases in natural gas gathering and processing, water handling and oil gathering and transportation volumes. As expected, natural gas gathering and processing volumes, water handling volumes and oil gathering and transportation volumes all increased significantly in the fourth quarter of 2020 as San Mateo gathered, transported, processed and handled the first full quarter of oil and natural gas production and produced water from Matador’s recently completed Boros wells in the Stateline asset area and the Leatherneck wells in the Greater Stebbins Area.
Operating Highlights
During the fourth quarter of 2020, San Mateo:
•Gathered and transported an average of 42,500 barrels of oil per day, a 39% sequential increase, as compared to 30,600 barrels per day in the third quarter of 2020, and a 59% year-over-year increase, as compared to 26,700 barrels per day in the fourth quarter of 2019.
•Handled an average of 260,000 barrels of produced water per day, a 12% sequential increase, as compared to 233,000 barrels per day in the third quarter of 2020, and a 22% year-over-year increase, as compared to 213,000 barrels per day in the fourth quarter of 2019.
•Gathered an average of 216 million cubic feet of natural gas per day, a 12% sequential increase, as compared to 193 million cubic feet per day in the third quarter of 2020, and an 18% year-over-year decrease, as compared to 262 million cubic feet per day in the fourth quarter of 2019.
•Processed an average of 175 million cubic feet of natural gas per day at the Black River Processing Plant, a 17% sequential increase, as compared to 150 million cubic feet per day in the third quarter of 2020, and a 24% year-over-year decrease, as compared to 232 million cubic feet per day in the fourth quarter of 2019.
10
Financial Results
During the fourth quarter of 2020, San Mateo achieved record financial results, including:
•Net income (GAAP basis) of $26.2 million, a 29% sequential increase from $20.3 million in the third quarter of 2020, and a 34% year-over-year increase from $19.6 million in the fourth quarter of 2019. 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 production volumes from Matador’s Boros and Leatherneck wells.
•Adjusted EBITDA (a non-GAAP financial measure) of $35.4 million, a 27% sequential increase from $28.0 million in the third quarter of 2020, and a 34% year-over-year increase from $26.5 million in the fourth quarter of 2019. 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 $26.1 million, leading to San Mateo adjusted free cash flow (a non-GAAP financial measure) of $21.4 million. San Mateo achieved these cash flow measures in the fourth quarter as a result of the completion of the significant expansion projects in Eddy County, New Mexico during the third quarter of 2020. San Mateo expects to generate adjusted free cash flow going forward, assuming a maintenance level of capital expenditures in future periods.
•In January 2021, San Mateo repaid $11 million in borrowings outstanding under its credit facility. Total borrowings outstanding under the San Mateo credit facility at February 23, 2021 were $323 million. The San Mateo credit facility is non-recourse with respect to Matador.
Capital Expenditures
Matador’s portion of San Mateo’s capital expenditures was approximately $7 million in the fourth quarter of 2020, about $6 million less than the Company’s estimate of $13 million for the fourth quarter, primarily attributable to both cost savings on completed projects and the timing of operations. For full year 2020, Matador’s portion of San Mateo’s capital expenditures was approximately $88 million, or about 7% below the midpoint of Matador’s guidance of $95 million for its portion of San Mateo’s full year 2020 capital expenditures. San Mateo’s full year 2020 capital expenditures totaled approximately $200 million.
Conference Call Information
The Company will host a live conference call on Wednesday, February 24, 2021, at 9:00 a.m. Central Time to discuss its fourth quarter and full year 2020 financial and operational results, as well as its 2021 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 6492069. 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, 2021.
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
11
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 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; 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 our business; the operating results of the Company’s midstream joint venture’s Black River natural gas cryogenic 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 which 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.
12
Contact Information
Mac Schmitz
Capital Markets Coordinator
(972) 371-5225
investors@matadorresources.com
13
Matador Resources Company and Subsidiaries
CONSOLIDATED BALANCE SHEETS - UNAUDITED
| (In thousands, except par value and share data) | December 31, | ||||||||||||||||
| 2020 | 2019 | ||||||||||||||||
| ASSETS | |||||||||||||||||
| Current assets | |||||||||||||||||
| Cash | $ | 57,916 | $ | 40,024 | |||||||||||||
| Restricted cash | 33,467 | 25,104 | |||||||||||||||
| Accounts receivable | |||||||||||||||||
| Oil and natural gas revenues | 85,098 | 95,228 | |||||||||||||||
| Joint interest billings | 34,823 | 67,546 | |||||||||||||||
| Other | 17,212 | 26,639 | |||||||||||||||
| Derivative instruments | 6,727 | — | |||||||||||||||
| Lease and well equipment inventory | 10,584 | 10,744 | |||||||||||||||
| Prepaid expenses and other current assets | 15,802 | 13,207 | |||||||||||||||
| Total current assets | 261,629 | 278,492 | |||||||||||||||
| Property and equipment, at cost | |||||||||||||||||
| Oil and natural gas properties, full-cost method | |||||||||||||||||
| Evaluated | 5,295,931 | 4,557,265 | |||||||||||||||
| Unproved and unevaluated | 902,133 | 1,126,992 | |||||||||||||||
| Midstream properties | 841,695 | 643,903 | |||||||||||||||
| Other property and equipment | 29,561 | 27,021 | |||||||||||||||
| Less accumulated depletion, depreciation and amortization | (3,701,551) | (2,655,586) | |||||||||||||||
| Net property and equipment | 3,367,769 | 3,699,595 | |||||||||||||||
| Other assets | |||||||||||||||||
| Derivative instruments | 2,570 | — | |||||||||||||||
| Other long-term assets | 55,312 | 91,589 | |||||||||||||||
| Total assets | $ | 3,687,280 | $ | 4,069,676 | |||||||||||||
| LIABILITIES AND SHAREHOLDERS’ EQUITY | |||||||||||||||||
| Current liabilities | |||||||||||||||||
| Accounts payable | $ | 13,982 | $ | 25,230 | |||||||||||||
| Accrued liabilities | 119,158 | 200,695 | |||||||||||||||
| Royalties payable | 66,049 | 85,193 | |||||||||||||||
| Amounts due to affiliates | 4,934 | 19,606 | |||||||||||||||
| Derivative instruments | 45,186 | 1,897 | |||||||||||||||
| Advances from joint interest owners | 4,191 | 14,837 | |||||||||||||||
| Amounts due to joint ventures | — | 486 | |||||||||||||||
| Other current liabilities | 37,436 | 51,828 | |||||||||||||||
| Total current liabilities | 290,936 | 399,772 | |||||||||||||||
| Long-term liabilities | |||||||||||||||||
| Borrowings under Credit Agreement | 440,000 | 255,000 | |||||||||||||||
| Borrowings under San Mateo Credit Facility | 334,000 | 288,000 | |||||||||||||||
| Senior unsecured notes payable | 1,040,998 | 1,039,416 | |||||||||||||||
| Asset retirement obligations | 37,919 | 35,592 | |||||||||||||||
| Derivative instruments | — | 1,984 | |||||||||||||||
| Deferred income taxes | — | 37,329 | |||||||||||||||
| Other long-term liabilities | 30,402 | 43,131 | |||||||||||||||
| Total long-term liabilities | 1,883,319 | 1,700,452 | |||||||||||||||
| Shareholders’ equity | |||||||||||||||||
| Common stock — $0.01 par value, 160,000,000 shares authorized; 116,847,003 and 116,644,246 shares issued; and 116,844,768 and 116,642,899 shares outstanding, respectively | 1,169 | 1,166 | |||||||||||||||
| Additional paid-in capital | 2,027,069 | 1,981,014 | |||||||||||||||
| Accumulated deficit | (741,705) | (148,500) | |||||||||||||||
| Treasury stock, at cost, 2,235 and 1,347 shares, respectively | (3) | (26) | |||||||||||||||
| Total Matador Resources Company shareholders’ equity | 1,286,530 | 1,833,654 | |||||||||||||||
| Non-controlling interest in subsidiaries | 226,495 | 135,798 | |||||||||||||||
| Total shareholders’ equity | 1,513,025 | 1,969,452 | |||||||||||||||
| Total liabilities and shareholders’ equity | $ | 3,687,280 | $ | 4,069,676 | |||||||||||||
14
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, | ||||||||||||||||||||||||
| 2020 | 2019 | 2020 | 2019 | |||||||||||||||||||||||
| Revenues | ||||||||||||||||||||||||||
| Oil and natural gas revenues | $ | 238,676 | $ | 258,619 | $ | 744,461 | $ | 892,325 | ||||||||||||||||||
| Third-party midstream services revenues | 15,071 | 17,656 | 64,932 | 59,110 | ||||||||||||||||||||||
| Sales of purchased natural gas | 3,859 | 34,711 | 41,742 | 74,769 | ||||||||||||||||||||||
| Lease bonus - mineral acreage | — | — | 4,062 | 1,711 | ||||||||||||||||||||||
| Realized (loss) gain on derivatives | (10,634) | 1,701 | 38,937 | 9,482 | ||||||||||||||||||||||
| Unrealized loss on derivatives | (22,737) | (24,012) | (32,008) | (53,727) | ||||||||||||||||||||||
| Total revenues | 224,235 | 288,675 | 862,126 | 983,670 | ||||||||||||||||||||||
| Expenses | ||||||||||||||||||||||||||
| Production taxes, transportation and processing | 26,985 | 26,304 | 93,338 | 92,273 | ||||||||||||||||||||||
| Lease operating | 24,489 | 30,077 | 104,953 | 117,305 | ||||||||||||||||||||||
| Plant and other midstream services operating | 12,371 | 10,244 | 41,500 | 36,798 | ||||||||||||||||||||||
| Purchased natural gas | 2,610 | 33,984 | 32,734 | 69,398 | ||||||||||||||||||||||
| Depletion, depreciation and amortization | 89,749 | 101,043 | 361,831 | 350,540 | ||||||||||||||||||||||
| Accretion of asset retirement obligations | 499 | 468 | 1,948 | 1,822 | ||||||||||||||||||||||
| Full-cost ceiling impairment | 109,579 | — | 684,743 | — | ||||||||||||||||||||||
| General and administrative | 16,533 | 21,507 | 62,578 | 80,054 | ||||||||||||||||||||||
| Total expenses | 282,815 | 223,627 | 1,383,625 | 748,190 | ||||||||||||||||||||||
| Operating (loss) income | (58,580) | 65,048 | (521,499) | 235,480 | ||||||||||||||||||||||
| Other income (expense) | ||||||||||||||||||||||||||
| Net loss on asset sales and inventory impairment | (200) | (160) | (2,832) | (967) | ||||||||||||||||||||||
| Interest expense | (20,352) | (19,701) | (76,692) | (73,873) | ||||||||||||||||||||||
| Other income (expense) | 309 | (1,348) | 1,864 | (2,126) | ||||||||||||||||||||||
| Total other expense | (20,243) | (21,209) | (77,660) | (76,966) | ||||||||||||||||||||||
| (Loss) income before income taxes | (78,823) | 43,839 | (599,159) | 158,514 | ||||||||||||||||||||||
| Income tax provision (benefit) | ||||||||||||||||||||||||||
| Deferred | (2,230) | 10,197 | (45,599) | 35,532 | ||||||||||||||||||||||
| Total income tax (benefit) provision | (2,230) | 10,197 | (45,599) | 35,532 | ||||||||||||||||||||||
| Net (loss) income | (76,593) | 33,642 | (553,560) | 122,982 | ||||||||||||||||||||||
| Net income attributable to non-controlling interest in subsidiaries | (12,861) | (9,623) | (39,645) | (35,205) | ||||||||||||||||||||||
| Net (loss) income attributable to Matador Resources Company shareholders | $ | (89,454) | $ | 24,019 | $ | (593,205) | $ | 87,777 | ||||||||||||||||||
| (Loss) earnings per common share | ||||||||||||||||||||||||||
| Basic | $ | (0.77) | $ | 0.21 | $ | (5.11) | $ | 0.75 | ||||||||||||||||||
| Diluted | $ | (0.77) | $ | 0.21 | $ | (5.11) | $ | 0.75 | ||||||||||||||||||
| Weighted average common shares outstanding | ||||||||||||||||||||||||||
| Basic | 116,163 | 116,641 | 116,068 | 116,555 | ||||||||||||||||||||||
| Diluted | 116,163 | 116,983 | 116,068 | 117,063 | ||||||||||||||||||||||
15
Matador Resources Company and Subsidiaries
CONSOLIDATED STATEMENTS OF CASH FLOWS - UNAUDITED
| (In thousands) | Three Months Ended December 31, | Year Ended December 31, | ||||||||||||||||||||||||||||||
| 2020 | 2019 | 2020 | 2019 | |||||||||||||||||||||||||||||
| Operating activities | ||||||||||||||||||||||||||||||||
| Net (loss) income | (76,593) | 33,642 | $ | (553,560) | $ | 122,982 | ||||||||||||||||||||||||||
| Adjustments to reconcile net (loss) income to net cash provided by operating activities | ||||||||||||||||||||||||||||||||
| Unrealized loss on derivatives | 22,737 | 24,012 | 32,008 | 53,727 | ||||||||||||||||||||||||||||
| Depletion, depreciation and amortization | 89,749 | 101,043 | 361,831 | 350,540 | ||||||||||||||||||||||||||||
| Accretion of asset retirement obligations | 499 | 468 | 1,948 | 1,822 | ||||||||||||||||||||||||||||
| Full-cost ceiling impairment | 109,579 | — | 684,743 | — | ||||||||||||||||||||||||||||
| Stock-based compensation expense | 3,176 | 4,765 | 13,625 | 18,505 | ||||||||||||||||||||||||||||
| Deferred income tax (benefit) provision | (2,230) | 10,197 | (45,599) | 35,532 | ||||||||||||||||||||||||||||
| Amortization of debt issuance cost | 718 | 670 | 2,832 | 2,484 | ||||||||||||||||||||||||||||
| Net loss on asset sales and inventory impairment | 200 | 160 | 2,832 | 967 | ||||||||||||||||||||||||||||
| Changes in operating assets and liabilities | ||||||||||||||||||||||||||||||||
| Accounts receivable | 941 | (5,920) | 53,001 | (43,261) | ||||||||||||||||||||||||||||
| Lease and well equipment inventory | (23) | 2,470 | (655) | 4,777 | ||||||||||||||||||||||||||||
| Prepaid expenses and other current assets | (2,599) | 255 | (3,010) | (4,844) | ||||||||||||||||||||||||||||
| Other long-term assets | (103) | 969 | 1,681 | 678 | ||||||||||||||||||||||||||||
| Accounts payable, accrued liabilities and other current liabilities | 17,608 | (3,464) | (43,844) | (19,004) | ||||||||||||||||||||||||||||
| Royalties payable | (2,274) | 21,003 | (19,144) | 20,417 | ||||||||||||||||||||||||||||
| Advances from joint interest owners | (3,521) | 7,028 | (10,646) | 3,869 | ||||||||||||||||||||||||||||
| Other long-term liabilities | (241) | 1,617 | (461) | 2,851 | ||||||||||||||||||||||||||||
| Net cash provided by operating activities | 157,623 | 198,915 | 477,582 | 552,042 | ||||||||||||||||||||||||||||
| Investing activities | ||||||||||||||||||||||||||||||||
| Drilling, completion and equipping capital expenditures | (70,531) | (185,238) | (471,087) | (679,395) | ||||||||||||||||||||||||||||
| Acquisition of oil and natural gas properties | (7,374) | (8,906) | (72,809) | (50,766) | ||||||||||||||||||||||||||||
| Midstream capital expenditures | (36,417) | (71,243) | (234,359) | (192,035) | ||||||||||||||||||||||||||||
| Expenditures for other property and equipment | (404) | 210 | (2,200) | (3,701) | ||||||||||||||||||||||||||||
| Proceeds from sale of assets | 215 | 250 | 4,789 | 21,921 | ||||||||||||||||||||||||||||
| Net cash used in investing activities | (114,511) | (264,927) | (775,666) | (903,976) | ||||||||||||||||||||||||||||
| Financing activities | ||||||||||||||||||||||||||||||||
| Repayments of borrowings | (35,000) | (25,000) | (35,000) | (35,000) | ||||||||||||||||||||||||||||
| Borrowings under Credit Agreement | — | 65,000 | 220,000 | 250,000 | ||||||||||||||||||||||||||||
| Borrowings under San Mateo Credit Facility | 7,600 | 28,000 | 46,000 | 68,000 | ||||||||||||||||||||||||||||
| Cost to enter into or amend credit facilities | — | (830) | (660) | (1,443) | ||||||||||||||||||||||||||||
| Proceeds from stock options exercised | — | — | 45 | 3,300 | ||||||||||||||||||||||||||||
| Contributions related to formation of San Mateo I | — | — | 14,700 | 14,700 | ||||||||||||||||||||||||||||
| Contributions from non-controlling interest owners of less-than-wholly-owned subsidiaries | 20,678 | 35,000 | 119,700 | 77,330 | ||||||||||||||||||||||||||||
| Distributions to non-controlling interest owners of less-than-wholly-owned subsidiaries | (12,740) | (11,515) | (45,570) | (39,200) | ||||||||||||||||||||||||||||
| Taxes paid related to net share settlement of stock-based compensation | — | (26) | (1,556) | (3,691) | ||||||||||||||||||||||||||||
| Other | (170) | (295) | 6,680 | (918) | ||||||||||||||||||||||||||||
| Net cash (used in) provided by financing activities | (19,632) | 90,334 | 324,339 | 333,078 | ||||||||||||||||||||||||||||
| Increase (decrease) in cash and restricted cash | 23,480 | 24,322 | 26,255 | (18,856) | ||||||||||||||||||||||||||||
| Cash and restricted cash at beginning of period | 67,903 | 40,806 | 65,128 | 83,984 | ||||||||||||||||||||||||||||
| Cash and restricted cash at end of period | $ | 91,383 | $ | 65,128 | $ | 91,383 | $ | 65,128 | ||||||||||||||||||||||||
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, prepayment premium on extinguishment of debt and net gain or loss on asset sales and inventory impairment. Adjusted EBITDA for San Mateo includes the combined financial results of San Mateo Midstream, LLC and San Mateo Midstream II, LLC prior to the October 2020 merger. 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 inventory impairments. 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 | ||||||||||||||||||||
| (In thousands) | December 31, 2020 | September 30, 2020 | December 31, 2019 | |||||||||||||||||
| Unaudited Adjusted EBITDA Reconciliation to Net (Loss) Income: | ||||||||||||||||||||
| Net (loss) income attributable to Matador Resources Company Shareholders | $ | (89,454) | $ | (276,064) | $ | 24,019 | ||||||||||||||
| Net income attributable to non-controlling interest in subsidiaries | 12,861 | 9,957 | 9,623 | |||||||||||||||||
| Net (loss) income | (76,593) | (266,107) | 33,642 | |||||||||||||||||
| Interest expense | 20,352 | 18,231 | 19,701 | |||||||||||||||||
| Total income tax (benefit) provision | (2,230) | 26,497 | 10,197 | |||||||||||||||||
| Depletion, depreciation and amortization | 89,749 | 88,025 | 101,043 | |||||||||||||||||
| Accretion of asset retirement obligations | 499 | 478 | 468 | |||||||||||||||||
| Full-cost ceiling impairment | 109,579 | 251,163 | — | |||||||||||||||||
| Unrealized loss on derivatives | 22,737 | 13,033 | 24,012 | |||||||||||||||||
| Non-cash stock-based compensation expense | 3,176 | 3,369 | 4,765 | |||||||||||||||||
| Net loss on asset sales and inventory impairment | 200 | — | 160 | |||||||||||||||||
| Consolidated Adjusted EBITDA | 167,469 | 134,689 | 193,988 | |||||||||||||||||
| Adjusted EBITDA attributable to non-controlling interest in subsidiaries | (17,350) | (13,701) | (12,964) | |||||||||||||||||
| Adjusted EBITDA attributable to Matador Resources Company shareholders | $ | 150,119 | $ | 120,988 | $ | 181,024 | ||||||||||||||
| Three Months Ended | ||||||||||||||||||||
| (In thousands) | December 31, 2020 | September 30, 2020 | December 31, 2019 | |||||||||||||||||
| Unaudited Adjusted EBITDA Reconciliation to Net Cash Provided by Operating Activities: | ||||||||||||||||||||
| Net cash provided by operating activities | $ | 157,623 | $ | 109,574 | $ | 198,915 | ||||||||||||||
| Net change in operating assets and liabilities | (9,788) | 7,599 | (23,958) | |||||||||||||||||
| Interest expense, net of non-cash portion | 19,634 | 17,516 | 19,031 | |||||||||||||||||
| Adjusted EBITDA attributable to non-controlling interest in subsidiaries | (17,350) | (13,701) | (12,964) | |||||||||||||||||
| Adjusted EBITDA attributable to Matador Resources Company shareholders | $ | 150,119 | $ | 120,988 | $ | 181,024 | ||||||||||||||
Adjusted EBITDA – San Mateo (100%)
| Three Months Ended | |||||||||||||||||
| (In thousands) | December 31, 2020 | September 30, 2020 | December 31, 2019 | ||||||||||||||
| Unaudited Adjusted EBITDA Reconciliation to Net Income: | |||||||||||||||||
| Net income | $ | 26,247 | $ | 20,323 | $ | 19,642 | |||||||||||
| Depletion, depreciation and amortization | 7,277 | 5,822 | 4,249 | ||||||||||||||
| Interest expense | 1,827 | 1,766 | 2,502 | ||||||||||||||
| Accretion of asset retirement obligations | 56 | 50 | 58 | ||||||||||||||
| Adjusted EBITDA | $ | 35,407 | $ | 27,961 | $ | 26,451 | |||||||||||
| Three Months Ended | |||||||||||||||||
| (In thousands) | December 31, 2020 | September 30, 2020 | December 31, 2019 | ||||||||||||||
| Unaudited Adjusted EBITDA Reconciliation to Net Cash Provided by Operating Activities: | |||||||||||||||||
| Net cash provided by operating activities | $ | 26,131 | $ | 24,795 | $ | 23,834 | |||||||||||
| Net change in operating assets and liabilities | 7,716 | 1,477 | 199 | ||||||||||||||
| Interest expense, net of non-cash portion | 1,560 | 1,689 | 2,418 | ||||||||||||||
| Adjusted EBITDA | $ | 35,407 | $ | 27,961 | $ | 26,451 | |||||||||||
18
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 gains or losses or transaction costs for certain acquisitions and divestitures or other non-recurring expense items, along with the related tax effects 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 securities 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.
| Three Months Ended | ||||||||||||||||||||
| December 31, 2020 | September 30, 2020 | December 31, 2019 | ||||||||||||||||||
| (In thousands, except per share data) | ||||||||||||||||||||
| Unaudited Adjusted Net Income and Adjusted Earnings Per Common Share Reconciliation to Net (Loss) Income: | ||||||||||||||||||||
| Net (loss) income attributable to Matador Resources Company shareholders | $ | (89,454) | $ | (276,064) | $ | 24,019 | ||||||||||||||
| Total income tax (benefit) provision | (2,230) | 26,497 | 10,197 | |||||||||||||||||
(Loss) income attributable to Matador Resources shareholders before taxes (1) | (91,684) | (249,567) | 34,216 | |||||||||||||||||
| Less non-recurring and unrealized charges to (loss) income before taxes: | ||||||||||||||||||||
| Full-cost ceiling impairment | 109,579 | 251,163 | — | |||||||||||||||||
| Unrealized loss on derivatives | 22,737 | 13,033 | 24,012 | |||||||||||||||||
| Net loss on asset sales and inventory impairment | 200 | — | 160 | |||||||||||||||||
| Adjusted income attributable to Matador Resources shareholders before taxes | 40,832 | 14,629 | 58,388 | |||||||||||||||||
Income tax expense(1) | 8,575 | 3,072 | 12,261 | |||||||||||||||||
| Adjusted net income attributable to Matador Resources Company shareholders (non-GAAP) | $ | 32,257 | $ | 11,557 | $ | 46,127 | ||||||||||||||
| Basic weighted average shares outstanding, without participating securities | 116,163 | 116,155 | 115,746 | |||||||||||||||||
| Dilutive effect of participating securities | 677 | 685 | 895 | |||||||||||||||||
| Weighted average shares outstanding, including participating securities - basic | 116,840 | 116,840 | 116,641 | |||||||||||||||||
| Dilutive effect of options and restricted stock units | 704 | 569 | 342 | |||||||||||||||||
| Weighted average common shares outstanding - diluted | 117,544 | 117,409 | 116,983 | |||||||||||||||||
| Adjusted earnings per share attributable to Matador Resources shareholders (non-GAAP) | ||||||||||||||||||||
| Basic | $ | 0.28 | $ | 0.10 | $ | 0.40 | ||||||||||||||
| Diluted | $ | 0.27 | $ | 0.10 | $ | 0.39 | ||||||||||||||
(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
19
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. Adjusted free cash flow for San Mateo includes the combined financial results of San Mateo Midstream, LLC and San Mateo Midstream II, LLC prior to their October 2020 merger.
| Three Months Ended | ||||||||||||||||||||
| (In thousands) | December 31, 2020 | September 30, 2020 | December 31, 2019 | |||||||||||||||||
| Net cash provided by operating activities | $ | 157,623 | $ | 109,574 | $ | 198,915 | ||||||||||||||
| Net change in operating assets and liabilities | (9,788) | 7,599 | (23,958) | |||||||||||||||||
San Mateo discretionary cash flow attributable to non-controlling interest in subsidiaries(1) | (16,585) | (12,873) | (11,776) | |||||||||||||||||
| Performance incentives received from Five Point | — | — | — | |||||||||||||||||
| Total discretionary cash flow | 131,250 | 104,300 | 163,181 | |||||||||||||||||
| Drilling, completion and equipping capital expenditures | 70,531 | 117,194 | 185,238 | |||||||||||||||||
| Midstream capital expenditures | 36,417 | 74,604 | 71,243 | |||||||||||||||||
| Expenditures for other property and equipment | 404 | 415 | (210) | |||||||||||||||||
| Decrease in capital accruals | (30,753) | (43,000) | (29,849) | |||||||||||||||||
Accrual-based San Mateo capital expenditures related to non-controlling interest in subsidiaries(2) | (6,083) | (26,870) | (60,285) | |||||||||||||||||
Total accrual-based capital expenditures(3) | 70,516 | 122,343 | 166,137 | |||||||||||||||||
| Adjusted free cash flow | $ | 60,734 | $ | (18,043) | $ | (2,956) | ||||||||||||||
(1)Represents Five Point’s 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, and for the three months ended December 31, 2019, amounts related to Five Point’s $50 million carry of Matador’s proportionate interest in San Mateo II.
(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 | ||||||||||||||||||||
| (In thousands) | December 31, 2020 | September 30, 2020 | December 31, 2019 | |||||||||||||||||
| Net cash provided by San Mateo operating activities | $ | 26,131 | $ | 24,795 | $ | 23,834 | ||||||||||||||
| Net change in San Mateo operating assets and liabilities | 7,716 | 1,477 | 199 | |||||||||||||||||
| San Mateo discretionary cash flow | 33,847 | 26,272 | 24,033 | |||||||||||||||||
| San Mateo capital expenditures | 36,333 | 74,712 | 71,921 | |||||||||||||||||
| (Decrease) increase in San Mateo capital accruals | (23,919) | (19,875) | 13,166 | |||||||||||||||||
| Accrual-based San Mateo capital expenditures | 12,414 | 54,837 | 85,087 | |||||||||||||||||
| Adjusted San Mateo free cash flow | $ | 21,433 | $ | (28,565) | $ | (61,054) | ||||||||||||||
20
Exhibit 99.2
MATADOR RESOURCES COMPANY ANNOUNCES
2021 OPERATING PLAN AND MARKET GUIDANCE
DALLAS, Texas, February 23, 2021 -- Matador Resources Company (NYSE: MTDR) (“Matador” or the “Company”) today announced its full year 2021 operating plan and market guidance. A slide presentation summarizing the highlights of Matador’s 2021 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 2020.
Full Year 2021 Guidance Summary
Matador’s full year 2021 guidance estimates are summarized in the table below.
| Guidance Metric | Actual 2020 Results | 2021 Guidance | % YoY Change(1) | ||||||||
| Total Oil Production | 15.9 million Bbl | 17.2 to 17.8 million Bbl | +10% | ||||||||
| Total Natural Gas Production | 69.5 Bcf | 76.0 to 79.0 Bcf | +12% | ||||||||
| Total Oil Equivalent Production | 27.5 million BOE | 29.9 to 31.0 million BOE | +11% | ||||||||
D/C/E CapEx(2) | $450 million | $525 to $575 million | +22% | ||||||||
Midstream CapEx(3) | $89 million | $20 to $30 million | -72% | ||||||||
| Total D/C/E and Midstream CapEx | $539 million | $545 to $605 million | +7% | ||||||||
(1) Represents percentage change from 2020 actual results to the midpoint of 2021 guidance.
(2) Capital expenditures associated with drilling, completing and equipping wells.
(3) Primarily reflects Matador’s share of capital expenditures for San Mateo Midstream, LLC (“San Mateo”).
The full year 2021 guidance estimates presented in the table above are based upon the following key assumptions for 2021 drilling and completions activity and capital expenditures.
•Matador estimates 2021 capital expenditures for drilling, completing and equipping wells (“D/C/E capital expenditures”) of $525 to $575 million, inclusive of an estimated $58 million for non-operated well opportunities, $38 million for artificial lift and other production-related capital expenditures, $18 million of capitalized general and administrative and interest expenses and an average 10% increase in drilling and completion costs in anticipation of increased service costs beginning in the second quarter of 2021. Matador anticipates continued improvement in its capital efficiency in 2021, with drilling and completion costs for operated horizontal wells turned to sales in 2021 expected to average approximately $730 per completed lateral foot.
•Matador began 2021 operating three drilling rigs in the Delaware Basin but plans to add a fourth operated drilling rig beginning in March. The Company then expects to operate four drilling rigs in the Delaware Basin throughout the remainder of 2021.
•Matador expects 49 gross (45.6 net) operated horizontal wells, with an average completed lateral length of 10,400 feet, should be turned to sales during 2021. Matador estimates that 48 wells, or 98%, will have lateral lengths of two miles or greater. Matador anticipates that it will have 83 gross (76.8 net) operated wells in progress at varying times during 2021, 82 of which are expected to have lateral lengths of two miles or greater.
1
•Matador expects to participate in 76 gross (7.0 net) non-operated well opportunities during 2021, including 68 gross (6.7 net) non-operated wells anticipated to be completed and turned to sales in the Delaware Basin and eight gross (0.3 net) non-operated wells anticipated to be completed and turned to sales in the Haynesville shale. Matador estimates that 72 of these non-operated wells, or 95%, will have lateral lengths greater than one mile, including 51 wells, or 67%, that are expected to have lateral lengths of two miles or greater.
•Matador estimates 2021 midstream capital expenditures of $20 to $30 million. This estimate reflects Matador’s 51% share of San Mateo’s 2021 estimated capital expenditures of $39 to $59 million.
Management Comments Regarding 2021 Operating Plan
Joseph Wm. Foran, Matador’s Chairman and CEO, commented, “The Board, the staff and I are pleased today to provide our 2021 operating plan and market guidance. We believe this year should be particularly exciting for Matador and its shareholders, as we work to continue developing our excellent Delaware Basin assets, transition to free cash flow, pay down debt and institute a dividend to augment our returns to our shareholders.
“We began 2021 operating three drilling rigs in the Delaware Basin and had planned to operate these three rigs there throughout 2021. As a result of recent actions taken by the newly inaugurated Biden administration, we have elected to pick up a fourth operated drilling rig beginning in March to ensure the orderly development of our federal leasehold in the Delaware Basin going forward. As you are most likely aware, in late January 2021, following President Biden’s inauguration, the United States Department of the Interior ordered a 60-day pause limiting the authority of local offices of the Bureau of Land Management (“BLM”) to grant federal drilling permits and certain extensions, sundries, rights-of-way and other necessary approvals for the development of federal oil and natural gas leases. This order did not impact operations on existing valid federal leases, and we have continued active operations on our existing federal properties, such as the Stateline asset area and the Rodney Robinson leasehold, without any difficulties since this order was issued. While we remain optimistic that the BLM will resume its timely approval of such requests on federal leases in late March following this 60-day pause, we cannot be sure as to what, if any, changes may be forthcoming regarding operations on federal properties and our ability to develop our federal leasehold. Thus, we believe it is a prudent action on our part to add a fourth drilling rig, for now, to our 2021 operating plan to accelerate the development of our existing federal permits. Beginning in March 2021, we expect to begin operating four drilling rigs in the Delaware Basin and plan to do so throughout the remainder of 2021, with an increased focus on the development of our federal properties in New Mexico.
“We were pleased to announce yesterday that Matador’s Board of Directors adopted a dividend policy and declared Matador’s first quarterly cash dividend of $0.025 per share, amounting to $0.10 per share, or approximately $12 million, on an annualized basis. Initiation of the dividend policy marks a significant step for Matador in returning value to our shareholders and also indicates our confidence in Matador’s financial strength and ability to generate free cash flow going forward. During the fourth quarter of 2020, Matador achieved adjusted free cash flow, and we expect to generate adjusted free cash flow in aggregate in 2021 as well, even in light of adding the fourth operated drilling rig, given the current outlook for oil and natural gas prices in 2021.
“Matador’s 2021 drilling program will focus on our federal properties, which include some of the best acreage in the Delaware Basin, including the continued development of our Stateline asset area in southern Eddy County, New Mexico, continued drilling of the Rodney Robinson federal leasehold in western Antelope Ridge and further development of the Greater Stebbins Area in the southern portion of our Arrowhead asset area, where all wells we turn to sales in 2021 are anticipated to be two-mile or longer laterals. In fact, the transition to drilling and completing longer laterals throughout our various asset areas in the Delaware Basin, which we began in 2019 and continued in 2020, has been fully realized. In 2021, 98%, or all but one, of the operated horizontal laterals we complete and turn to sales are expected to have lateral lengths of two miles or greater, as compared to 74% in 2020, 9% in 2019 and only one two-mile lateral in 2018. These longer laterals are delivering better well performance and
2
economic returns. In 2021, Matador should also begin receiving performance incentives from our joint venture partner in San Mateo as we execute our operational plan in the Stateline asset area and the Greater Stebbins Area and connect to San Mateo’s gathering and transportation systems. This will further enhance the returns from these wells and provide an additional source of free cash flow to Matador in 2021.
“We are anticipating a number of key milestones in 2021, as we did in 2020, that are expected to add significant value to Matador and its midstream affiliate, San Mateo, while positioning Matador for continued growth and free cash flow in the coming years. The first of these milestones should occur in March 2021 when production from four new Rodney Robinson wells in the western portion of our Antelope Ridge asset area and two wells in our Ranger asset area is turned to sales. The second milestone should be realized in April and May when we turn to sales production from the first 13 Voni wells in our Stateline asset area, all of which are expected to have completed lateral lengths of approximately 12,000 feet, or about 2.3 miles. Given the strong early performance from the first 13 Boros wells turned to sales in September 2020 in the Stateline asset area, we are particularly excited to get this first group of Voni wells on production. During the summer, we expect to reach a third milestone when we turn to sales production from the first four of 13 wells we expect to drill and complete in the Greater Stebbins Area during 2021. The fourth and final key milestone for 2021 should occur in late October and through November when the remaining nine wells in the Greater Stebbins Area, along with the next 13 Boros wells in the Stateline asset area, are expected to be turned to sales. As a result of our operated and non-operated drilling activities in 2021, we anticipate 10 to 12% growth in our oil equivalent production and should exit 2021 well positioned for further growth in 2022. This will not be ‘growth for growth’s sake’ but profitable growth at a measured pace that results from our decision to preserve and bring forward the value of our federal properties for all of Matador’s stakeholders at a time of increasing federal uncertainty and increasing commodity prices.
“San Mateo concluded a record quarter in the fourth quarter of 2020 and a record year in 2020 and is poised to have another record year in 2021. During the fourth quarter of 2020, San Mateo also achieved adjusted free cash flow, as it enjoyed the first full quarter of operations following the completion and successful startup of the expansion of the Black River Processing Plant and related pipeline infrastructure and began gathering and processing natural gas and gathering, transporting and handling oil and produced water from Matador’s Stateline asset area and the Greater Stebbins Area. San Mateo expects to generate adjusted free cash flow throughout 2021, given the current maintenance level of capital expenditures budgeted for 2021. The San Mateo team will be working hard in 2021 to add new non-Matador customers to its ‘three-pipe’ midstream system throughout Eddy County, New Mexico, which, if successful, could require additional capital expenditures in 2021.
“As we execute our 2021 operating plan, Matador will continue to be mindful of our balance sheet as we have always been, and one of our key objectives for 2021 will be continuing to pay down debt under our reserves-based credit facility. As we reported in our fourth quarter 2020 earnings release issued today along with this 2021 guidance release, we have reduced the borrowings outstanding under our reserves-based credit facility by $45 million and under the San Mateo credit facility by $11 million since our previous earnings release in late October 2020. We ended 2020 with a leverage ratio under our reserves-based credit facility of 2.9x, below our expectations of 3.2x at the end of the third quarter and far below our expectations in March and April of 2020 of as high as 3.9x by year-end 2020. The Board and I would like to congratulate and commend the entire Matador team for all the hard work and professionalism they demonstrated in 2020 to allow Matador to successfully weather the many challenges faced by our society and the oil and natural gas industry in 2020 and to position ourselves well for further prosperity in 2021 and going forward.
“The Board, the staff and I are confident in our abilities to execute this 2021 operating plan. We are excited about the milestones in front of us in 2021 and are off to a good start. In short, we believe this 2021 operating plan should generate substantial value growth for our stakeholders in the year ahead and for years to come.”
3
Federal Acreage and Permits
In light of the Company’s decision to add a fourth rig to its 2021 operated drilling program beginning in March to focus on development of its federal properties, Matador provides the following update on its federal acreage position and federal drilling permits.
Federal Acreage Update
At December 31, 2020, Matador held approximately 124,700 net leasehold and mineral acres in the Delaware Basin in Eddy and Lea Counties, New Mexico and in Loving County, Texas, of which approximately 34,500 net acres, or about 28%, were on federal lands. Approximately 90,200 net acres, or about 72%, of the Company’s Delaware Basin leasehold and mineral position are comprised of private (fee) and state leasehold. In addition, at December 31, 2020, Matador held approximately 26,300 net acres in the Eagle Ford shale play in South Texas and approximately 17,700 net acres in the Haynesville shale play in Northwest Louisiana, the vast majority of which were located on private (fee) and state lands. Including the Company’s South Texas and Northwest Louisiana acreage and mineral positions, at December 31, 2020, only about 21% of Matador’s total net leasehold and mineral acreage was on federal lands, giving the Company considerable options for oil and natural gas development across its acreage position and years of additional drilling inventory, including many “A+ locations,” outside of its federal leasehold position.
A more detailed breakdown of Matador’s federal leasehold position by asset area in the Delaware Basin is provided in the table below.
| Delaware Basin | Federal | Federal, as % of | ||||||||||||
| Delaware Basin Asset Area | County | Leasehold | Leasehold | Delaware Basin Leasehold | ||||||||||
| (net acres) | (net acres) | |||||||||||||
| Antelope Ridge | Lea | 16,000 | 7,300 | 6% | ||||||||||
| Rustler Breaks | Eddy | 26,200 | 1,600 | 1% | ||||||||||
| Stateline | Eddy | 2,800 | 2,800 | 2% | ||||||||||
| Arrowhead | Eddy | 26,800 | 14,000 | 11% | ||||||||||
| Ranger | Lea | 18,400 | 8,400 | 7% | ||||||||||
| Twin Lakes | Lea | 23,200 | 400 | — | ||||||||||
| Wolf/Jackson Trust | Loving | 10,800 | — | — | ||||||||||
| Other | — | 500 | — | — | ||||||||||
| TOTAL | 124,700 | 34,500 | 28% | |||||||||||
At December 31, 2020, Matador estimates that approximately 70% of its federal leasehold in the Delaware Basin was held by production, including all 1,200 net acres in the recently drilled Rodney Robinson leasehold and approximately 1,280 net acres in the Stateline asset area. Matador should soon have the entire Stateline asset area held by production when the first 13 Voni wells in the western portion of the Stateline asset area are turned to sales, which is expected to begin in April 2021. Once the Stateline asset area is fully held by production, Matador estimates that approximately 75% of its federal leasehold would then be held by production. Further, approximately 23%, or 7,800 net acres, of Matador’s federal acreage position in the Delaware Basin, or almost all the Company’s remaining federal leasehold in the Delaware Basin, is not subject to expiration before 2028.
4
Federal Permits Update
The table below summarizes the Company’s undrilled federal drilling permits, approved and in progress, at February 23, 2021.
| Undrilled Permits | Undrilled Permits | ||||||||||
| Delaware Basin Asset Area | County | Approved and Received | in Progress | ||||||||
Antelope Ridge (Rodney Robinson)(1) | Lea | 18 | 1 | ||||||||
| Antelope Ridge (All other) | Lea | 30 | 13 | ||||||||
| Arrowhead | Eddy | 32 | 45 | ||||||||
Ranger(1) | Lea | 21 | 6 | ||||||||
| Rustler Breaks | Eddy | 22 | 33 | ||||||||
Stateline (Boros)(1) | Eddy | 23 | — | ||||||||
Stateline (Voni)(1) | Eddy | 31 | — | ||||||||
| TOTAL | 177 | 98 | |||||||||
(1) Does not include permits approved for 10 Rodney Robinson, 21 Boros, 13 Voni and two Ranger wells (46 wells) that were drilled in 2020 or are currently in progress in early 2021. | |||||||||||
At February 23, 2021, Matador had secured 177 approved and undrilled federal drilling permits and had 98 additional permits under review by the BLM for future drilling on federal lands across its various asset areas in the Delaware Basin. In addition, at February 23, 2021, Matador had a total of 19 wells undergoing completion operations on its federal leasehold, including 13 Voni wells in the Stateline asset area, four wells on the Rodney Robinson leasehold and two wells in the Ranger asset area, as well as eight (soon to be 13) new Boros wells currently being drilled in the Stateline asset area. These 27 wells are excluded from the 177 approved and undrilled federal permits noted above, although these wells have yet to be turned to sales. Since the Company’s last update of its federal permit status on October 27, 2020, Matador has drilled wells using a total of 12 federal permits—two in its Ranger asset area, two additional permits in its Rodney Robinson leasehold and eight (soon to be 13) Boros permits in the Stateline asset area. A total of 24 federal permits in the Rustler Breaks and Arrowhead asset areas were also allowed to expire prior to December 31, 2020, as these permits were for shorter lateral wells (primarily one-mile laterals) or wells that are not expected to be drilled within the next several years given Matador’s current expectations for its operated drilling program. Matador also received federal permits for three new wells in its Arrowhead asset area during the fourth quarter of 2020.
At February 23, 2021, Matador had received approved drilling permits for all of its planned Boros and Voni wells in the Stateline asset area and all but one of its planned wells on the Rodney Robinson leasehold. The Company also believes that it has secured all necessary surface disturbance, facilities and right-of-way permits necessary to complete its planned development of these asset areas. Matador expects to continue submitting requests for new federal drilling permits, sundries, extensions to existing permits, rights of way and other necessary federal approvals for the development of its federal leases and remains optimistic that the BLM will resume its approval of these requests on existing federal leases in late March following the 60-day pause imposed by the United States Department of the Interior in late January 2021.
2021 Operating Plan
The table below provides Matador’s expectations for operated and non-operated wells to be completed and turned to sales during 2021. Additional details regarding Matador’s drilling and completions program for 2021 are provided in the sections that follow and in the slide presentation accompanying this press release.
5
| Operated | Non-Operated | Total | Gross Operated | ||||||||||||||||||||||||||
| Asset/Operating Area | Gross | Net | Gross | Net | Gross | Net | Well Completion Intervals | ||||||||||||||||||||||
Western Antelope Ridge (Rodney Robinson) | 4 | 3.8 | - | - | 4 | 3.8 | 2-3BS, 2-WC A-XY | ||||||||||||||||||||||
Antelope Ridge (All Other) | - | - | 20 | 1.4 | 20 | 1.4 | No operated completions in 2021 | ||||||||||||||||||||||
| Arrowhead | 13 | 11.4 | 12 | 1.2 | 25 | 12.6 | 4-2BS, 4-3BS, 4-WC A-XY, 1-WC B | ||||||||||||||||||||||
| Ranger | 4 | 2.7 | 8 | 1.3 | 12 | 4.0 | 4-2BS | ||||||||||||||||||||||
| Rustler Breaks | - | - | 28 | 2.8 | 28 | 2.8 | No operated completions in 2021 | ||||||||||||||||||||||
| Stateline | 26 | 26.0 | - | - | 26 | 26.0 | 3-AVLN, 3-1BS, 6-2BS, 4-3BSC, 4-WC A-XY, 4-WC A-Lower, 2-WC B | ||||||||||||||||||||||
| Twin Lakes | - | - | - | - | - | - | No completions in 2021 | ||||||||||||||||||||||
| Wolf/Jackson Trust | 2 | 1.7 | - | - | 2 | 1.7 | 2-2BS | ||||||||||||||||||||||
| Delaware Basin | 49 | 45.6 | 68 | 6.7 | 117 | 52.3 | |||||||||||||||||||||||
| Eagle Ford Shale | - | - | - | - | - | - | No completions in 2021 | ||||||||||||||||||||||
| Haynesville Shale | - | - | 8 | 0.3 | 8 | 0.3 | No operated completions in 2021 | ||||||||||||||||||||||
| Total | 49 | 45.6 | 76 | 7.0 | 125 | 52.6 | |||||||||||||||||||||||
Note: AVLN = Avalon; WC = Wolfcamp; BS = Bone Spring; BSC = Bone Spring Carbonate. For example, 2-3BS indicates two Third Bone Spring completions and 2-WC A-XY indicates two Wolfcamp A-XY completions for full year 2021.
Delaware Basin
Matador began 2021 operating three drilling rigs in the Delaware Basin but has recently contracted a fourth operated drilling rig, which is expected to begin drilling operations in the Company’s Stebbins area and surrounding leasehold in the Arrowhead asset area (the “Greater Stebbins Area”) in March 2021. Matador then expects to operate four drilling rigs in the Delaware Basin throughout the remainder of 2021. Two of these rigs are expected to operate full time in the Stateline asset area. The other two rigs are expected to operate in certain of the Company’s other asset areas, including the Greater Stebbins Area, the Wolf asset area, the Ranger asset area and the Rodney Robinson leasehold in the western portion of the Antelope Ridge asset area.
Matador expects to complete and turn to sales 49 gross (45.6 net) operated wells in the Delaware Basin in 2021, as follows.
•Six gross (5.1 net) wells in the first quarter, including four wells in the Rodney Robinson leasehold and two wells in the Ranger asset area;
•15 gross (14.7 net) wells in the second quarter, including the first 13 Voni wells in the Stateline asset area and two wells in the Wolf asset area;
•Four gross (3.5 net) wells in the third quarter, all in the Greater Stebbins Area; and
•24 gross (22.3 net) wells in the fourth quarter, including nine wells in the Greater Stebbins Area, 13 additional Boros wells in the Stateline asset area and two wells in the Ranger asset area.
Additional key features of Matador’s 2021 Delaware Basin operating program are noted below.
•98% of Matador’s gross operated horizontal wells completed and turned to sales in 2021 are expected to have lateral lengths of two miles or greater, as compared to 74% in 2020 and just 9% in 2019. Only one well in the Wolf asset area is expected to be a 1.5-mile lateral. Matador estimates its average completed lateral length for
6
operated wells turned to sales in 2021 should be approximately 10,400 feet, an increase of 18%, as compared to an average completed lateral length of approximately 8,800 feet in 2020.
•Matador expects to complete and turn to sales approximately 508,000 gross lateral feet in its operated horizontal wells in 2021, an increase of 9%, as compared to 465,000 gross lateral feet in 2020. These projected results reflect improvements the Company continues to make in its operating efficiency and overall rig productivity.
•Matador anticipates continued improvement in its capital efficiency, with drilling and completion costs for operated horizontal wells turned to sales in 2021 estimated to average approximately $730 per completed lateral foot. This represents a 14% decline in average drilling and completion costs per completed lateral foot, as compared to $850 per completed lateral foot in 2020, and a decline of 37% from $1,165 per completed lateral foot in 2019. Matador anticipates this continued improvement in capital efficiency in 2021, despite its expectations of an average 10% increase in drilling and completions costs beginning in the second quarter of 2021.
•In addition to the capital efficiencies generated using multi-well pads and other techniques, co-development of formations in Matador’s Stateline asset area, the Rodney Robinson leasehold in western Antelope Ridge and the Greater Stebbins Area should continue to boost the well returns in those areas, as Matador believes this approach should minimize the impact of reservoir drainage, as well as shut-ins and downtime associated with hydraulic fracturing operations in future wells.
•The average working interest of operated wells expected to be completed and turned to sales in the Delaware Basin in 2021 is estimated to be 93%, as compared to 86% in 2020.
•Production growth and capital expenditures are expected to continue to be uneven or “lumpy” on a quarterly basis, similar to what Matador experienced in 2020. Capital expenditures are expected to be highest in the first and third quarters of 2021, as most of the Company’s completion activities for 2021 should occur during those quarters. Conversely, the Company’s anticipated production growth is expected to increase sharply on a sequential basis in the second and fourth quarters, while declining sequentially in the first and third quarters of 2021.
•Matador expects to have 34 gross (31.2 net) operated Delaware Basin wells in progress, but not yet turned to sales, at year-end 2021, as many of these wells are associated with larger, multi-well pads expected to be in progress at year-end 2021. Although these wells will not contribute to production growth in 2021, many of these wells should be completed and turned to sales late in the first quarter or early in the second quarter of 2022, which Matador anticipates could result in a higher rate of production growth in 2022 as compared to 2021.
Stateline Asset Area – Eddy County, New Mexico
At February 23, 2021, Matador was operating two rigs in the Stateline asset area and expects to continue operating two rigs there throughout 2021. The Company is currently completing the first 13 Voni wells on the western side of the Stateline asset area, and these wells are expected to be turned to sales in April and May 2021. The two rigs are currently drilling eight (soon to be 13) additional Boros wells on the eastern side of the Stateline asset area, and these wells are expected to be turned to sales in late October and November 2021. Once drilling operations are completed on the current Boros wells, the two rigs will move back to the western side of the Stateline asset area to begin drilling an additional 12 Voni wells, but these wells are not expected to be turned to sales until the second quarter of 2022.
7
Arrowhead and Ranger Asset Areas – Eddy and Lea Counties, New Mexico
Matador plans to operate two drilling rigs in the Greater Stebbins Area beginning in March 2021. The Company expects to drill and complete 13 wells in this area during 2021. The first four wells are expected to be turned to sales in early July, while the remaining nine wells should be turned to sales in late November 2021. Once these 13 wells are drilled, one of these rigs is expected to drill two wells in the Ranger asset area before returning to the Rodney Robinson leasehold in the western portion of the Antelope Ridge asset area. The other rig is also expected to move to the Rodney Robinson leasehold, and both rigs should drill a total of nine wells there before the end of 2021.
Matador is currently completing two wells in the Ranger asset area, and these wells are expected to be turned to sales in mid-March 2021. Matador expects to complete and turn to sales two additional wells in the Ranger asset area in early October 2021.
Antelope Ridge and Rustler Breaks Asset Areas – Lea and Eddy Counties, New Mexico
Matador is currently completing four 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 2021. Beginning in August 2021, as noted above, Matador plans to return to the Rodney Robinson leasehold with two rigs to drill a total of nine wells before the end of 2021, but these wells are not expected to be turned to sales until the second quarter of 2022. The Company does not plan to turn to sales any other operated wells in the Antelope Ridge asset area in 2021.
Matador does not currently expect to turn to sales any operated wells in the Rustler Breaks asset area in 2021.
Wolf Asset Area – Loving County, Texas
Matador expects to drill and complete two wells in the Wolf asset area in 2021. At February 23, 2021, drilling operations had been completed on one well, with drilling operations on the second well projected to conclude by the end of February. These wells are expected to be completed early in the second quarter and turned to sales in May 2021.
Non-Operated Activity
Matador anticipates increased non-operated drilling and completions activity on certain of its properties in 2021. In 2021, the Company expects to participate in 76 gross (7.0 net) non-operated wells completed and turned to sales in the Delaware Basin and the Haynesville shale, as compared to 40 gross (2.2 net) non-operated wells completed and turned to sales in 2020. Matador anticipates no non-operated activity on its properties in South Texas in 2021.
2021 Production Estimates and Cadence
Oil, Natural Gas and Oil Equivalent Production Growth and Anticipated Cadence
Matador expects to continue drilling longer horizontal laterals from multi-well pads in 2021, almost all with lateral lengths of two miles or greater. This, in turn, will result in an uneven cadence of wells being completed and turned to sales in any given period, much like the Company experienced in 2020. As a result, Matador expects its production growth to continue to be uneven or “lumpy” from quarter to quarter, with the second and fourth quarters of 2021 anticipated to have the largest sequential increases in total production.
The table below provides Matador’s estimates for anticipated sequential changes in its average daily oil, natural gas and total oil equivalent production on a quarterly basis throughout 2021. While the table below should provide a
8
reasonable expectation of the Company’s production growth profile for 2021 as of February 23, 2021, the Company anticipates updating these quarterly estimates for the second quarter of 2021 and future periods throughout the year, as necessary, to reflect its actual results and then-current estimates.
| Sequential Change by Quarter | |||||||||||
| Period | Average Daily Total Production | Average Daily Oil Production | Average Daily Natural Gas Production | ||||||||
| Q1 2021 | -13% to -15% | -15% to -17% | -10% to -12% | ||||||||
| Q2 2021 | +21% to +23% | +24% to +26% | +17% to +19% | ||||||||
| Q3 2021 | -4% to -6% | -4% to -6% | -5% to -7% | ||||||||
| Q4 2021 | +8% to +10% | +8% to +10% | +8% to +10% | ||||||||
Note: Please see discussion below on expected weather impacts to first quarter 2021 production cadence.
Matador’s estimated 2021 total oil equivalent production of 30.45 million barrels of oil equivalent (“BOE”), or an average daily oil equivalent production of 83,400 BOE per day (57% oil), at the midpoint of 2021 guidance, reflects a year-over-year increase of 11%, as compared to 27.5 million BOE (58% oil), or 75,200 BOE per day, produced in 2020. The Company anticipates its average daily oil equivalent production should increase 9% from 83,200 BOE per day in the fourth quarter of 2020 to approximately 90,700 BOE per day in the fourth quarter of 2021. As essentially all of its 2021 operating activities are planned for the Delaware Basin, Matador expects a higher level of production growth in the Delaware Basin in 2021, offsetting production declines from both the Company’s South Texas and Haynesville shale asset areas throughout the year.
Matador’s estimated 2021 total oil production of 17.5 million barrels, or an average daily oil production of 47,900 barrels per day, at the midpoint of 2021 guidance, reflects an increase of 10%, as compared to 15.9 million barrels, or an average daily oil production of 43,500 barrels per day, produced in 2020. The Company anticipates its average daily oil production should increase 9% from 48,000 barrels of oil per day in the fourth quarter of 2020 to approximately 52,500 barrels of oil per day in the fourth quarter of 2021.
Matador’s estimated 2021 total natural gas production of 77.5 billion cubic feet, or an average daily natural gas production of 212 million cubic feet per day, at the midpoint of 2021 guidance, reflects an increase of 12%, as compared to 69.5 billion cubic feet, or an average daily natural gas production of 190 million cubic feet per day, produced in 2020. The Company anticipates its average daily natural gas production should increase 9% from 211 million cubic feet per day in the fourth quarter of 2020 to approximately 229 million cubic feet per day in the fourth quarter of 2021.
Delaware Basin Production Growth
Matador estimates total oil equivalent production of 28.7 million BOE (59% oil) from the Delaware Basin, or 78,600 BOE per day, at the midpoint of 2021 guidance, a year-over-year increase of 16% from 2020. The Company anticipates its total oil and natural gas production from the Delaware Basin should increase 11% and 25%, respectively, year-over-year at the midpoint of 2021 production guidance.
First Quarter 2021 Production Estimates and Weather Impacts
As noted in the table above, Matador expects its production to decline substantially in the first quarter of 2021, as compared to the fourth quarter of 2020. Matador had anticipated an approximate 10% sequential decrease in production in the first quarter, primarily attributable to fewer wells being completed and turned to sales both in the fourth quarter of 2020 and the first two months of 2021, as compared to prior periods, and to the timing of new wells anticipated to be turned to sales late in the first quarter of 2021. In addition, several of the Boros and Rodney
9
Robinson wells have been shut in as anticipated for portions of the first quarter of 2021, as newly drilled offsetting wells are completed in those areas, and this has also impacted first quarter production.
Matador’s production in the first quarter of 2021 has also been impacted by the historically prolonged cold weather conditions experienced in New Mexico and Texas during the middle to latter portions of February. During that time, Matador estimates that its average daily oil equivalent production was down approximately 30%, although the Company is pleased to report that it continued producing and selling the majority of its oil and natural gas during this difficult period. Matador commends the efforts of its production and field operations teams to keep most of the Company’s properties operational during this challenging time.
Accounting for this unprecedented period of cold weather, Matador now expects its oil equivalent production to decline approximately 13 to 15% in the first quarter of 2021, as noted in the table above. Further, in providing this first quarter 2021 guidance, Matador has assumed minimal impact to its production volumes due to insufficient storage capacity or damage to refineries downstream of the Company’s operations. Should these or other matters impact the Company’s ability to produce its wells in late February or into March, Matador expects that its first quarter 2021 production could decline further.
During the first quarter of 2021, Matador still plans to complete and turn to sales six gross (5.1 net) operated wells, but these wells are expected to be turned to sales in mid-to-late March near the end of the first quarter. As a result, these wells are expected to have minimal impact on Matador’s first quarter 2021 production.
First Quarter 2021 Realized Commodity Price Estimates
For the first quarter of 2021, Matador’s weighted average oil price differential relative to the NYMEX West Texas Intermediate benchmark price, inclusive of the monthly roll and transportation costs, is anticipated to be in the range of ($1.00) to ($2.00).
For the first quarter of 2021, Matador’s weighted average natural gas price differential relative to the Henry Hub benchmark price is anticipated to be in the range of +$0.50 to +$1.00, primarily attributable to improved natural gas price differentials at the Waha hub in West Texas, as well as to recent improvements in prices for natural gas liquids.
2021 Estimated Capital Expenditures
D/C/E Capital Expenditures
As noted in the summary table at the beginning of this press release, Matador estimates D/C/E capital expenditures of $525 to $575 million in 2021, as compared to D/C/E capital expenditures of $450 million for full year 2020. As previously noted, these anticipated 2021 D/C/E capital expenditures are inclusive of an estimated $58 million for non-operated well opportunities, $38 million for artificial lift and other production-related capital expenditures, $18 million of capitalized general and administrative and interest expenses and an average 10% increase in drilling and completion costs in anticipation of increased service costs beginning in the second quarter of 2021.
Matador’s 2021 D/C/E capital expenditures also include 34 gross (31.2 net) Delaware Basin wells expected to be in progress at year-end 2021, as compared to 20 gross (19.1 net) wells in progress at year-end 2020, and these capital expenditures will not contribute to Matador’s production in 2021.
Midstream Capital Expenditures
In 2021, Matador estimates it will incur midstream capital expenditures of $20 to $30 million, reflecting its 51% share of San Mateo’s total 2021 estimated capital expenditures of $39 to $59 million. San Mateo’s 2021 capital
10
expenditures are expected to primarily consist of (i) routine installation of gathering or transportation infrastructure needed to provide service for newly-drilled wells operated by Matador and other San Mateo customers, (ii) routine maintenance and improvements of existing facilities and (iii) the drilling and completion of a new produced water disposal well and the related infrastructure in Matador’s Greater Stebbins Area to handle additional produced water volumes anticipated as a result of Matador’s increased drilling and completions activity in that area in 2021. In addition, should San Mateo be awarded a significant midstream contract by a customer other than Matador during 2021, additional capital expenditures would almost certainly be required, and any necessary adjustments to San Mateo’s 2021 capital expenditures would be made at that time.
Performance Incentives
In connection with the original formation of San Mateo in February 2017, Matador had the potential to earn up to $73.5 million in performance incentives from a subsidiary of Five Point Energy LLC (“Five Point”) over a five-year period, which was extended to a six-year period in October 2020. These performance incentives are primarily associated with wells that Matador completes and turns to sales in and around the Rustler Breaks and Wolf asset areas. At February 23, 2021, Matador had earned $58.8 million of the potential $73.5 million in performance incentives. Through February 23, 2021, Five Point had paid $14.7 million in performance incentives in each of the first quarters of 2018, 2019 and 2020, and Matador expects Five Point to pay an additional $14.7 million in performance incentives to the Company in the first quarter of 2021. Matador may earn up to the remaining $14.7 million in original San Mateo performance incentives from Five Point over the next two years.
In addition, Matador could earn up to an additional $150 million in performance incentives from Five Point over the next several years related to the San Mateo expansion projects initiated in February 2019 and completed in the fall of 2020. These performance incentives would be in addition to the $73.5 million in performance incentives noted above and are primarily associated with wells that Matador completes and turns to sales in and around the Stateline asset area and the Greater Stebbins Area. During the fourth quarter of 2020, Matador met the threshold requirements to begin earning the additional $150 million in performance incentives from Five Point. Matador earned the first $0.7 million of these performance incentives in the fourth quarter of 2020, and Five Point paid this $0.7 million to Matador in the first quarter of 2021. Going forward, Matador expects to earn performance incentives from Five Point as we execute our operational plan in the Stateline asset area and the Greater Stebbins Area and connect to San Mateo’s gathering and transportation systems over the next several years. These incentive payments are generally due to be paid to Matador by Five Point throughout the course of the year.
At February 23, 2021, Matador anticipates that the total performance incentive payments to be received from Five Point during 2021 could be approximately $35 million. It is important to remember that these San Mateo performance incentives are paid directly from Five Point to Matador and do not impact San Mateo’s net income, Adjusted EBITDA or adjusted free cash flow. These performance incentives are not included in Matador’s net income or Adjusted EBITDA, because they are accounted for as equity contributions in the Company’s consolidated financial statements. Matador does include these performance incentives in its estimates of adjusted free cash flow, as these incentive payments are a source of additional cash flow for the Company.
Conference Call Information
The Company will host a live conference call on Wednesday, February 24, 2021, at 9:00 a.m. Central Time to discuss its fourth quarter and full year 2020 financial and operational results, as well as its 2021 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 6492069. 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, 2021.
11
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 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; 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 our business; the operating results of the Company’s midstream joint venture’s Black River natural gas cryogenic 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 which 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
12
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
13