www.matadorresources.com<\/a> on the Events and Presentations page under the Investor Relations tab.\n<\/p>\nManagement Summary Comments<\/b><\/p>\n
\nIn summarizing the year, Joseph Wm. Foran, Matador\u2019s Founder, Chairman and CEO, noted, \u201cBefore I report that 2024 was another record year for Matador, I want to express my appreciation to each of our shareholders, office and field staff, board members, management, vendors, banks, partners and other stakeholders for their continued interest, friendship and support in making these results happen. It has been a team effort. Building on our 2024 plans, our 2025 plan is again expected to yield record results. The Matador team and I are excited to discuss not only our 2024 accomplishments with you but also the opportunities we have in front of us for 2025.\n<\/p>\n
Dividend Increase<\/i><\/p>\n
\n\u201cFirst, I am pleased to announce that Matador\u2019s Board of Directors (the \u2018Board\u2019) has approved a 25% increase in Matador\u2019s dividend policy, raising the dividend from $1.00 annually, or $0.25 per quarter, to $1.25 annually, or $0.3125 per quarter (see Slide A<\/b>). In accordance with this new dividend policy, the Board formally declared a quarterly cash dividend of $0.3125 per share of common stock payable on March 14, 2025 to shareholders of record as of February 28, 2025. Matador believes that a steadily increasing fixed dividend is the best way to comfortably return cash to its shareholders while also continuing to build value through growing our upstream and midstream businesses. Matador has now raised its dividend six times in four years.\n<\/p>\n
\n\u201cRaising the dividend\u2014and senior management buying the stock, of which there are 30 \u2018buys\u2019 since 2021 and no \u2018sells\u2019\u2014is the sincerest way we know to express our confidence in the operational and financial outlook for Matador going forward (see Slide A<\/b> and Slide T<\/b>). The Board and I would now like to point out some accomplishments that support this dividend increase. These accomplishments include the successful integration of the Advance and Ameredev acquisitions, which are performing as well or better than Matador expected; the addition of 50,000 net acres to our inventory; and the combination of Pronto Midstream, LLC (\u2018Pronto\u2019) with San Mateo Midstream, LLC (\u2018San Mateo\u2019) in December 2024 (the \u2018Pronto Transaction\u2019), which resulted in Matador receiving $220 million in cash and the ability to earn up to $75 million in additional performance incentives. Furthermore, this dividend increase reflects the Board\u2019s confidence in Matador\u2019s ability to generate increased adjusted free cash flow going forward. Matador projects adjusted free cash flow will approach $1 billion in 2025 (assuming strip oil and natural gas pricing as of mid-February 2025). Meanwhile, Matador has in fact reduced\u2014as pledged\u2014its leverage ratio from 1.3x at the time of the Ameredev transaction in September 2024 to 1.05x at December 31, 2024.\n<\/p>\n
2024 Accomplishments and 2023 Comparisons<\/i><\/p>\n\n- \n\u201cIn the fourth quarter of 2024, Matador achieved record quarterly average daily production of 201,116 barrels of oil and natural gas equivalent (\u2018BOE\u2019) per day\u2014the first time in Matador\u2019s history that it has produced an average of over 200,000 BOE per day for an entire quarter. This production level is a 30% increase as compared to average daily production of 154,261 BOE per day in the fourth quarter of 2023 (see Slide B<\/b>).\n<\/li>\n
- \n\u201cMatador also achieved in the fourth quarter of 2024 record quarterly average daily oil production of 118,440 barrels per day (an increase of 34%) and achieved record quarterly average daily natural gas production of 496.1 million cubic feet per day (an increase of 26%), compared to average daily oil production of 88,663 barrels per day and average daily natural gas production of 393.6 million cubic feet per day in the fourth quarter of 2023.\n<\/li>\n
- \n\u201cMatador also produced record annual average daily oil production of 99,808 barrels per day (an increase of 32%) and record annual average daily natural gas production of 425.7 million cubic feet per day (an increase of 26%) in full-year 2024, compared to average daily oil production of 75,457 barrels per day and average daily natural gas production of 338.1 million cubic feet per day in full-year 2023 (see Slide C<\/b>).\n<\/li>\n
- \n\u201cWith the assistance of its vendors, Matador decreased its cost per completed lateral foot by as much as 11% during 2024 to $910 per completed lateral foot from its original expectations of $1,010 per completed lateral foot across its operating areas, primarily as a result of increased operational efficiencies such as \u2018U-Turn\u2019 wells, \u2018simul-frac\u2019 completions and \u2018trimul-frac\u2019 completions rather than forcing price reductions from vendors (see Slide D<\/b> and Slide E<\/b>).\n<\/li>\n
- \n\u201cMatador added nearly 50,000 net acres in 2024 bringing Matador\u2019s total acreage in the Delaware Basin to approximately 200,000 net acres, of which approximately 79% are held by existing production (see Slide F<\/b>). As a result, Matador was able to further high-grade its Delaware Basin inventory to 1,869 net locations with a total net lateral length of approximately 18.3 million feet, or 3,680 miles, as of December 31, 2024, which is an increase of 22% as compared to the total net lateral length of Matador\u2019s inventory of approximately 15.0 million feet, or 2,975 miles, as of December 31, 2023 (see Slide G<\/b>).\n<\/li>\n
- \n\u201cMatador achieved record total proved oil and natural gas reserves of 611.5 million BOE (an increase of 33%), with a standardized measure of $7.4 billion (an increase of 21%) and a PV-10 of $9.2 billion (an increase of 19%) at December 31, 2024, as compared to proved oil and natural gas reserves of 460.1 million BOE with a standardized measure of $6.1 billion and a PV-10 of $7.7 billion at December 31, 2023 (see comparison of commodity prices on Slide H<\/b>).\n<\/li>\n<\/ul>\n
Balance Sheet Strength and Low Leverage<\/i><\/p>\n
\n\u201cMatador finished 2024 in the best financial shape in its history with nearly $1.6 billion in RBL liquidity; just $595.5 million in borrowings under Matador\u2019s reserves-based lending (RBL) credit facility; and a leverage ratio of 1.05x. Current RBL borrowings represent a 38% decrease from $955 million in borrowings under Matador\u2019s reserves-based credit facility and a reduction in Matador\u2019s leverage ratio from 1.3x at September 30, 2024 after Matador closed the Ameredev acquisition to the 1.05x level today (see Slide I<\/b>).\n<\/p>\n
2024 Production and Drilling Results<\/i><\/p>\n
\n\u201cMatador\u2019s fourth quarter 2024 production would have been even higher if it had not experienced significant third-party midstream constraints for two-to-three months in its Antelope Ridge asset area. Matador estimates that these third-party midstream constraints, primarily occurring in Lea County, New Mexico, resulted in approximately 3,000 BOE per day (67% oil) being constrained during the fourth quarter of 2024. Importantly, these midstream constraints were largely resolved by the third-party midstream providers and such production was almost all back online as of February 18, 2025. Fortunately, Matador\u2019s controlled midstream affiliates, San Mateo and Pronto, thankfully experienced 99% uptime during this time for their natural gas processing plants and did not contribute to these constraints.\n<\/p>\n
\n\u201cNotably, Matador continued to advance operational efficiencies to drive production higher and average well costs lower during 2024. In fact, Matador turned to sales a record five new \u2018U-Turn\u2019 wells during the fourth quarter of 2024 (see Slide J<\/b>). Matador estimates that these five U-Turn wells saved drilling days and a total of $15 million, or approximately $3 million for each U-Turn well, as compared to drilling ten vertical wellbores and ten one-mile laterals. Initial results from the five U-Turn wells indicate that these U-Turn wells are performing as good or better than traditional two-mile straight lateral wells in the same area. Capital savings realized by drilling U-Turn wells decrease project payout times and reduce oil breakeven prices by as much as 20% in certain areas. This focus on operational efficiencies and synergies, along with marketing efforts and the quality of its wells, has helped Matador lead its peer group in profitability (see Slide K<\/b> and Slide L<\/b>).\n<\/p>\n
Ameredev Acquisition in September 2024 Contributed to Record Financial Results<\/i><\/p>\n
\n\u201cMatador\u2019s mergers and acquisitions group continues to provide substantial value and Adjusted EBITDA growth for Matador and its shareholders. Matador\u2019s key acquisition of Ameredev Stateline II, LLC (\u2018Ameredev\u2019) in September 2024 added 33,500 net acres, 371 net locations and more than 25,000 BOE per day in production. Each of Matador\u2019s teams has been hard at work successfully integrating the Ameredev properties (see Slide M<\/b>). Matador estimates that it has already experienced at least $4 million in drilling and completion cost synergies and expects additional drilling and completion cost synergies of over $150 million over the next five years. In addition, Matador estimates that it has reduced lease operating expenses on the Ameredev acreage by 35%, or more than $2 million per month, since Matador began operating the Ameredev assets. We look forward to realizing the full value of these efficiencies and synergies over the coming years.\n<\/p>\n
\n\u201cFor full-year 2024, Matador achieved net income of $885.3 million (an increase of 5%) and Adjusted EBITDA of $2.30 billion (an increase of 24%), compared to 2023 net income of $846.1 million and Adjusted EBITDA of $1.85 billion for full-year 2023 (see Slide N<\/b>). Matador\u2019s net cash provided by operating activities was $2.25 billion for full-year 2024, which is a 20% increase from $1.87 billion for full-year 2023. For full-year 2024, Matador\u2019s adjusted free cash flow was $807.3 million, which is a 75% increase from $460.0 million for full-year 2023. Matador exits 2024 as a leader among its peers in free cash flow generation, and Matador is optimistic that it will generate significant free cash flow again in 2025 (see Slide O<\/b>).\n<\/p>\n
2024 Midstream Achievements<\/i><\/p>\n
\n\u201cMatador\u2019s midstream team also made significant strides in 2024. As mentioned above, Matador contributed Pronto to San Mateo in December 2024, including its interest in Pronto\u2019s existing processing plant (the \u2018Marlan Plant\u2019) with a designed inlet capacity of 60 million cubic feet per day of natural gas and the Marlan Plant expansion that adds an additional plant with a designed inlet capacity of 200 million cubic feet of natural gas per day (see Slide P<\/b>). In addition to the financial benefits mentioned above, this transaction also provides increased flow assurance for Matador\u2019s production in Lea County, New Mexico and accelerates filling up the Marlan Plant to capacity. Furthermore, the construction of Pronto\u2019s new Marlan Plant expansion remains on time and on budget and is expected to be online in the second quarter of 2025 (see Slide Q<\/b>).\n<\/p>\n
2025 Outlook: Continued Record Results, Execution and Efficiencies<\/i><\/p>\n
\n\u201cWhile we celebrate our 2024 results and accomplishments, Matador remains focused on its continued growth, profitability and increased efficiencies going forward in 2025. Accordingly, the Matador team fully expects to produce record results again in 2025. Matador aims at increasing its average daily BOE production by 20% to an average of 205,000 BOE per day in full-year 2025, as compared to an average of 170,751 BOE per day in full-year 2024. Matador also expects to increase its yearly oil production by 22% in 2025 with average daily oil production of 122,000 barrels of oil per day in full-year 2025, as compared to an average of 99,808 barrels of oil per day in full-year 2024.\n<\/p>\n
2025 Additional Natural Gas Opportunity<\/i><\/p>\n
\n\u201cMatador produced 496 million cubic feet of natural gas per day in 2024 but Matador\u2019s 2025 plan remains flexible and its undeveloped acreage is sufficiently \u2018gassy\u2019 so that Matador can adjust and produce more natural gas if market conditions warrant a modification. As of December 31, 2024, Matador has 1.5 trillion cubic feet of natural gas reserves, primarily in the Delaware Basin (see Slide H<\/b>).\n<\/p>\n
\n\u201cSignificantly, Matador also retained its operating rights in the Cotton Valley in Northeast Louisiana, which we refer to as our \u2018gas bank\u2019 and is 100% held-by-production (see Slide R<\/b>). As of December 31, 2024, the expected natural gas production from Matador\u2019s Cotton Valley inventory is not included in its reserve report because Matador does not currently plan to drill the Cotton Valley formation in the near future unless natural gas prices improve and stabilize. Nevertheless, Matador\u2019s reservoir engineers consider the Cotton Valley to be a proven formation.\n<\/p>\n
\n\u201cMatador estimates that it has 37 net horizontal locations in the Cotton Valley, which Matador\u2019s reservoir engineers have estimated to be capable of producing up to 200 to 300 billion cubic feet of natural gas. Additionally, Matador anticipates that these operated Cotton Valley locations would have extended lateral lengths of approximately two miles, which would improve costs and provide other efficiencies. Furthermore, this Cotton Valley natural gas would have the benefit of using the same midstream infrastructure that serves the Haynesville Shale, including transportation to many of the Liquified Natural Gas (\u2018LNG\u2019) terminals along the Gulf Coast.\n<\/p>\n
2025 Midstream Opportunities and Flow Assurance<\/i><\/p>\n
\n\u201cMatador is pleased to report its midstream business remains a critical part of its success and is expected to continue providing value to Matador\u2019s shareholders in 2025 (see Slide S<\/b>). All of San Mateo\u2019s three-pipe (oil, water and natural gas) systems work together to build flow assurance for Matador and other customers. Being aligned with Matador provides San Mateo the unique perspective that allows it to provide flow assurance with a producer mindset. This producer mindset has been recognized by San Mateo\u2019s third-party customers as many of these producers are repeat customers and continue to expand their relationship with San Mateo. San Mateo expects to achieve Adjusted EBITDA of $285 million in 2025, which is an increase of 13% as compared to Adjusted EBITDA of $253.2 million in 2024.\n<\/p>\n
\n\u201cFrom an initial start in February 2017, San Mateo has grown to operate approximately 590 miles of oil, natural gas and water pipelines, 520 million cubic feet per day of designed natural gas processing capacity and 16 saltwater disposal wells with approximately 475,000 barrels per day of designed produced water disposal capacity. San Mateo anticipates its processing capacity will increase to 720 million cubic feet per day with the completion of the Marlan Plant expansion early in the second quarter of 2025.\n<\/p>\n
Closing Thoughts<\/i><\/p>\n
\n\u201cWhile each year brings its own challenges, we like our chances and opportunities going forward. In fact, members of Matador\u2019s senior management have made 30 separate purchases of Matador stock since 2021, and none of Matador\u2019s senior management group have ever sold a single Matador share (see Slide T<\/b>). Perhaps even more meaningful as an expression of confidence is the fact that Matador has over 95% participation (including field personnel) in its Employee Stock Purchase Plan (\u2018ESPP\u2019). We also look forward to discussing these results and opportunities and answering your questions at our upcoming conference call tomorrow morning.\u201d\n<\/p>\n
Highlights<\/span><\/b><\/p>\nFourth Quarter 2024 Operational and Financial Highlights
\n
<\/b>(for comparisons to prior year, please see the remainder of this press release)<\/b><\/p>\n\n- \nRecord quarterly average production of 201,116 BOE per day (118,440 barrels of oil per day)\n<\/li>\n
- \nNet cash provided by operating activities of $575.0 million\n<\/li>\n
- \nAdjusted free cash flow of $415.5 million\n<\/li>\n
- \nNet income of $214.5 million, or $1.71 per diluted common share\n<\/li>\n
- \nAdjusted net income of $229.9 million, or $1.83 per diluted common share\n<\/li>\n
- \nAdjusted EBITDA of $640.9 million\n<\/li>\n
- \nSan Mateo net income of $47.8 million\n<\/li>\n
- \nSan Mateo Adjusted EBITDA of $68.5 million\n<\/li>\n<\/ul>\n
Full Year 2024 Operational and Financial Highlights
\n
<\/b>(for comparisons to prior year, please see the remainder of this press release)<\/b><\/p>\n\n- \nRecord annual average production of 170,751 BOE per day (99,808 barrels of oil per day)\n<\/li>\n
- \nNet cash provided by operating activities of $2.25 billion\n<\/li>\n
- \nAdjusted free cash flow of $807.3 million\n<\/li>\n
- \nNet income of $885.3 million, or $7.14 per diluted common share\n<\/li>\n
- \nAdjusted net income of $928.0 million, or $7.48 per diluted common share\n<\/li>\n
- \nAdjusted EBITDA of $2.30 billion\n<\/li>\n
- \nSan Mateo net income of $175.6 million\n<\/li>\n
- \nSan Mateo Adjusted EBITDA of $253.2 million\n<\/li>\n<\/ul>\n
2025 Guidance Highlights<\/b><\/p>\n\n- \nOil production guidance of 120,000 to 124,000 barrels per day\n<\/li>\n
- \nNatural gas production guidance of 492.0 to 504.0 million cubic feet per day\n<\/li>\n
- \nTotal production guidance of 202,000 to 208,000 BOE per day\n<\/li>\n
- \nDrilling, completing and equipping capital expenditures of $1.28 to $1.47 billion\n<\/li>\n
- \nMidstream capital expenditures of $120 to $180 million\n<\/li>\n<\/ul>\n
Note: All references to Matador\u2019s net income, adjusted net income, 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, adjusted net income, Adjusted EBITDA or adjusted free cash flow, respectively, attributable to third-party non-controlling interests, including in San Mateo Midstream, LLC (\u201cSan Mateo\u201d). Matador owns 51% of San Mateo. For a definition of adjusted net income, adjusted earnings per diluted common share, Adjusted EBITDA, adjusted free cash flow and PV-10 and reconciliations of such non-GAAP financial metrics to their comparable GAAP metrics, please see \u201cSupplemental Non-GAAP Financial Measures\u201d below.<\/i><\/p>\n
Operational and Financial Update<\/b><\/p>\n
Record Fourth Quarter 2024 Oil, Natural Gas and Total Oil Equivalent Production<\/i><\/p>\n
\nMatador\u2019s average daily oil and natural gas production was 201,116 BOE per day in the fourth quarter of 2024, which was the highest in Matador\u2019s history as noted above and was a 2% increase as compared to the midpoint of Matador\u2019s expected fourth quarter production guidance of 198,000 BOE per day. The primary drivers behind this outperformance were (i) increased production from new wells turned to sales in the third quarter of 2024 in Matador\u2019s Rustler Breaks and Ranger asset areas and (ii) higher-than-expected production from non-operated assets. Production from the newly acquired Ameredev properties was 23,200 BOE per day, which was better than Matador\u2019s initial expectations despite additional shut-in volumes from accelerated offset completions.\n<\/p>\n
\n\n| \n \nProduction\n<\/p>\n<\/td>\n | \n \nQ4 2024
\n
Average Daily
\n
Volume\n<\/p>\n<\/td>\n | \n \nQ4 2024
\n
Guidance
\n
Range (1)<\/sup><\/p>\n<\/td>\n\n \nDifference (2)<\/sup><\/p>\n<\/td>\n| \n \nSequential (3)<\/sup><\/p>\n<\/td>\n| \n \nYoY (4)<\/sup><\/p>\n<\/td>\n<\/tr>\n\n| \n \nTotal, BOE per day\n<\/p>\n<\/td>\n | \n \n201,116\n<\/p>\n<\/td>\n | \n \n197,000 to 199,000\n<\/p>\n<\/td>\n | \n \n+2% Better than Guidance\n<\/p>\n<\/td>\n | \n \n+17%\n<\/p>\n<\/td>\n | \n \n+30%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil, Bbl per day\n<\/p>\n<\/td>\n | \n \n118,440\n<\/p>\n<\/td>\n | \n \n118,500 to 119,500\n<\/p>\n<\/td>\n | \n \n<-1% Less than Guidance\n<\/p>\n<\/td>\n | \n \n+18%\n<\/p>\n<\/td>\n | \n \n+34%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural Gas, MMcf per day\n<\/p>\n<\/td>\n | \n \n496.1\n<\/p>\n<\/td>\n | \n \n472.0 to 476.0\n<\/p>\n<\/td>\n | \n \n+5% Better than Guidance\n<\/p>\n<\/td>\n | \n \n+16%\n<\/p>\n<\/td>\n | \n \n+26%\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \n\n| \n \n(1) Production range previously projected, as provided on October 22, 2024.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(2) As compared to midpoint of guidance provided on October 22, 2024.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(3) Represents sequential percentage change from the third quarter of 2024.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(4) Represents year-over-year percentage change from the fourth quarter of 2023.\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n Fourth Quarter 2024 Realized Commodity Prices<\/i><\/p>\n \nThe following table summarizes Matador\u2019s realized commodity prices during the fourth quarter of 2024, as compared to the third quarter of 2024 and the fourth quarter of 2023.\n<\/p>\n \n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nSequential (Q4 2024 vs. Q3 2024)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nYoY (Q4 2024 vs. Q4 2023)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nRealized Commodity Prices\n<\/p>\n<\/td>\n | \n \nQ4 2024\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nQ3 2024\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nSequential
\n
Change(1)<\/sup><\/p>\n<\/td>\n\n \n\u00a0\n<\/p>\n<\/td>\n | \n \nQ4 2024\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nQ4 2023\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nYoY
\n
Change(2)<\/sup><\/p>\n<\/td>\n<\/tr>\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil Prices, per Bbl\n<\/p>\n<\/td>\n | \n \n$70.66\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$75.67\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nDown 7%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$70.66\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$79.00\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nDown 11%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural Gas Prices, per Mcf\n<\/p>\n<\/td>\n | \n \n$2.72\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$1.83\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nUp 49%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$2.72\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$3.01\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nDown 10%\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \n\n| \n \n(1) Fourth quarter 2024 as compared to third quarter 2024.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(2) Fourth quarter 2024 as compared to fourth quarter 2023.\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n Fourth Quarter 2024 Operating Expenses<\/i><\/p>\n \nMatador expected increased lease operating expenses in the fourth quarter of 2024 as a result of closing the Ameredev acquisition in September 2024 and continued integration of the acquired assets. However, Matador was able to offset certain of these anticipated expense increases through savings from a range of improvements relating to the wells acquired in the Ameredev transaction, including field supervision expenses, chemical usage and reduction in produced water disposal costs. Notably, in the fourth quarter of 2024, Matador recycled approximately 1.2 million barrels of water during fracturing operations on the 11 new Firethorn and Pimento wells that were acquired as part of the Ameredev acquisition. These actions to offset the expected increase in lease operating expenses resulted in total lease operating expenses of $5.37 per BOE for the fourth quarter of 2024, which is a 2% sequential decrease from $5.50 per BOE in the third quarter of 2024, and an 11% improvement from the midpoint of Matador\u2019s expected fourth quarter 2024 guidance range of $5.75 to $6.25 per BOE.\n<\/p>\n \nMatador\u2019s general and administrative (\u201cG&A\u201d) expenses increased 22% sequentially from $1.82 per BOE in the third quarter of 2024 to $2.22 per BOE in the fourth quarter of 2024. This increase is due in part to the value of employee stock awards that are settled in cash, which are remeasured at each quarterly reporting period according to accounting rules. These cash-settled stock award amounts increased as Matador\u2019s share price increased 14% from $49.42 at the end of the third quarter of 2024 to $56.26 at end of the fourth quarter of 2024. Matador\u2019s full year 2024 G&A expenses decreased 11% from $2.29 per BOE in 2023 to $2.04 per BOE in 2024.\n<\/p>\n \nDuring the fourth quarter of 2024, Matador\u2019s plant and other midstream services operating expenses, which include the costs to operate San Mateo\u2019s and Pronto\u2019s assets, were $2.75 per BOE, consistent with $2.77 per BOE in the third quarter of 2024. The fourth quarter 2024 plant and other midstream services operating expenses were also consistent with Matador\u2019s expected fourth quarter 2024 range of $2.50 to $3.00 per BOE.\n<\/p>\n Fourth Quarter 2024 Capital Expenditures<\/i><\/p>\n \nFor the fourth quarter of 2024, Matador\u2019s capital expenditures for drilling, completing and equipping wells (\u201cD\/C\/E capital expenditures\u201d) were $325.5 million and midstream capital expenditures were $65.2 million. D\/C\/E capital expenditures during the fourth quarter of 2024 were higher than expected, but full-year 2024 D\/C\/E capital expenditures of $1.32 billion were within Matador\u2019s expected range of $1.15 billion to $1.35 billion. D\/C\/E capital expenditures during the fourth quarter of 2024 were higher than expected due to costs associated with the acceleration of capital expenditures for certain non-operated properties and facility upgrades related to the Ameredev properties. These Ameredev facility upgrades contributed to the lower-than-expected lease operating expenses noted above.\n<\/p>\n \nMidstream capital expenditures during the fourth quarter of 2024 were higher than expected due to acceleration of costs associated with the Marlan Plant expansion, but full-year 2024 midstream capital expenditures of $238.7 million were still within Matador\u2019s expected annual range of $200 million to $250 million. The midstream capital expenditures during the fourth quarter of 2024 included payments related to the expansion of the Marlan Plant until the closing of the Pronto Transaction on December 18, 2024.\n<\/p>\n Midstream Update<\/b><\/p>\n \nSan Mateo\u2019s operations in the fourth quarter of 2024 were highlighted by record operating and financial results. San Mateo\u2019s natural gas gathering and oil gathering and transportation volumes in the fourth quarter of 2024 were all-time quarterly highs. The table below sets forth San Mateo\u2019s throughput volumes, as compared to the third quarter of 2024 and the fourth quarter of 2023. Because the Pronto Transaction closed in mid-December 2024, it did not significantly contribute to San Mateo\u2019s financial results in the fourth quarter of 2024.\n<\/p>\n \n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nSequential (Q4 2024 vs. Q3 2024)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nYoY (Q4 2024 vs. Q4 2023)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nSan Mateo Throughput Volumes\n<\/p>\n<\/td>\n | \n \nQ4 2024\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nQ3 2024\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nChange(1)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nQ4 2024\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nQ4 2023\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nChange(2)<\/sup><\/p>\n<\/td>\n<\/tr>\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural gas gathering, MMcf per day\n<\/p>\n<\/td>\n | \n \n454\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n431\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+5%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n454\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n416\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+9%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural gas processing, MMcf per day\n<\/p>\n<\/td>\n | \n \n434\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n424\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+2%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n434\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n413\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+5%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil gathering and transportation, Bbl per day\n<\/p>\n<\/td>\n | \n \n63,000\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n52,300\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+20%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n63,000\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n50,900\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+24%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nProduced water handling, Bbl per day\n<\/p>\n<\/td>\n | \n \n470,100\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n513,200\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n-8%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n470,100\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n442,000\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+6%\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \n\n| \n \n(1) Fourth quarter 2024 as compared to third quarter 2024.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(2) Fourth quarter 2024 as compared to fourth quarter 2023.\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n Proved Reserves, Standardized Measure and PV-10<\/b><\/p>\n \nThe following table summarizes Matador\u2019s estimated total proved oil and natural gas reserves at December 31, 2024 and 2023.\n<\/p>\n \n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n At December 31,<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n % YoY Change<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2024<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2023<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nEstimated proved reserves:(1)(2)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil (MBbl)(3)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n361,842\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n272,277\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+33%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural Gas (Bcf)(4)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n1,498.2\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n1,126.8\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+33%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal (MBOE)(5)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n611,536\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n460,070\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+33%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nEstimated proved developed reserves:\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil (MBbl)(3)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n206,269\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n161,642\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+28%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural Gas (Bcf)(4)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n963.2\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n782.7\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+23%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal (MBOE)(5)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n366,797\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n292,097\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+26%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nPercent developed\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n60.0\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n63.5\n<\/p>\n<\/td>\n | \n \n%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nEstimated proved undeveloped reserves:\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil (MBbl)(3)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n155,573\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n110,635\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+41%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural Gas (Bcf)(4)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n535.0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n344.0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+56%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal (MBOE)(5)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n244,740\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n167,973\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+46%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nStandardized Measure (in millions)(6)<\/sup><\/p>\n<\/td>\n| \n \n$\n<\/p>\n<\/td>\n | \n \n7,376.6\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n6,113.5\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+21%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nPV-10 (in millions)(7)<\/sup><\/p>\n<\/td>\n| \n \n$\n<\/p>\n<\/td>\n | \n \n9,233.8\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n7,704.1\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n+20%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nCommodity prices:(2)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil (per Bbl)\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n71.96\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n74.70\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(4)%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural Gas (per MMBtu)\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2.13\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2.64\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n(19)%\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \n\n| \n \n(1) Numbers in table may not total due to rounding.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(2) Matador\u2019s estimated proved reserves, Standardized Measure and PV-10 were determined using index prices for oil and natural gas, without giving effect to derivative transactions, and were held constant throughout the life of the properties. The unweighted arithmetic averages of first-day-of-the-month prices for the period from January through December 2024 were $71.96 per Bbl for oil and $2.13 per MMBtu for natural gas and for the period from January through December 2023 were $74.70 per Bbl for oil and $2.64 per MMBtu for natural gas. These prices were adjusted by property for quality, energy content, regional price differentials, transportation fees, marketing deductions and other factors affecting the price received at the wellhead. Matador reports its proved reserves in two streams, oil and natural gas, and the economic value of the natural gas liquids (\u201cNGL\u201d) associated with the natural gas is included in the estimated wellhead price on those properties where NGLs are extracted and sold.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(3) One thousand barrels of oil.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(4) One billion cubic feet of natural gas.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(5) One thousand barrels of oil equivalent, estimated using a conversion factor of one barrel of oil per six thousand standard cubic feet of natural gas.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(6) Standardized Measure represents the present value of estimated future net cash flows from proved reserves, less estimated future development, production, plugging and abandonment and income tax expenses, discounted at 10% per annum to reflect the timing of future cash flows. Standardized Measure is not an estimate of the fair market value of Matador\u2019s properties.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(7) PV-10 is a non-GAAP financial measure. For a reconciliation of PV-10 (non-GAAP) to Standardized Measure (GAAP), please see \u201cSupplemental Non-GAAP Financial Measures.\u201d PV-10 is not an estimate of the fair market value of our properties.\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \nThe proved reserves estimates presented for each period in the table above were prepared by the Company\u2019s internal engineering staff and audited by an independent reservoir engineering firm, Netherland, Sewell & Associates, Inc. These proved reserves estimates were prepared in accordance with the SEC\u2019s rules for oil and natural gas reserves reporting and do not include any unproved reserves classified as probable or possible that might exist on Matador\u2019s properties.\n<\/p>\n \nMatador\u2019s total proved oil and natural gas reserves increased 33% year-over-year from 460.1 million BOE (59% oil, 64% proved developed, 97% Delaware Basin), consisting of 272.3 million barrels of oil and 1.13 trillion cubic feet of natural gas, at December 31, 2023 to 611.5 million BOE (59% oil, 60% proved developed, 99% Delaware Basin), consisting of 361.8 million barrels of oil and 1.50 trillion cubic feet of natural gas, at December 31, 2024. Matador\u2019s total proved oil and natural gas reserves at December 31, 2024 were an all-time high.\n<\/p>\n \nThe Standardized Measure of Matador\u2019s total proved oil and natural gas reserves increased 21% from $6.11 billion at December 31, 2023 to $7.38 billion at December 31, 2024. The PV-10 (a non-GAAP financial measure) of Matador\u2019s total proved oil and natural gas reserves increased 20% from $7.70 billion at December 31, 2023 to $9.23 billion at December 31, 2024. The increase in both Standardized Measure and PV-10 of Matador\u2019s proved oil and natural gas reserves at December 31, 2024 resulted primarily from the ongoing development and delineation of Matador\u2019s Delaware Basin properties and the Ameredev acquisition, partially offset by a decrease in both oil and natural gas prices used to estimate proved reserves at December 31, 2024, as compared to December 31, 2023. At December 31, 2024, the oil and natural gas prices used to estimate total proved reserves were $71.96 per barrel (a 4% decrease) and $2.13 per MMBtu (a 19% decrease), respectively, as compared to $74.70 per barrel and $2.64 per MMBtu, respectively, at December 31, 2023.\n<\/p>\n Full Year 2025 Guidance Summary<\/b><\/p>\n \nMatador\u2019s full year 2025 guidance estimates are summarized in the table below, as compared to the actual results for 2024.\n<\/p>\n \n\n| \n \nGuidance Metric\n<\/p>\n<\/td>\n | \n \nActual\n<\/p>\n \n2024 Results\n<\/p>\n<\/td>\n | \n \n2025 Guidance Range\n<\/p>\n<\/td>\n | \n \n% YoY\n<\/p>\n \nChange(1)<\/sup><\/p>\n<\/td>\n<\/tr>\n\n| \n \nOil Production\n<\/p>\n<\/td>\n | \n \n99,808 Bbl\/d(2)<\/sup><\/p>\n<\/td>\n| \n \n120,000 to 124,000 Bbl\/d\n<\/p>\n<\/td>\n | \n \n+22%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural Gas Production\n<\/p>\n<\/td>\n | \n \n425.7 MMcf\/d(3)<\/sup><\/p>\n<\/td>\n| \n \n492.0 to 504.0 MMcf\/d\n<\/p>\n<\/td>\n | \n \n+17%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil Equivalent Production\n<\/p>\n<\/td>\n | \n \n170,751 BOE\/d(4)<\/sup><\/p>\n<\/td>\n| \n \n202,000 to 208,000 BOE\/d\n<\/p>\n<\/td>\n | \n \n+20%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nD\/C\/E CapEx(5)<\/sup><\/p>\n<\/td>\n| \n \n$1.32 billion\n<\/p>\n<\/td>\n | \n \n$1.28 to $1.47 billion\n<\/p>\n<\/td>\n | \n \n+4%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nMidstream CapEx(6)<\/sup><\/p>\n<\/td>\n| \n \n$238.7 million\n<\/p>\n<\/td>\n | \n \n$120 to $180 million\n<\/p>\n<\/td>\n | \n \n(37) %\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal D\/C\/E and Midstream CapEx\n<\/p>\n<\/td>\n | \n \n$1.56 billion\n<\/p>\n<\/td>\n | \n \n$1.40 to $1.65 billion\n<\/p>\n<\/td>\n | \n \n(2) %\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \n\n| \n \n(1) Represents percentage change from 2024 actual results to the midpoint of 2025 guidance range.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(2) One barrel of oil per day.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(3) One million cubic feet of natural gas per day.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(4) One barrel of oil equivalent per day, estimated using a conversion factor of one barrel of oil per six thousand standard cubic feet of natural gas.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(5) Capital expenditures associated with drilling, completing and equipping wells.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(6) Includes Matador\u2019s share of estimated capital expenditures for San Mateo and other wholly-owned midstream projects. Pronto was wholly-owned by Matador until December 18, 2024, the date Pronto was contributed to San Mateo in the Pronto Transaction. Excludes the acquisition cost of Ameredev\u2019s midstream assets in 2024.\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \nThe full year 2025 guidance estimates presented in the table above are based upon the following key assumptions for 2025 drilling and completions activity and capital expenditures.\n<\/p>\n \n- \nMatador began 2024 operating seven drilling rigs in the Delaware Basin and added an eighth operated drilling rig in late January 2024 and a ninth operated drilling rig in the middle of 2024. The 2% decrease in total capital expenditures from $1.56 billion in 2024 to $1.53 billion in 2025 is the result of (i) a 37% decrease in midstream capital expenditures, as a majority of the costs related to the Marlan Plant expansion were incurred in 2024, which is partially offset by (ii) a 4% increase in D\/C\/E capital expenditures due to operating nine drilling rigs for full-year 2025 and the anticipated mix of wells that will be turned to sales in 2025, as compared to 2024.\n<\/li>\n
- \nMatador estimates its 2025 D\/C\/E capital expenditures will be $1.28 to $1.47 billion, as further detailed in the table below.\n<\/li>\n<\/ul>\n
\n\n| \n \n\u00a0\n<\/p>\n \nD\/C\/E CapEx(1)<\/sup> Components\n<\/p>\n<\/td>\n| \n \nActual\n<\/p>\n \n2024 Results\n<\/p>\n<\/td>\n | \n \n2025 CapEx Estimates\n<\/p>\n<\/td>\n | \n \n% YoY\n<\/p>\n \nChange(2)<\/sup><\/p>\n<\/td>\n<\/tr>\n\n| \n \nOperated(3)<\/sup><\/p>\n<\/td>\n| \n \n$1.19 billion\n<\/p>\n<\/td>\n | \n \n$1.16 to $1.32 billion\n<\/p>\n<\/td>\n | \n \n+4%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNon-Operated\n<\/p>\n<\/td>\n | \n \n$81 million\n<\/p>\n<\/td>\n | \n \n$70 to $90 million\n<\/p>\n<\/td>\n | \n \n-1%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nCapitalized G&A and Interest\n<\/p>\n<\/td>\n | \n \n$45 million\n<\/p>\n<\/td>\n | \n \n$50 to $60 million\n<\/p>\n<\/td>\n | \n \n+22%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n Total D\/C\/E CapEx<\/b><\/p>\n<\/td>\n | \n $1.32 billion<\/b><\/p>\n<\/td>\n | \n $1.28 to $1.47 billion<\/b><\/p>\n<\/td>\n | \n +4%<\/b><\/p>\n<\/td>\n<\/tr>\n<\/table>\n\n\n| \n \n(1) Capital expenditures associated with drilling, completing and equipping wells.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(2) Represents percentage change from 2024 actual results to the midpoint of 2025 guidance range.\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \n(3) Includes $60 to $70 million of artificial lift and other production-related capital expenditures estimated in 2025.\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \n- \nMatador anticipates full-year 2025 drilling and completion costs per completed lateral foot to average between $865 to $895 per completed lateral foot, or a 3% decrease at the midpoint of the 2025 range as compared to $910 in 2024. As it has done in the past, Matador expects to continue to seek to maximize and increase its capital efficiencies across all operations. Matador anticipates \u201cSimul-Frac\u201d and \u201cTrimul-Frac\u201d operations to account for over 80% of completions in 2025 with Trimul-Frac alone accounting for approximately 35% of anticipated 2025 completions, as compared to 15% in 2024. Notably, Matador expects that improved water and sand logistics, casing design optimization, MaxCom well targeting, use of existing infrastructure and increased operating efficiency should reduce drilling and completion days on wells.\n<\/li>\n
- \nMatador estimates 2025 midstream capital expenditures of $120 to $180 million. This estimate includes (i) $90 to $130 million for Matador\u2019s 51% share of San Mateo\u2019s 2025 estimated capital expenditures of approximately $176 to $255 million and (ii) $30 to $50 million for other wholly-owned midstream projects, including expansion of the 180 mile gas gathering, water gathering and oil transportation and gathering pipeline system that Matador acquired in connection with the Ameredev acquisition. San Mateo\u2019s 2025 capital expenditures include finishing the Marlan Plant expansion as well as the pipelines and related infrastructure required to connect San Mateo\u2019s three-stream pipeline system to Matador and third-party customers.\n<\/li>\n<\/ul>\n
2025 Production Estimates and Cadence<\/b><\/p>\n Oil, Natural Gas and Oil Equivalent Production Growth and Anticipated Cadence<\/span><\/p>\n\nMatador expects full-year 2025 production of 120,000 to 124,000 barrels of oil per day and 492 to 504 million cubic feet of natural gas per day, resulting in 202,000 to 208,000 BOE per day, which would be an increase of 20% as compared to our record 2024 production of 170,751 BOE per day (99,808 barrels of oil per day). The cadence of production is expected to be lumpy throughout 2025, primarily due to completion timing and larger, more capital efficient batches. As detailed further below, Matador expects significant sequential increases in the second and fourth quarters of 2025 while experiencing modest sequential decreases in the first and third quarters of 2025.\n<\/p>\n First Quarter 2025 Estimated Oil, Natural Gas and Total Oil Equivalent Production<\/i><\/p>\n \nAs noted in the table below, Matador anticipates its average daily oil equivalent production of 201,116 BOE per day in the fourth quarter of 2024 to decrease to a midpoint of approximately 196,000 BOE per day in the first quarter of 2025 before increasing to new production records again in the second quarter of 2025.\n<\/p>\n \n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \nQ4 2024 and Q1 2025 Production Comparison\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nPeriod\n<\/p>\n<\/td>\n | \n \nAverage Daily
\n
Total Production,
\n
BOE per day\n<\/p>\n<\/td>\n | \n \nAverage Daily
\n
Oil Production,
\n
Bbl per day\n<\/p>\n<\/td>\n | \n \nAverage Daily
\n
Natural Gas Production,
\n
MMcf per day\n<\/p>\n<\/td>\n | \n \n% Oil\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nQ4 2024\n<\/p>\n<\/td>\n | \n \n201,116\n<\/p>\n<\/td>\n | \n \n118,440\n<\/p>\n<\/td>\n | \n \n496.1\n<\/p>\n<\/td>\n | \n \n59%\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nQ1 2025E\n<\/p>\n<\/td>\n | \n \n195,000 to 197,000\n<\/p>\n<\/td>\n | \n \n114,000 to 115,000\n<\/p>\n<\/td>\n | \n \n486.0 to 492.0\n<\/p>\n<\/td>\n | \n \n59%\n<\/p>\n<\/td>\n<\/tr>\n<\/table>\n \nThe decline in production from the fourth quarter of 2024 to the first quarter of 2025 is due to the lumpiness of production as a result of the timing of wells being turned to sales. Matador expects to turn to sales between 35 and 40 operated wells during the first quarter of 2025, of which only two operated wells had been turned to sales in the first half of the quarter. The remaining 33 to 38 wells are expected to be turned to sales in the latter half of the first quarter of 2025, which will primarily contribute to production beginning in the second quarter of 2025. Among the wells expected to be turned to sales in the first quarter of 2025 are the first three-mile lateral wells drilled by Matador.\n<\/p>\n First Quarter 2025 Estimated Capital Expenditures<\/i><\/p>\n \nAt February 18, 2025, Matador expects D\/C\/E capital expenditures for the first quarter of 2025 will be approximately $340 to $400 million, which is a 14% increase as compared to $325 million for the fourth quarter of 2024, primarily due to an increased number of completions and increased non-operated capital expenditures. Matador expects its proportionate share of midstream capital expenditures to be approximately $65 to $95 million in the first quarter of 2025, as compared to $65.2 million in the fourth quarter of 2024. Midstream capital expenditures are expected to be higher in the first quarter of 2025 as compared to the remainder of 2025 primarily due to costs associated with the completion of the Marlan Plant expansion.\n<\/p>\n 2025 Estimated Cash Taxes<\/i><\/p>\n \nMatador expects to make cash tax payments of approximately 5 to 10% of pre-tax book net income for the year ended December 31, 2025 at current commodity prices, as compared to cash tax payments of approximately 2% of pre-tax book net income for the year ended December 31, 2024. The Company\u2019s cash tax payments will be dependent upon a variety of factors that will impact taxable income, including oil and natural gas prices, allowable deductions and any legislative changes thereon, and any tax credits generated that would offset tax liabilities in 2025.\n<\/p>\n Conference Call Information<\/b><\/p>\n \nThe Company will host a live conference call on Wednesday, February 19, 2025, at 9:00 a.m. Central Time to discuss its fourth quarter and full year 2024 financial and operational results, as well as its 2025 operating plan and market guidance. To access the live conference call by phone, you can use the following link https:\/\/register.vevent.com\/register\/BIa2657091ad6f4bdc9092002a18d1e2dc<\/a> and you will be provided with dial in details. To avoid delays, it is recommended that participants dial into the conference call 15 minutes ahead of the scheduled start time.\n<\/p>\n\nThe live conference call will also be available through the Company\u2019s website at www.matadorresources.com<\/a> on the Events and Presentations page under the Investor Relations tab. The replay for the event will be available on the Company\u2019s website at www.matadorresources.com<\/a> on the Events and Presentations page under the Investor Relations tab for one year.\n<\/p>\nAbout Matador Resources Company<\/b><\/p>\n \nMatador 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 in support of its exploration, development and production operations and provides natural gas processing, oil transportation services, oil, natural gas and produced water gathering services and produced water disposal services to third parties.\n<\/p>\n \nFor more information, visit Matador Resources Company at www.matadorresources.com<\/a>.\n<\/p>\nForward-Looking Statements<\/b><\/p>\n \nThis press release includes \u201cforward-looking statements\u201d 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. \u201cForward-looking statements\u201d 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 \u201ccould,\u201d \u201cbelieve,\u201d \u201cwould,\u201d \u201canticipate,\u201d \u201cintend,\u201d \u201cestimate,\u201d \u201cexpect,\u201d \u201cmay,\u201d \u201cshould,\u201d \u201ccontinue,\u201d \u201cplan,\u201d \u201cpredict,\u201d \u201cpotential,\u201d \u201cproject,\u201d \u201chypothetical,\u201d \u201cforecasted\u201d 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\u2019s 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; the operating results of the Company\u2019s midstream oil, natural gas and water gathering and transportation systems, pipelines and facilities, the acquiring of third-party business and the drilling of any additional salt water disposal wells; costs of operations; delays and other difficulties related to producing oil, natural gas and natural gas liquids; delays and other difficulties related to regulatory and governmental approvals and restrictions; impact on the Company\u2019s operations due to seismic events; its ability to make acquisitions on economically acceptable terms; its ability to integrate acquisitions; disruption from the Company\u2019s acquisitions making it more difficult to maintain business and operational relationships; significant transaction costs associated with the Company\u2019s acquisitions; the risk of litigation and\/or regulatory actions related to the Company\u2019s acquisitions; availability of sufficient capital to execute its business plan, including from future cash flows, capital markets, available borrowing capacity under its revolving credit facilities and otherwise; the operating results of and the availability of any potential distributions from our joint ventures; weather and environmental conditions; and the other factors that could cause actual results to differ materially from those anticipated or implied in the forward-looking statements. For further discussions of risks and uncertainties, you should refer to Matador\u2019s filings with the SEC, including the \u201cRisk Factors\u201d section of Matador\u2019s 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.\n<\/p>\n \nSequential and year-over-year quarterly comparisons of selected financial and operating items are shown in the following table:\n<\/p>\n \n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n Three Months Ended<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n December 31,<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n September 30,<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n December 31,<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2024<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2024<\/b><\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n 2023<\/b><\/p>\n<\/td>\n<\/tr>\n\n| \n \nNet Production Volumes:(1)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil (MBbl)(2)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n10,896\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n9,229\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n8,157\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural gas (Bcf)(3)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n45.6\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n39.3\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n36.2\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal oil equivalent (MBOE)(4)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n18,503\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n15,776\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n14,192\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nAverage Daily Production Volumes:(1)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil (Bbl\/d)(5)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n118,440\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n100,315\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n88,663\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural gas (MMcf\/d)(6)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n496.1\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n427.0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n393.6\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal oil equivalent (BOE\/d)(7)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n201,116\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n171,480\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n154,261\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nAverage Sales Prices:\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil, without realized derivatives (per Bbl)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n70.66\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n75.67\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n79.00\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil, with realized derivatives (per Bbl)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n70.66\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n75.67\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n79.00\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural gas, without realized derivatives (per Mcf)(8)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2.72\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n1.83\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n3.01\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNatural gas, with realized derivatives (per Mcf)\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2.81\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n1.94\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2.92\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nRevenues (millions):\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOil and natural gas revenues\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n893.9\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n770.2\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n753.2\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nThird-party midstream services revenues\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n37.7\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n38.3\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n35.6\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nRealized gain (loss) on derivatives\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n4.2\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n4.5\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n(3.1\n<\/p>\n<\/td>\n | \n \n)\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOperating Expenses (per BOE):\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nProduction taxes, transportation and processing\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n4.70\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n4.61\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n5.31\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nLease operating\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n5.37\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n5.50\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n5.06\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nPlant and other midstream services operating\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2.75\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2.77\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2.56\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nDepletion, depreciation and amortization\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n15.85\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n15.39\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n15.51\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nGeneral and administrative(9)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2.22\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n1.82\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n2.08\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nTotal(10)<\/sup><\/p>\n<\/td>\n| \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n30.89\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n30.09\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n$\n<\/p>\n<\/td>\n | \n \n30.52\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nOther (millions):\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n | \n \n\u00a0\n<\/p>\n<\/td>\n<\/tr>\n | \n| \n \nNet sales of purchased natural gas | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |