2018 IPAA OGIS New York Matthew V. Hairford, President April 9, - - PowerPoint PPT Presentation
2018 IPAA OGIS New York Matthew V. Hairford, President April 9, - - PowerPoint PPT Presentation
2018 IPAA OGIS New York Matthew V. Hairford, President April 9, 2018 NYSE: MTDR Disclosure Statements Safe Harbor Statement This presentation and statements made by representatives of Matador Resources Company (Matador or the
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Disclosure Statements
Safe Harbor Statement – This presentation and statements made by representatives of Matador Resources Company (“Matador” or the “Company”) during the course of this presentation include “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, results in certain basins, objectives, project timing, expectations and intentions 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 Matador’s financial and operational performance: general economic conditions; Matador’s ability to execute its business plan, including whether Matador’s 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; Matador’s 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; Matador’s ability to replace reserves and efficiently develop its current reserves; Matador’s ability to make acquisitions on economically acceptable terms; Matador’s ability to integrate acquisitions; availability of sufficient capital to execute Matador’s business plan, including from its future cash flows, increases in Matador’s borrowing base and otherwise; weather and environmental conditions; the ability of the Company’s midstream joint venture to expand the Black River cryogenic processing plant, the timing of such expansion and the operating results thereof; the timing and
- perating 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 salt 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 (the “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 and does not intend to update these forward-looking statements to reflect events or circumstances occurring after the date of this presentation, 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 presentation. All forward-looking statements are qualified in their entirety by this cautionary statement. Cautionary Note – The SEC permits oil and gas companies, in their filings with the SEC, to disclose only proved, probable and possible reserves. Potential resources are not proved, probable or possible reserves. The SEC’s guidelines prohibit Matador from including such information in filings with the SEC. Definitions – Proved oil and natural gas reserves are the estimated quantities of oil and natural gas that geological and engineering data demonstrate with reasonable certainty to be recoverable in future years from known reservoirs under existing economic and operating conditions. Matador’s production and proved reserves are reported in two streams: oil and natural gas, including both dry and liquids-rich natural gas. Where Matador produces liquids-rich natural gas, the economic value of the natural gas liquids associated with the natural gas is included in the estimated wellhead natural gas price on those properties where the natural gas liquids are extracted and sold. Estimated ultimate recovery (EUR) is a measure that by its nature is more speculative than estimates of proved reserves prepared in accordance with SEC definitions and guidelines and is accordingly less certain. Type curves shown in this presentation are used to compare actual well performance to a range of potential production results calculated without regard to economic conditions; actual recoveries may vary from these type curves based on individual well performance and economic conditions.
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Selected Financial Measures
Matador Resources Company
(In thousands) 1Q 2011 2Q 2011 3Q 2011 4Q 2011 1Q 2012 2Q 2012 3Q 2012 4Q 2012 Net (loss) income attributable to Matador Resources Company Shareholders $ (27,596) $ 7,153 $ 6,194 $ 3,941 $ 3,801 $ (6,676) $ (9,197) $ (21,188) Net cash provided by operating activities $ 12,732 $ 6,799 $ 14,912 $ 27,425 $ 5,110 $ 46,416 $ 28,799 $ 43,903 Adjusted EBITDA attributable to Matador Resources Company shareholders $ 10,148 $ 15,324 $ 12,078 $ 12,361 $ 21,338 $ 27,926 $ 28,631 $ 38,029 (In thousands) 1Q 2013 2Q 2013 3Q 2013 4Q 2013 1Q 2014 2Q 2014 3Q 2014 4Q 2014 Net (loss) income attributable to Matador Resources Company Shareholders $ (15,505) $ 25,119 $ 20,105 $ 15,374 $ 16,363 $ 18,226 $ 29,619 $ 46,563 Net cash provided by operating activities $ 32,229 $ 51,684 $ 43,280 $ 52,278 $ 31,945 $ 81,530 $ 66,883 $ 71,123 Adjusted EBITDA attributable to Matador Resources Company shareholders $ 40,672 $ 40,772 $ 61,485 $ 48,840 $ 56,345 $ 69,464 $ 66,814 $ 70,320 (In thousands) 1Q 2015 2Q 2015 3Q 2015 4Q 2015 1Q 2016 2Q 2016 3Q 2016 4Q 2016 Net (loss) income attributable to Matador Resources Company Shareholders $ (50,234) $ (157,091) $ (242,059) $ (230,401) $ (107,654) $ (105,853) $ 11,931 $ 104,154 Net cash provided by operating activities $ 93,346 $ 20,043 $ 72,535 $ 22,611 $ 18,358 $ 31,242 $ 46,862 $ 37,624 Adjusted EBITDA attributable to Matador Resources Company shareholders $ 50,144 $ 66,675 $ 58,023 $ 48,293 $ 17,200 $ 38,946 $ 47,260 $ 54,486 (In thousands) 1Q 2017 2Q 2017 3Q 2017 4Q 2017 Net (loss) income attributable to Matador Resources Company Shareholders $ 43,984 $ 28,509 $ 15,039 $ 38,335 Net cash provided by operating activities $ 61,309 $ 59,933 $ 101,274 $ 76,609 Adjusted EBITDA attributable to Matador Resources Company shareholders $ 69,959 $ 72,652 $ 84,833 $ 108,619 (In thousands) 2008 2009 2010 2011 2012 2013 2014 2015 Net (loss) income attributable to Matador Resources Company Shareholders $103,878 ($14,425) $6,377 ($10,309) ($33,261) $45,094 $110,771 ($679,785) Net cash provided by operating activities $25,851 $1,791 $27,273 $61,868 $124,228 $179,470 $251,481 $208,535 Adjusted EBITDA attributable to Matador Resources Company shareholders $18,411 $15,184 $23,635 $49,911 $115,923 $191,771 $262,926 $223,138 (In thousands) 2016 2017 Net (loss) income attributable to Matador Resources Company Shareholders ($97,421) $125,867 Net cash provided by operating activities $134,086 $299,125 Adjusted EBITDA attributable to Matador Resources Company shareholders $157,892 $336,063 Year Ended December 31, Year Ended December 31,
San Mateo Midstream, LLC
Year Ended December 31, (In thousands) 2015 2016 2017 Unaudited Adjusted EBITDA reconciliation to Net Income (Loss): Net income $2,719 $10,174 $26,391 Total income tax provision 647 97 269 Depletion, depreciation and amortization 562 1,739 4,231 Accretion of asset retirement obligations 16 47 30 Adjusted EBITDA (Non-GAAP) $3,944 $12,057 $30,921 Year Ended December 31, (In thousands) 2015 2016 2017 Unaudited Adjusted EBITDA reconciliation to Net Cash Provided by Operating Activities: Net cash provided by operating activities 13,916 6,694 21,308 Net change in operating assets and liabilities (10,007) 5,266 9,344 Current income tax provision 35 97 269 Adjusted EBITDA (Non-GAAP) $3,944 $12,057 $30,921
Matador Resources Company – Company Overview
Market Capitalization(1) ~$3.4 billion Avg Daily Production – Q4 2017(2) ~43,700 BOE/d Oil (% total) ~24,700 Bbl/d (56%) Natural Gas (% total) ~114 MMcf/d (44%) Proved Reserves @ 12/31/2017 152.8 million BOE % Proved Developed 45% % Oil 57% 2018E CapEx(3) $600 to $660 million % Delaware Basin ~100% Gross Acreage(4) ~256,900 acres Net Acreage(4) ~165,800 acres Engineered Drilling Locations(5) 5,355 gross / 2,318 net Delaware Basin 4,630 gross / 1,958 net Eagle Ford 241 gross / 208 net Haynesville/Cotton Valley 484 gross / 152 net
* Note: Represents year-over-year increase as compared to the fourth quarter of 2016. ** Note: Represents increase as compared to each respective figure at or for the year ended December 31, 2016. (1) Market capitalization based on closing share price as of March 5, 2018 and shares outstanding as reported in the Company’s most recent Annual Report on Form 10-K. (2) Average daily production for the three months ended December 31, 2017. (3) 2018 estimated capital expenditures, including anticipated operations and midstream expenditures, but excluding potential land and seismic expenditures, as of February 21, 2018. Assumes a 6-rig program in the Delaware Basin. (4) As of December 31, 2017. (5) Identified and engineered locations for potential future drilling, including specified production units and estimated lateral lengths, costs and well spacing using objective criteria for designation. Locations identified as of December 31, 2017, but including limited locations at Twin Lakes (including one operated horizontal well planned for 2018 and eight vertical Strawn PUDs). Includes identified locations where Matador has an operated or non-operated working interest.
4 46%* 44%* 18%** 14%** 57%*
10% of total production Almost no oil 23% of total natural gas 10% of total production 15% of total oil 4% of total natural gas 80% of total production 85% of total oil 73% of total natural gas
34%*
422 3,317 5,843 9,095 12,306 13,924 21,510 2011 2012 2013 2014 2015 2016 2017 7.0 9.0 11.7 16.1 25.0 27.8 38.9 2011 2012 2013 2014 2015 2016 2017
6,700 7,600 44,800 66,100 88,800 94,300 114,000 2011 2012 2013 2014 2015 2016 2017
4 10 16 24 46 57 87 32 24 52 69 85 106 153 2011 2012 2013 2014 2015 2016 2017
Reserves
Oil, MMBbl Total Reserves, MMBOE
Strong Track Record of Production and Reserves Growth
5 Average Daily Oil Production(1)
(Bbl/d)
Growth since IPO
Average Daily Total Production(1)
(MBOE/d)
Growth since IPO
Note: CAGRs reflect 2012 through 2017. (1) Unless otherwise noted, at or for the year ended December 31 of each year.
Permian Acreage(1)
(Net Acres)
Growth since IPO
Oil Reserves and Total Reserves(1)
(MMBbl and MMBOE, respectively)
Eagle Ford Development Start Delaware Program
Growth since IPO
10% 77% 47% 209% 61%
- 50%
0% 50% 100% 150% 200% 250% Q1 2016 Q2 2016 Q3 2016 Q4 2016 Q1 2017 Q2 2017 Q3 2017 Q4 2017
Permian Production Growth per Debt-Adjusted Share vs. Permian Pure Play Peers(1)
(% Change in Total (BOE) Production per Debt-Adjusted Share)
Matador’s Permian production growth per debt-adjusted share has significantly exceeded that of its Permian pure-play peers
Source: Bloomberg for all peer information. For MTDR only, upper line in graph is limited to Permian only. Peer group includes pure-play Permian peers: CPE, EGN, FANG, LPI, PE and RSPP. (1) Production per debt-adjusted share is defined as Total Production / (Shares Outstanding + (Net Debt / Volume-Weighted Average Share Price)).
Permian Basin Production Growth Compares Favorably vs. Peers
Total Production
Delaware Basin (MBOE)
Oil Production
Delaware Basin (MBbl)
BOE Production Oil Production Permian Only All-in
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24 96 124 192 242 319 563 695 802 905 1,322 1,702 1,902 2,208 2,514 2,825 3,207 Q4 2013 Q1 2014 Q2 2014 Q3 2014 Q4 2014 Q1 2015 Q2 2015 Q3 2015 Q4 2015 Q1 2016 Q2 2016 Q3 2016 Q4 2016 Q1 2017 Q2 2017 Q3 2017 Q4 2017 22 81 87 137 174 222 407 505 563 653 891 1,0811,180 1,4121,515 1,719 1,933 Q4 2013 Q1 2014 Q2 2014 Q3 2014 Q4 2014 Q1 2015 Q2 2015 Q3 2015 Q4 2015 Q1 2016 Q2 2016 Q3 2016 Q4 2016 Q1 2017 Q2 2017 Q3 2017 Q4 2017
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Note: All averages exclude MTDR. Peer averages based on Form 10-K public filings for the year ended December 31, 2017. Peers included in averages are CPE, CRZO, EGN, EPE, FANG, PDCE, PE, RSPP and WPX. (1) Drill bit, including revisions to proved reserves, during the three years ended December 31, 2017.
Favorable Finding and Development Costs Compared to Permian Peers
Finding and Development Costs – Drill Bit(1)
For the Three Years Ended December 31, 2017 ($/BOE)
Finding and Development Costs – All-in
For the Three Years Ended December 31, 2017 ($/BOE)
16% Lower 12% Lower
$10.20 $11.57
MTDR Peer Median
$14.93 $17.81
MTDR Peer Median
LEA LOVING EDDY
Jackson Trust Wolf
Quality Acreage Additions in Key Asset Areas Throughout 2017
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- Permian acreage position includes
199,600 gross (114,000 net) acres, almost all in the Delaware Basin
- During the fourth quarter of 2017, Matador
acquired ~6,900 net acres in the Delaware Basin
- From January 1 through December 31, 2017,
Matador acquired ~25,100 net acres in the Delaware Basin, including a small volume of associated production, for a total acquisition cost of ~$238 million
− Weighted average cost of $7,000 to $8,000 per net acre, excluding the value of the production acquired – far below recent public transaction prices(1)
Note: All acreage at December 31, 2017. Some tracts not shown on map. (1) Refers to publicly announced Delaware Basin transactions since January 1, 2015, with per acre valuations as high as $40,000 to $50,000 per net acre.
TWIN LAKES ~46,100 gross / ~34,400 net acres WOLF / JACKSON TRUST ~13,600 gross / ~9,400 net acres RANGER ~28,800 gross / ~15,500 net acres ARROWHEAD ~56,600 gross / ~23,400 net acres RUSTLER BREAKS ~41,000 gross / ~21,200 net acres ANTELOPE RIDGE ~12,000 gross / ~8,900 net acres
Matador Acreage Matador Acreage Acquired in 2017
LEA LOVING EDDY
Jackson Trust Wolf
Delaware Basin Acreage Position and Recent Operations and Results
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TWIN LAKES ~46,100 gross / ~34,400 net acres WOLF / JACKSON TRUST ~13,600 gross / ~9,400 net acres RANGER ~28,800 gross / ~15,500 net acres ARROWHEAD ~56,600 gross / ~23,400 net acres RUSTLER BREAKS ~41,000 gross / ~21,200 net acres ANTELOPE RIDGE ~12,000 gross / ~8,900 net acres
Matador Acreage Matador Acreage Acquired in 2017
Running six rigs in Delaware Basin – expect to run six rigs throughout 2018
- Rustler Breaks: Three rigs drilling
primarily Wolfcamp A-XY and Wolfcamp B wells, plus at least two salt water disposal wells for San Mateo
- Antelope Ridge: One rig testing
multiple targets – initial well results confirm potential of acreage position
- Wolf/Jackson Trust: One rig drilling
primarily Wolfcamp A-XY and Wolfcamp B wells – more longer laterals in Wolfcamp A-XY
- Arrowhead/Ranger/Twin Lakes:
One rig drilling primarily Second and Third Bone Spring wells; second Wolfcamp D test in Twin Lakes
Note: All acreage at December 31, 2017. Some tracts not shown on map. Note: Callout boxes outlined in green and red above include well results released publicly for the first time in the Fourth Quarter 2017 Earnings Release on February 21, 2018 and at Analyst Day on March 6, 2018, respectively. Note: Rig shown at Antelope Ridge drilled only two wells in Q4 2017, both of which were completed and turned to sales in Q1 2018.
Stebbins 20 #124H
2nd Bone Spring 24-hr IP: 845 BOE/d (90% oil)
Stebbins 19 #123H
2nd Bone Spring 24-hr IP: 1,012 BOE/d (90% oil)
Florence #202H
Wolfcamp A 24-hr IP: 1,947 BOE/d (81% oil)
Charlie Sweeney #204H
Wolfcamp A-Lower 24-hr IP: 1,188 BOE/d (75% oil)
Tom Matthews #223H
Wolfcamp B-Blair 24-hr IP: 2,273 BOE/d (31% oil)
Toot #211H
Wolfcamp A-Lower 24-hr IP: 1,692 BOE/d (81% oil)
Cimarex State LF 32-5 2H
Wolfcamp D test at Twin Lakes 2-mile lateral; currently being completed Leo Thorsness #211H Wolfcamp A-Lower Currently flowing back after completion Marlan Downey #111H 1st Bone Spring 24-hr IP: 1,491 BOE/d (82% oil)
Rustler Breaks Asset Area – Eddy County, New Mexico
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Asset Summary and Recent Highlights
− Approximately 41,000 gross (21,200 net) acres; continuing to add to and block up acreage position − Producing from seven intervals, including 2nd Bone Spring, Wolfcamp A-XY, Wolfcamp A-Lower, three intervals of the Wolfcamp B and the Morrow(1) − Plan to run three rigs throughout remainder of 2018, including drilling two additional SWDs for San Mateo − Continue to achieve strong, consistent well results in Wolfcamp A-XY and Wolfcamp B intervals − Strong Wolfcamp A-XY well results in the northwest portion of Rustler Breaks acreage – several outperforming 900 MBOE type curve − Initial Wolfcamp A-Lower wells continue to perform well; additional testing included in 2018 program − Initial tests planned in the 3rd Bone Spring(2) and Wolfcamp D intervals in 2018 − In Q4 2017, the Rustler Breaks asset area accounted for 62% of our Delaware Basin total production, including 12,000 Bbl/d of oil and 58 MMcf/d of natural gas
RUSTLER BREAKS ~41,000 gross / ~21,200 net acres Zach McCormick Fed #226H 24-hr IP: 2,033 BOE/d (42% oil) Matador Acreage
Michael Collins #206H
24-hr IP: 1,312 BOE/d (77% oil) 2nd Bone Spring Wolfcamp A-XY Wolfcamp B Wolfcamp A-Lower
Miss Sue #202H
24-hr IP: 1,343 BOE/d (78% oil)
Charlie Sweeney #204H
24-hr IP: 1,188 BOE/d (75% oil) Tom Matthews #223H 24-hr IP: 2,273 BOE/d (31% oil)
Anne Com #202H
24-hr IP: 1,394 BOE/d (76% oil)
Note: Callout boxes outlined in green and red above include well results released publicly for the first time in the Fourth Quarter 2017 Earnings Release on February 21, 2018 and at Analyst Day on March 6, 2018, respectively. Acreage at December 31, 2017. (1) Producing from existing vertical well deepened to the Morrow. (2) Test planned by another operator on Matador acreage in 2018.
Black River Cryogenic Natural Gas Processing Plant and Salt Water Disposal Wells #1, #2 and #3 Norris-Thornton #2 Vertical Morrow(1) Flowing 3 MMcf/d @ 3,375 psi Still cleaning up following completion
Antelope Ridge Asset Area – Off to a Strong Start!
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2nd Bone Spring Wolfcamp A-XY Brushy Canyon
Asset Summary and Highlights
− Approximately 12,000 gross (8,900 net) acres in area of strong industry well results − Excellent initial test results from first two operated wells in two different intervals: First Bone Spring and Wolfcamp A-XY − Approximately 5,900 net state and federal acres with net revenue interests of 78 to 87.5% − High oil cuts; often above 80% − Lower water cuts; often 50% or less
ANTELOPE RIDGE ~12,000 gross / ~8,900 net acres
Note: Callout boxes outlined in green and red above include well results released publicly for the first time in the Fourth Quarter 2017 Earnings Release on February 21, 2018 and at Analyst Day on March 6, 2018, respectively. Acreage at December 31, 2017.
Wolfcamp A-Lower 3rd Bone Spring 1st Bone Spring
Florence #1H Regeneration (Matador acquired) 24 month cum: 272 MBOE (79% oil) Gettysburg St Com #1H Concho 27 month cum: 380 MBOE (82% oil) Tour Bus 23 St #502H EOG 15 month cum: 195 MBOE (82% oil) Leo Thorsness #211H Matador Currently flowing back after completion Marlan Downey #111H Matador 24-hr IP: 1,491 BOE/d (82% oil) White Falcon 16 St #1H Endurance (Concho acquired) 20 month cum: 441 MBOE (81% oil) Skull Cap Fed Com #22H Concho 11 month cum: 492 MBOE (85% oil) Sweetness 30 State #1H Devon 31 month cum: 310 MBOE (71% oil) Florence State #202H Matador 24-hr IP: 1,947 BOE/d (81% oil)
24-Hour Initial Potential Test Results
Well Interval Oil (Bbl/d) Gas (Mcf/d) BOE (BOE/d) % Oil Florence State Com #202H Wolfcamp A-XY 1,585 2,217 1,947 81% Marlan Downey State Com #111H 1st Bone Spring 1,228 1,582 1,491 82% Leo Thorsness #211H Wolfcamp A-Lower Flowing Back
Matador Acreage
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Wolf and Jackson Trust Asset Areas – Loving County, Texas
Asset Summary and Recent Highlights
− Approximately 13,600 gross (9,400 net) acres − Successfully tested five primary intervals, including Second Bone Spring, Wolfcamp A-X and A-Y, Wolfcamp A-Lower and Wolfcamp B − Running one rig in Q1 2018 and expect to run one rig throughout 2018 − Wolfcamp A-Lower wells drilled at Jackson Trust in 2017 are best Wolfcamp A-Lower Matador has wells drilled to date in Loving County − Matador’s first Wolfcamp B test at Wolf continues to perform above expectations − Barnett #224H well is currently tracking above 1 million BOE type curve − Matador’s longest completed lateral, the Kerr #201H well, had a completed lateral length of ~7,700 feet; more longer laterals planned in 2018 − In Q4 2017, the Wolf and Jackson Trust asset areas accounted for 22% of Delaware Basin total production, including ~4,500 Bbl/d of oil and ~19.8 MMcf/d of natural gas
Wolfcamp B 2nd Bone Spring Wolfcamp A-XY Wolfcamp A-Lower WOLF / JACKSON TRUST ~13,600 gross / ~9,400 net acres
Larson #201H
24-hr IP: 1,301 BOE/d (62% oil)
Toot #211H
24-hr IP: 1,692 BOE/d (81% oil)
Kerr #201H and #202H
24-hr IP: 1,071 BOE/d (63% oil) 24-hr IP: 1,170 BOE/d (59% oil)
Barnett #224H
24-hr IP: 1,803 BOE/d (28% oil)
Walter Fister #201H
24-hr IP: 1,170 BOE/d (59% oil)
Totum #211H
12-month cum: ~300,000 BOE Matador Acreage
Note: Callout boxes outlined in green and red above include well results released publicly for the first time in the Fourth Quarter 2017 Earnings Release on February 21, 2018 and at Analyst Day on March 6, 2018, respectively. Acreage at December 31, 2017.
LEA EDDY
Arrowhead and Ranger Asset Areas – Eddy and Lea Counties, NM
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Baroque “BTQ” Fed Com #1H Yates Petroleum (EOG) ~471 MBbl in first 22 months
Asset Summary and Recent Highlights
− Approximately 85,400 gross (38,900 net) acres between Arrowhead and Ranger asset areas with NRIs typically above 80% − Producing from four primary intervals, principally 2nd Bone Spring and 3rd Bone Spring − Running one rig in Q1 2018 and expect to run one rig throughout remainder of 2018 − Tested 2nd and 3rd Bone Spring across Matador’s northern Delaware Basin acreage position in 2017 − First test of 2nd Bone Spring in Arrowhead asset area, the Stebbins 20 Federal #123H well, has produced over 200,000 BOE in first nine months
- f production, including more than 150,000 Bbl of oil
− Mallon 27 Federal Com #1H, #2H and #3H wells, each Third Bone Spring completions, have produced almost 1.3 million BOE (90% oil) in the aggregate, including over 1.1 million barrels of oil in just over one year of production
2nd Bone Spring Wolfcamp A-Lower Wolfcamp D
Note: All acreage at December 31, 2017.
Airstrip #132H Matador 24-hr IP: 1,263 BOE/d (93% oil) ~86 MBbl in first 5 months Cimarron #133H Matador 24-hr IP: 920 BOE/d (92% oil) Della 29 Federal Com #701H EOG ~143 MBbl in first 14 months Mallon 27 Fed Com #1H, #2H, #3H Matador Combined ~1,100 MBbl in first 13 months
3rd Bone Spring
Gobbler 5 B2PM #1H Mewbourne ~251 MBbl in first 33 months Leo 15 B2DH Fed #1H Mewbourne ~307 MBbl in first 32 months Lea Unit #39H Legacy ~242 MBbl in first 11 months
1st Bone Spring
Federal 30 #123H Matador 24-hr IP: 657 BOE/d (91% oil) Stebbins 20 Fed #134H Matador 24-hr IP: 856 BOE/d (76% oil) Stebbins 20 Fed #123H Matador ~150 MBbl in first 9 months Stebbins 19 Fed Com #123H Matador 24-hr IP: 1,012 BOE/d (90% oil) Stebbins 20 Fed #124H Matador 24-hr IP: 845 BOE/d (90% oil) Birddog 20 17 B2FC State Com #1H Mewbourne Tested ~2,300 BOE/d (90% oil) Hackberry 26 Fed Com #1H Cimarex ~127 MBbl in first 6 months Ranger 33 State Com #123H Matador 24-hr IP: 689 BOE/d (92% oil)
Wolfcamp A-XY
Matador Acreage
Note: Callout boxes outlined in green above include well results released publicly for the first time in the Fourth Quarter 2017 Earnings Release on February 21, 2018.
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San Mateo Natural Gas Gathering and Processing System Overview
System Overview
- Black River Processing Plant has a designed natural gas processing capacity of 60 MMcf/d
- During Q4 2017, San Mateo processed an average of 64 MMcf/d
- Additional 200 MMcf/d of designed processing capacity expected to come online in Q1 2018
- Expecting to process 90 to 100 MMcf/d with initial expansion start-up
- Provides capacity for third-party volumes
- San Mateo has 45 miles of natural gas gathering infrastructure in Rustler Breaks and Wolf asset areas
- During Q4 2017, San Mateo gathered an average of 106 MMcf/d
- NGL pipeline interconnect at tailgate of Black River Processing Plant expected to be completed in Q1 2018
- Eliminates need for trucks to haul NGLs
- Allows for plant to operate in full ethane recovery mode
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San Mateo Water Gathering and Disposal System Overview
(1) February 2018 average daily disposal volume rate.
System Overview
- Current designed salt water disposal capacity of 160,000 Bbl/d
- Six disposal wells – three in Rustler Breaks asset area and three in Wolf asset area
- 44 miles of water gathering and transportation pipeline in Rustler Breaks and Wolf
- During Q4 2017, San Mateo disposed of an average of 82,000 Bbl/d of water
- Currently disposing of almost 110,000 Bbl/d(1) of water
- Expect to increase designed capacity to 220,000 Bbl/d in 2018
- Upgrading capacity of existing salt water disposal wells in Rustler Breaks
- Expect to drill and complete at least two additional salt water disposal wells and construct associated
commercial facilities in Rustler Breaks
- Currently connected via pipeline to multiple third-party producers and accepting trucked volumes
- In discussions with additional third-party producers for water gathering and disposal contracts
San Mateo Midstream Overview
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- Equity: Owns 49% equity interest
- Contribution: Contributed $171.5 million plus initial capital
commitment of $73.5 million
- Equity: Owns 51% equity interest
- Special Distribution: Received $171.5 million
- Performance Incentives: Earned $14.7 million in
performance incentives paid by Five Point in March 2018; may receive additional $58.8 million over next four years
- Contribution: Contributed Delaware Basin midstream
assets plus initial capital commitment of $76.5 million
- Operations: Retains operational control of Joint
Venture
- Other Terms: Receives firm service at market rates in
exchange for acreage dedication and relatively modest minimum volume commitments Midstream Assets
- Eddy County, NM cryogenic natural gas processing plant – Black River Processing Plant
- Eddy County salt water disposal wells and commercial facilities
- Eddy County oil, natural gas and water gathering and transportation systems
- Loving County, TX salt water disposal wells and commercial facilities
- Loving County oil, natural gas and water gathering systems
Implied valuation of $500 million at formation
Formed February 2017
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San Mateo Plans to Expand Oil Gathering and Transportation System Through Strategic Relationship with Plains(1)
- Gathering and Transportation System: San Mateo continues
to build out its oil gathering and transportation pipelines in Eddy County, NM and Loving County, TX
- Central Delivery Points: San Mateo is constructing delivery
points in Eddy County, NM that are expected to be capable of accepting third-party trucked oil volumes
- Third-Parties: San Mateo expects to benefit from Plains’
extensive asset footprint and long-term customer relationships to tie in third parties
- San Mateo Milestone: Transaction broadens San Mateo’s
- fferings to a full suite of midstream services – oil gathering and
transportation, natural gas gathering and processing and salt water gathering and disposal
- Long-Haul Transportation: Plains intends to construct a mainline
extension from its current long-haul oil pipeline system in Culberson County, TX
Strategic Oil Gathering and Transportation Relationship
- Joint Development Area: San Mateo and Plains have agreed to work together through a Joint Tariff arrangement and related
transactions to offer producers located within a joint development area of ~400,000 acres in Eddy County, NM crude oil transportation services from the wellhead to Midland, TX with access to other end markets
- Federal Energy Regulatory Commission (FERC): Crude oil expected to be shipped under a Joint Tariff that will be filed with FERC prior
to the oil transportation pipeline being placed into service
- Completion: Oil gathering and transportation system expected to be complete in the second quarter or early third quarter of 2018
(1) As announced on January 22, 2018.
Q4 2015 Q4 2016 Q4 2017 Growth(1)
Designed Water Disposal Capacity 25,000 Bbl/d 70,000 Bbl/d 160,000 Bbl/d Average Water Disposed 23,000 Bbl/d 49,000 Bbl/d 82,000 Bbl/d Gathering Lines 29 miles 62 miles 91 miles Average Natural Gas Gathered 15 MMcf/d 61 MMcf/d 106 MMcf/d Average Natural Gas Processed 0 MMcf/d(2) 35 MMcf/d 64 MMcf/d San Mateo Adjusted EBITDA(3)(4) $3.9 million $12.1 million $30.9 million Cumulative Midstream Asset Value Realized $143 million $143 million $330 million(5) Value of Delaware Midstream Assets Minor $500 million(6) > $500 million
Significant Growth in Delaware Midstream Business in Last Three Years
18
6.4x 3.6x 3.1x 7.1x Significant 7.9x Significant
(1) Represents growth from Q4 2015 to Q4 2017. (2) Pro forma for the sale of the Loving County natural gas processing plant to EnLink in October 2015. (3) For the years ended December 31, 2015, 2016 and 2017, respectively. Pro forma for February 2017 San Mateo transaction and the purchase of the non-controlling interest in Fulcrum Delaware Water Resources, LLC not previously owned by Matador. (4) Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to San Mateo’s net income (loss) and net cash provided by operating activities, see Appendix. (5) As of March 6, 2018. Includes $143 million attributable to sale of the Loving County natural gas processing plant to EnLink in October 2015, $172 million received in connection with formation of San Mateo in February 2017 and approximately $15 million in performance incentives received from Five Point in March 2018. (6) Value of midstream business based upon implied valuation of San Mateo at time of formation on February 17, 2017. At March 6, 2018, Matador owns 51% of San Mateo.
$4 $12 $31 $65 $75 $100 $0 $20 $40 $60 $80 $100 $120 2015 2016 2017 Base / Low Case: 6 MTDR Rigs + Currently Contracted 3rd Party Volumes High Case: 6 MTDR Rigs + Anticipated 3rd Party Volumes High Case Run- Rate: (Q4 2018E High Case annualized) San Mateo's Adjusted EBITDA ($ in millions)(1) Water Oil Gas
- San Mateo allows Matador to retain operational control over its Delaware Basin midstream business while enhancing its ability to
unlock and capture significant value as a stand-alone business Matador has received from Five Point $14.7 million of the potential $73.5 million in performance incentives in connection with the formation of San Mateo
- Plans are to complete expansion of the Black River Processing Plant to a total designed capacity of 260 MMcf/d, as well as continue
to build out oil, natural gas and water gathering and transportation systems in Eddy County, NM and Loving County, TX and expand salt water disposal capacity in Eddy County
- Matador’s 2018E midstream capital expenditures of $80 million(1) reflects Matador’s 51% share of estimated 2018 San Mateo capital
expenditures of $137 to $177 million
19
San Mateo Initiatives Expected to Enhance Shareholder Value
100% owned by Matador Contributes ~$33 and ~$38 million, respectively, to Matador’s Adjusted EBITDA(2) Contributes ~$51 million to Matador’s Adjusted EBITDA(2) Contributed $17 million to Matador’s Adjusted EBITDA(2) Natural Gas Oil Water San Mateo formed in February 2017
~
High Case Run-Rate: Q4 2018E High Case Annualized High Case: 6 MTDR Rigs + Anticipated 3rd Party Volumes Base / Low Case: 6 MTDR Rigs + Currently Contracted 3rd Party Volumes High Case: 6 MTDR Rigs + Anticipated 3rd Party Volumes
Note: Figures exclude assets sold to EnLink in October 2015. As of March 2018, Matador owned a 51% interest in San Mateo. (1) Midpoint of 2018 guidance of $70 to $90 million for Matador’s midstream capital expenditures. (2) Adjusted EBITDA includes allocations for general and administrative expenses. Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to San Mateo’s net income (loss) and net cash provided by operating activities, see Appendix. Pro forma for February 2017 San Mateo transaction and the purchase of the non-controlling interest in Fulcrum Delaware Water Resources, LLC not previously owned by Matador.
$100 $550 $1,243 $630 $1,243 $918 $518
$613 million
Pro Forma to January 1, 2018
Elected Borrowing Commitment Available Liquidity Midstream CapEx(7) 2018 D/C/E CapEx(6) 2018 Projected Cash Flow(4) Cash and Restricted Cash(5) Additional Borrowing Base Capacity(3) $0 $100 $200 $300 $400 $500 $600 $700 $800 2018 2019 2020 2021 2022 2023 2024
$575 million $400 million elected commitment(2) - undrawn at January 1, 2018 Senior Notes $725 million borrowing base(2) $725 million
- Strong, supportive bank group led by Royal Bank of Canada
- Borrowing base increased to $725 million in March 2018
Matador chose to keep “elected borrowing commitment” at $400 million
- No borrowings outstanding at December 31, 2017 and
March 6, 2018
- Financial covenants
Maximum Total Debt to Adjusted EBITDA(1) Ratio of not more than 4.25:1.00
20
Strong Financial Position and Significant Liquidity Entering 2018
(1) Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to our net income (loss) and net cash provided by operating activities, see Appendix. (2) Borrowing capacity of $397.9 million at December 31, 2017 and March 6, 2018, after accounting for $2.1 million in outstanding letters of credit. (3) Borrowing base in excess of our $400 elected commitment. (4) Includes $14.7 million in performance incentives paid by Five Point Capital Partners LLC in March 2018 and excludes projected cash flow attributable to non-controlling interest in subsidiaries. (5) Includes Matador’s proportionate share of restricted cash. (6) Includes capital expenditures related to drilling, completing and equipping (D/C/E) wells; does not include any expenditures for land or seismic acquisitions. Estimate shown at midpoint of range. (7) Reflects Matador’s 51% share of estimated 2018 San Mateo joint venture capital expenditures. Estimate shown at midpoint of range.
Debt Maturities ($ in millions) Liquidity Position ($ in millions)
- Estimated 2018 liquidity of almost $1.25 billion pro forma to
January 1, 2018 following increase in borrowing base
- Matador is well funded to conduct its E&P and midstream
- perations in 2018 and into 2019
Strong, Simple Balance Sheet Ample Liquidity for 2018
LEA LOVING
Matador Resources Acreage
TWIN LAKES ~46,100 gross / ~34,400 net acres WOLF / JACKSON TRUST ~13,600 gross / ~9,400 net acres RANGER ~38,800 gross / ~15,500 net acres ARROWHEAD ~56,600 gross / ~23,400 net acres
EDDY
RUSTLER BREAKS ~41,000 gross / ~21,200 net acres Jackson Trust ANTELOPE RIDGE ~12,000 gross / ~8,900 net acres Wolf #
Gross wells on production in 2018
Matador’s 2018 Delaware Basin Operated Drilling Program
21
Note: All acreage at December 31, 2017. Some tracts not shown on map. Note: Third rig shown at Rustler Breaks expected to drill at least two SWDs for San Mateo. (1) Total operated well count includes two gross Morrow deepenings in the Ruster Breaks asset area.
Rustler Breaks
− 51 gross (39.0 net) wells in progress for 2018 − 42 gross (33.9 net) wells turned to sales, including 28 Wolfcamp A, 8 Wolfcamp B, 1 Wolfcamp D and 3 2nd Bone Spring wells
Antelope Ridge
− 18 gross (16.0 net) wells in progress for 2018 − 15 gross (13.2 net) wells turned to sales, including 8 Wolfcamp A, 2 1st Bone Spring, 2 2nd Bone Spring, 2 3rd Bone Spring and 1 Brushy Canyon wells
Wolf/Jackson Trust
− 15 gross (11.0 net) wells in progress for 2018 − 11 gross (7.4 net) wells turned to sales, including 8 Wolfcamp A-XY, 1 Wolfcamp A-Lower and 2 Wolfcamp B wells
Ranger/Arrowhead
− 15 gross (9.3 net) wells in progress for 2018 − 11 gross (7.7 net) wells turned to sales, including 7 2nd Bone Spring, 3 3rd Bone Spring and 1 Wolfcamp A-XY wells
Twin Lakes
− 1 gross (0.8 net) wells in progress and turned to sales during 2018 – second Wolfcamp D test
Total Operated Drilling Program
− 100 gross (76.1 net) wells in progress for 2018 − 80 gross (62.9 net)(1) wells turned to sales, including 58 Wolfcamp, 19 Bone Spring and 1 Brushy Canyon
11 42 8 1 15 3
1,696 3,805 6,578 8,963 2,377 5,831 10,754 14,621
2015 2016 2017 2018E 36% 36% 124% 145% 73% 84%
12.2 25.1 34.1 4.1 4,492 5,096 7,851 9,900 9,109 10,180 14,212 16,900
2015 2016 2017 2018E 26% 19% 13% 12% 54% 40%
27.7 30.5 38.2 42.0
Total Oil and Natural Gas Production
Oil (MBbl)
22
2018 Oil and Natural Gas Production Estimates(1)
Oil, MBbl Natural Gas, Bcf
Total (MBOE)
Delaware Oil and Natural Gas Production
2018E Oil Production – 26% Growth YoY
- Estimated oil production of 9.7 to 10.1 million barrels
− 26% increase from 2017 to midpoint of 2018 range
- Average daily oil production of 27,100 Bbl/d, up from 21,500 Bbl/d
in 2017
− Delaware Basin ~24,600 Bbl/d (91%) – up 36% YoY − Eagle Ford ~2,500 Bbl/d (9%) – down 26% YoY − Oil production increases from 24,700 Bbl/d in Q1 2018 to 29,100 Bbl/d in Q4 2018 – flat in Q1 2018 from Q4 2017 and growing from there − Q4 2018 up 18% over Q4 2017
2018E Natural Gas Production – 10% Growth YoY
- Estimated natural gas production of 41.0 to 43.0 Bcf
− 10% increase from 2017 to midpoint of 2018 range
- Average daily natural gas production of 115.1 MMcf/d, compared
to 104.6 MMcf/d in 2017
− Delaware Basin ~93.4 MMcf/d (81%) – up 36% YoY − Haynesville/Cotton Valley ~17.5 MMcf/d (15%) – down 42% YoY − Eagle Ford ~4.1 MMcf/d (4%) – down 27% YoY − Q1 2018 down 3 to 5% from Q4 2017 − Q4 2018 up 1% over Q4 2017 – peaks in Q3 2018
Oil, MBbl Natural Gas, Bcf
Natural Gas (Bcf) Oil (MBbl) Total (MBOE) 2018E CapEx(2) (Midpoint): D/C/E: $550 MM Midstream(3): $80 MM Total: $630 MM
(1) As provided on February 21, 2018. (2) Includes only capital expenditures related to drilling, completing and equipping (D/C/E) wells and for various midstream projects; does not include any expenditures for land or seismic acquisitions. (3) Reflects Matador’s 51% share of estimated 2018 San Mateo capital expenditures.
- Preserved and enhanced liquidity through October 2017 equity offering and February 2017 San Mateo midstream joint venture.
- Strong financial position and well-funded to execute our 2018 drilling program and midstream operations, primarily using cash on the
balance sheet of ~$97 million (not including $6 million of restricted cash, most of which is associated with San Mateo) at December 31, 2017, operating cash flows, performance incentives of ~$15 million received in March 2018 from Five Point(1), proceeds from our October 2017 equity offering of ~$208 million and undrawn borrowing capacity of ~$400 million(2) at March 6, 2018.
- Net Debt/LTM Adjusted EBITDA(3)(4)(5) of ~1.4x at December 31, 2017
23
(1) On March 2, 2018, Matador received $14.7 million in performance incentives from Five Point, in connection with the February 2017 formation of San Mateo. Matador may earn an additional $58.8 million in performance incentives over the next four years. (2) Borrowing capacity of $397.9 million at December 31, 2017 and March 6, 2018, after accounting for $2.1 million in outstanding letters of credit. The Company’s lenders under its credit facility increased the borrowing base to $725 million on March 5, 2018, but the Company maintained its ‘elected borrowing commitment’ at $400 million. (3) Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to our net income (loss) and net cash provided by operating activities, see Appendix. (4) Net Debt is equal to debt outstanding less available cash (including Matador’s proportionate share of any restricted cash). (5) Attributable to Matador Resources Company shareholders after giving effect to amounts attributable to third-party non-controlling interests.
Committed to Maintaining Strong Balance Sheet
Initial Public Offering Equity Raise Equity Raise Notes Offering + Equity Raise
(3)(4)(5)
Net Debt ($ millions) Midstream Sale Equity Raise Notes Offering + Equity Raise Midstream JV Equity Raise
14.0
0.0 4.0 8.0 12.0 16.0 Mar-Dec 2018
Natural Gas Hedged (Bcf) Prices in $/MMBtu
2,400 1,600 600 4,600
1,000 2,000 3,000 4,000 5,000 Mar-Dec 2018
Oil Volume Hedged (MBbl) Prices in $/Bbl
Hedging Profile
Remainder of 2018 Hedges(1)
- Oil (WTI) Costless Collars: ~2.4 million barrels hedged for remainder of 2018 at weighted average floor and ceiling prices of $44/Bbl and $60/Bbl,
respectively
- Oil (WTI) Costless Participating Three-Way Collars(2): ~1.6 million barrels hedged for remainder of 2018 at weighted average floor price of $50/Bbl
and call spread / ceiling prices of $64/Bbl (short call) and $67/Bbl (long call), respectively
- Oil (LLS) Costless Collars: ~0.6 million barrels hedged for remainder of 2018 at weighted average floor and ceiling prices of $45/Bbl and $63/Bbl,
respectively
- Midland-Cushing Oil Basis Differential: ~4.4 million barrels hedged for remainder of 2018 at a weighted average price of -$1.02/Bbl
- Natural Gas: ~14.0 Bcf hedged for remainder of 2018 at weighted average floor and ceiling prices of $2.58/MMBtu and $3.67/MMBtu, respectively
24
Oil Hedges (Costless Collars) Natural Gas Hedges (Costless Collars)
(1) At March 6, 2018. (2) Participating three-way costless collars consist of a long put (the floor) and a short call (the ceiling) just like an ordinary costless collar, but adds a long call that limits losses on the upside and allows Matador to participate in a rising price environment.
$60 $44
~55% hedged for remainder of 2018 ~40% hedged for remainder of 2018
$3.67 $2.58 $63 $45 LLS Collars WTI Participating Three-Way Collars $64/67 $50 WTI Collars
Updated 2017 Guidance(1) Actual 2017 Results 2018 Guidance(2) %YoY Change(3)
D/C/E CapEx
$440 to $465 million $493 million $530 to $570 million + 12%
Midstream CapEx(4)
$66 to $74 million $60 million $70 to $90 million + 33%
Total Oil Production
7.7 to 7.75 million Bbl 7.9 million Bbl 9.7 to 10.1 million Bbl + 26%
Total Natural Gas Production
37.0 to 37.5 Bcf 38.2 Bcf 41.0 to 43.0 Bcf + 10%
Total Oil Equivalent Production
13.9 to 14.0 million BOE 14.2 million BOE 16.5 to 17.3 million BOE + 19%
Adjusted EBITDA(5)
$300 to $310 million $336 million $425 to $455 million + 31%
25
Summary and 2018 Guidance (as Provided on February 21, 2018)
(1) As updated on November 6, 2017. Adjusted EBITDA based on the midpoint of updated 2017 production guidance range and actual values realized through September 30, 2017. Estimated average realized prices for oil and natural gas used in the estimates were $50.50/Bbl (WTI oil price of $53.00/Bbl less $2.50/Bbl of estimated price differentials) and $2.87/Mcf (NYMEX Henry Hub natural gas price assuming regional price differentials and uplifts from natural gas processing roughly offset), respectively, for the period October through December 2017. (2) As provided on February 21, 2018. Estimated average realized prices for oil and natural gas used in the estimates were $55.71/Bbl (forward strip for oil prices as of mid-February 2018, which yields an average West Texas Intermediate oil price of $58.21/Bbl, less $2.50/Bbl of estimated price differentials) and $2.98/Mcf (forward strip for natural gas prices as of mid-February 2018, which yields an average NYMEX Henry Hub natural gas price of $2.73/Mcf, plus $0.25/Mcf, assuming uplifts from natural gas processing are slightly above regional price differentials during the year), respectively, for the period January through December 2018. (3) Represents percentage change from 2017 actual results to the midpoint of 2018 guidance. (4) Reflects Matador’s 51% share of 2018 estimated capital expenditures for San Mateo. (5) Adjusted EBITDA is a non-GAAP financial measure. For a definition of Adjusted EBITDA and a reconciliation of Adjusted EBITDA to our net income (loss) and net cash provided by operating activities, see Appendix.
- Plan to run 6 rigs in the Delaware Basin throughout 2018
Three rigs in Rustler Breaks, one rig in Antelope Ridge, one rig in Wolf/Jackson Trust and one rig in Ranger/Arrowhead/Twin Lakes One of the Rustler Breaks rigs expected to drill at least two salt water disposal wells for San Mateo
- Limited capital expenditures in the Eagle Ford and Haynesville in 2018
- Oil production expected to be relatively flat sequentially in Q1 2018 before growing again in subsequent quarters
- Natural gas production expected to be down 3 to 5% sequentially in Q1 2018
- Will pursue strategic acreage and mineral acquisitions, primarily in the Delaware Basin, as opportunities arise
April 9, 2018
2018 IPAA OGIS – New York
NYSE: MTDR Matthew V. Hairford, President
Appendix
NYSE: MTDR
28
Adjusted EBITDA Reconciliation
This investor presentation 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 industry 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
- perations from period to period without regard to its financing methods or capital structure. The Company defines Adjusted EBITDA
as earnings before interest expense, income taxes, depletion, depreciation and amortization, accretion of asset retirement obligations, property impairments, unrealized derivative gains and losses, certain other non-cash items and non-cash stock-based compensation expense, and net gain or loss on asset sales and inventory impairment. Adjusted EBITDA is not a measure of net income (loss) or net cash provided by operating activities as determined by GAAP. Adjusted EBITDA should not be considered an alternative to, or more meaningful than, net income (loss) or net cash provided by
- perating activities as determined in accordance with GAAP or as a primary 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 the forward-looking Adjusted
EBITDA numbers included in this investor presentation 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.
Adjusted EBITDA Reconciliation
The following table presents our calculation of Adjusted EBITDA and reconciliation of Adjusted EBITDA to the GAAP financial measures of net income (loss) and net cash provided by operating activities, respectively. 29
(In thousands) 1Q 2011 2Q 2011 3Q 2011 4Q 2011 1Q 2012 2Q 2012 3Q 2012 4Q 2012 1Q 2013 2Q 2013 3Q 2013 4Q 2013 Unaudited Adjusted EBITDA reconciliation to Net (Loss) Income: Net (loss) income attributable to Matador Resources Company shareholders $ (27,596) $ 7,153 $ 6,194 $ 3,941 $ 3,801 $ (6,676) $ (9,197) $ (21,188) $ (15,505) $ 25,119 $ 20,105 $ 15,374 Net (loss) income attributable to non-controlling interest in subsidiaries
- Net income (loss)
(27,596) 7,153 6,194 3,941 3,801 (6,676) (9,197) (21,188) (15,505) 25,119 20,105 15,374 Interest expense 106 184 171 222 308 1 144 549 1,271 1,609 2,038 768 Total income tax provision (benefit) (6,906) (46)
- 1,430
3,064 (3,713) (593) (188) 46 32 2,563 7,056 Depletion, depreciation and amortization 7,111 8,180 7,287 9,176 11,205 19,914 21,680 27,655 28,232 20,234 26,127 23,802 Accretion of asset retirement obligations 39 57 62 51 53 58 59 86 81 80 86 100 Full-cost ceiling impairment 35,673
- 33,205
3,596 26,674 21,230
- Unrealized (gain) loss on derivatives
1,668 (332) (2,870) (3,604) 3,270 (15,114) 12,993 3,653 4,825 (7,526) 9,327 606 Stock-based compensation expense 53 128 1,234 991 (363) 191 (51) 363 492 1,032 1,239 1,134 Net loss (gain) on asset sales and inventory impairment
- 154
- 60
- 425
- 192
- Consolidated Adjusted EBITDA
10,148 15,324 12,078 12,361 21,338 27,926 28,631 38,029 40,672 40,772 61,485 48,840 Adjusted EBITDA attributable to non-controlling interest in subsidiaries
- Adjusted EBITDA attributable to Matador Resources Company shareholders
$ 10,148 $ 15,324 $ 12,078 $ 12,361 $ 21,338 $ 27,926 $ 28,631 $ 38,029 $ 40,672 $ 40,772 $ 61,485 $ 48,840 (In thousands) 1Q 2011 2Q 2011 3Q 2011 4Q 2011 1Q 2012 2Q 2012 3Q 2012 4Q 2012 1Q 2013 2Q 2013 3Q 2013 4Q 2013 Unaudited Adjusted EBITDA reconciliation to Net Cash Provided by Operating Activities: Net cash provided by operating activities $ 12,732 $ 6,799 $ 14,912 $ 27,425 $ 5,110 $ 46,416 $ 28,799 $ 43,903 $ 32,229 $ 51,684 $ 43,280 $ 52,278 Net change in operating assets and liabilities (2,690) 8,386 (3,004) (15,286) 15,920 (18,491) (500) (6,235) 7,126 (12,553) 15,265 (3,630) Interest expense, net of non-cash portion 106 184 171 222 308 1 144 549 1,271 1,609 2,038 768 Current income tax (benefit) provision
- (45)
(1)
- 188
(188) 46 32 902 (576) Adjusted EBITDA attributable to non-controlling interest in subsidiaries
- Adjusted EBITDA attributable to Matador Resources Company shareholders
$ 10,148 $ 15,324 $ 12,078 $ 12,361 $ 21,338 $ 27,926 $ 28,631 $ 38,029 $ 40,672 $ 40,772 $ 61,485 $ 48,840 (In thousands) 1Q 2014 2Q 2014 3Q 2014 4Q 2014 1Q 2015 2Q 2015 3Q 2015 4Q 2015 1Q 2016 2Q 2016 3Q 2016 4Q 2016 1Q 2017 2Q 2017 3Q 2017 4Q 2017 Unaudited Adjusted EBITDA reconciliation to Net (Loss) Income: Net (loss) income attributable to Matador Resources Company shareholders $ 16,363 $ 18,226 $ 29,619 $ 46,563 $ (50,234) $ (157,091) $ (242,059) $ (230,401) $ (107,654) $ (105,853) $ 11,931 $ 104,154 $ 43,984 $ 28,509 $ 15,039 $ 38,335 Net (loss) income attributable to non-controlling interest in subsidiaries
- (17)
36 75 45 105 (13) 106 116 155 1,916 3,178 2,940 4,106 Net income (loss) 16,363 18,226 29,619 46,546 (50,198) (157,016) (242,014) (230,296) (107,667) (105,747) 12,047 104,309 45,900 31,687 17,979 42,441 Interest expense 1,396 1,616 673 1,649 2,070 5,869 7,229 6,586 7,197 6,167 6,880 7,955 8,455 9,224 8,550 8,336 Total income tax provision (benefit) 9,536 10,634 16,504 27,701 (26,390) (89,350) (33,305) 1,677
- (1,141)
105
- (8,157)
Depletion, depreciation and amortization 24,030 31,797 35,143 43,767 46,470 51,768 45,237 35,370 28,923 31,248 30,015 31,863 33,992 41,274 47,800 54,436 Accretion of asset retirement obligations 117 123 130 134 112 132 182 307 264 289 276 354 300 314 323 353 Full-cost ceiling impairment
- 67,127
229,026 285,721 219,292 80,462 78,171
- Unrealized (gain) loss on derivatives
3,108 5,234 (16,293) (50,351) 8,557 23,532 (6,733) 13,909 6,839 26,625 (3,203) 10,977 (20,631) (13,190) 12,372 11,734 Stock-based compensation expense 1,795 1,834 1,038 857 2,337 2,794 1,755 2,564 2,243 3,310 3,584 3,224 4,166 7,026 1,296 4,166 Net loss (gain) on asset sales and inventory impairment
- 97
- (1,005)
(1,065) (1,002) (1,073) (104,137) (7)
- (16)
- Consolidated Adjusted EBITDA
56,345 69,464 66,814 70,303 50,182 66,755 58,072 48,404 17,196 39,061 47,385 54,650 72,175 76,335 88,304 113,309 Adjusted EBITDA attributable to non-controlling interest in subsidiaries
- 17
(38) (80) (49) (111) 4 (115) (125) (164) (2,216) (3,683) (3,471) (4,690) Adjusted EBITDA attributable to Matador Resources Company shareholders $ 56,345 $ 69,464 $ 66,814 $ 70,320 $ 50,144 $ 66,675 $ 58,023 $ 48,293 $ 17,200 $ 38,946 $ 47,260 $ 54,486 $ 69,959 $ 72,652 $ 84,833 $ 108,619 (In thousands) 1Q 2014 2Q 2014 3Q 2014 4Q 2014 1Q 2015 2Q 2015 3Q 2015 4Q 2015 1Q 2016 2Q 2016 3Q 2016 4Q 2016 1Q 2017 2Q 2017 3Q 2017 4Q 2017 Unaudited Adjusted EBITDA reconciliation to Net Cash Provided by Operating Activities: Net cash provided by operating activities $ 31,945 $ 81,530 $ 66,883 $ 71,123 $ 93,346 $ 20,043 $ 72,535 $ 22,611 $ 18,358 $ 31,242 $ 46,862 $ 37,624 $ 61,309 $ 59,933 $ 101,274 $ 76,609 Net change in operating assets and liabilities 21,729 (15,221) (586) 56 (45,234) 40,843 (20,846) 16,254 (8,059) 1,944 (4,909) 9,215 2,455 7,198 (21,481) 36,886 Interest expense, net of non-cash portion 1,396 1,616 673 1,649 2,070 5,869 6,678 6,285 6,897 5,875 6,573 7,706 8,411 9,204 8,511 7,971 Current income tax (benefit) provision 1,275 1,539 (156) (2,525)
- (295)
3,254
- (1,141)
105
- (8,157)
Adjusted EBITDA attributable to non-controlling interest in subsidiaries
- 17
(38) (80) (49) (111) 4 (115) (125) (164) (2,216) (3,683) (3,471) (4,690) Adjusted EBITDA attributable to Matador Resources Company shareholders $ 56,345 $ 69,464 $ 66,814 $ 70,320 $ 50,144 $ 66,675 $ 58,023 $ 48,293 $ 17,200 $ 38,946 $ 47,260 $ 54,486 $ 69,959 $ 72,652 $ 84,833 $ 108,619
Adjusted EBITDA Reconciliation
30 The following table presents our calculation of Adjusted EBITDA and reconciliation of Adjusted EBITDA to the GAAP financial measures of net income (loss) and net cash provided by operating activities, respectively.
(In thousands) 2010 2011 2012 2013 2014 2015 2016 2017 Unaudited Adjusted EBITDA reconciliation to Net Income (Loss): Net income (loss) attributable to Matador Resources Company shareholders $6,377 ($10,309) ($33,261) $45,094 $110,771 ($679,785) ($97,421) $125,867 Net (loss) income attributable to non-controlling interest in subsidiaries
- (17)
261 364 12,140 Net income (loss) $6,377 ($10,309) ($33,261) $45,094 $110,754 ($679,524) ($97,057) $138,007 Interest expense 3 683 1,002 5,687 5,334 21,754 28,199 34,565 Total income tax provision (benefit) 3,521 (5,521) (1,430) 9,697 64,375 (147,368) (1,036) (8,157) Depletion, depreciation and amortization 15,596 31,754 80,454 98,395 134,737 178,847 122,048 177,502 Accretion of asset retirement obligations 155 209 256 348 504 734 1,182 1,290 Full-cost ceiling impairment
- 35,673
63,475 21,229
- 801,166
158,633
- Unrealized (gain) loss on derivatives
(3,139) (5,138) 4,802 7,232 (58,302) 39,265 41,238 (9,715) Stock-based compensation expense 898 2,406 140 3,897 5,524 9,450 12,362 16,654 Net loss (gain) on asset sales and inventory impairment 224 154 485 192 (908) (107,277) (23) Consolidated Adjusted EBITDA 23,635 49,911 115,923 191,771 262,926 223,416 158,292 350,123 Adjusted EBITDA attributable to non-controlling interest in subsidiaries
- 17
(278) (400) (14,060) Adjusted EBITDA attributable to Matador Resources Company shareholders $23,635 $49,911 $115,923 $191,771 $262,943 $223,138 $157,892 $336,063 (In thousands) 2010 2011 2012 2013 2014 2015 2016 2017 Unaudited Adjusted EBITDA reconciliation to Net Cash Provided by Operating Activities: Net cash provided by operating activities $27,273 $61,868 $124,228 $179,470 $251,481 $208,535 $134,086 $299,125 Net change in operating assets and liabilities (2,230) (12,594) (9,307) 6,210 5,978 (8,980) (1,809) 25,058 Interest expense, net of non-cash portion 3 683 1,002 5,687 5,334 20,902 27,051 34,097 Current income tax provision (benefit) (1,411) (46)
- 404
133 2,959 (1,036) (8,157) Adjusted EBITDA attributable to non-controlling interest in subsidiaries
- 17
(278) (400) (14,060) Adjusted EBITDA attributable to Matador Resources Company shareholders $23,635 $49,911 $115,923 $191,771 $262,943 $223,138 $157,892 $336,063 Year Ended December 31, Year Ended December 31,
Adjusted EBITDA Reconciliation – San Mateo Midstream, LLC(1)
31 The following table presents the calculation of Adjusted EBITDA and reconciliation of Adjusted EBITDA to the GAAP financial measures of net income (loss) and net cash provided by operating activities, respectively, for San Mateo Midstream, LLC(1).
(1) Pro forma for February 2017 San Mateo transaction and the purchase of the non-controlling interest in Fulcrum Delaware Water Resources, LLC not previously owned by Matador.
Year Ended December 31, (In thousands) 2015 2016 2017 Unaudited Adjusted EBITDA reconciliation to Net Income (Loss): Net income $2,719 $10,174 $26,391 Total income tax provision 647 97 269 Depletion, depreciation and amortization 562 1,739 4,231 Accretion of asset retirement obligations 16 47 30 Adjusted EBITDA (Non-GAAP) $3,944 $12,057 $30,921 Year Ended December 31, (In thousands) 2015 2016 2017 Unaudited Adjusted EBITDA reconciliation to Net Cash Provided by Operating Activities: Net cash provided by operating activities 13,916 6,694 21,308 Net change in operating assets and liabilities (10,007) 5,266 9,344 Current income tax provision 35 97 269 Adjusted EBITDA (Non-GAAP) $3,944 $12,057 $30,921