EX-99.1 2 ea119151ex99-1_texaspacific.htm INVESTOR PRESENTATION MARCH 2020

Exhibit 99.1

 

Investor Presentation March 2020

 

 

| 2 NYSE: TPL Management Team Tyler Glover Chief Executive Officer Robert Packer Chief Financial Officer Sameer Parasnis Chief Commercial Officer Robert Crain Executive Vice President of TPWR Chris Steddum Vice President, Finance and Investor Relations

 

 

| 3 NYSE: TPL This presentation has been designed to provide general information about Texas Pacific Land Trust and its subsidiaries (“TPL” or the “Trust”). Any information contained or referenced herein is suitable only as an introduction to the Trust. The recipient is strongly encouraged to refer to and supplement this presentation with information the Trust has filed with the Securities and Exchange Co mmission (“SEC”). The Trust makes no representation or warranty, express or implied, as to the accuracy or completeness of the information cont ain ed in this presentation, and nothing contained herein is, or shall be, relied upon as a promise or representation, whether as to the past or to the future. This presentation does not purport to include all of the information that may be required to evaluate the subject matter herein and any recipient hereof should conduct its own independent analysis of the Trust and the data containe d or referred to herein. Unless otherwise stated, statements in this presentation are made as of the date of this presentation, and nothing shall crea te an implication that the information contained herein is correct as of any time after such date. TPL reserves the right to cha nge any of its opinions expressed herein at any time as it deems appropriate. The Trust disclaims any obligations to update the data, in for mation or opinions contained herein or to notify the market or any other party of any such changes, other than required by la w. Industry and Market Data The Trust has neither sought nor obtained consent from any third party for the use of previously published information. Any s uch statements or information should not be viewed as indicating the support of such third party for the views expressed herein. Th e Trust shall not be responsible or have any liability for any misinformation contained in any third party report, SEC or other re gulatory filing. The industry in which the Trust operates is subject to a high degree of uncertainty and risk due to a variet y o f factors, which could cause our results to differ materially from those expressed in these third - party publications. Some of the data incl uded in this presentation is based on TPL’s good faith estimates, which are derived from TPL’s review of internal sources as wel l as the third party sources described above. All registered or unregistered service marks, trademarks and trade names referred to in thi s presentation are the property of their respective owners, and TPL’s use herein does not imply an affiliation with, or endor sem ent by, the owners of these service marks, trademarks and trade names. Forward - looking Statements This presentation contains certain forward - looking statements within the meaning of the U.S. federal securities laws that are ba sed on TPL’s beliefs, as well as assumptions made by, and information currently available to, TPL, and therefore involve risk s a nd uncertainties that are difficult to predict. These statements include, but are not limited to, statements about strategies, p lan s, objectives, expectations, intentions, expenditures and assumptions and other statements that are not historical facts. Whe n u sed in this document, words such as “anticipate,” “believe,” “estimate,” “expect,” “intend,” “plan” and “project” and similar expres sio ns are intended to identify forward - looking statements. You should not place undue reliance on these forward - looking statements. Although we believe our plans, intentions and expectations reflected in or suggested by the forward - looking statements we make i n this presentation are reasonable, we may be unable to achieve these plans, intentions or expectations and actual results, performance or achievements may vary materially and adversely from those envisaged in this document. For more information con cer ning factors that could cause actual results to differ from those expressed or forecasted, see TPL’s annual report on Form 10 - K and quarterly reports on Form 10 - Q filed with the SEC. The tables, graphs, charts and other analyses provided throughout this do cument are provided for illustrative purposes only and there is no guarantee that the trends, outcomes or market conditions depicted on them will continue in the future. There is no assurance or guarantee with respect to the prices at which sub - share c ertificates of the Trust will trade, and such securities may not trade at prices that may be implied herein. TPL’s forecasts and expectations for future periods are dependent upon many assumptions, including the drilling and developme nt plans of our customers, estimates of production and potential drilling locations, which may be affected by commodity price declines or other factors that are beyond TPL’s control. These materials are provided merely for general informational purposes and are not intended to be, nor should they be constru ed as 1) investment, financial, tax or legal advice, 2) a recommendation to buy or sell any security, or 3) an offer or solicita tio n to subscribe for or purchase any security. These materials do not consider the investment objective, financial situation, suitab ili ty or the particular need or circumstances of any specific individual who may receive or review this presentation, and may no t b e taken as advice on the merits of any investment decision. Although TPL believes the information herein to be reliable, the Trust an d p ersons acting on its behalf make no representation or warranty, express or implied, as to the accuracy or completeness of tho se statements or any other written or oral communication it makes, safe as provided for by law, and the Trust expressly disclaim s a ny liability relating to those statements or communications (or any inaccuracies or omissions therein). These cautionary stat eme nts qualify all forward - looking statements attributable to us or persons acting on our behalf. Non - GAAP Financial Measures In this presentation, TPL utilizes earnings before interest, taxes, depreciation and amortization (“EBITDA”), which is not de fin ed in the U.S. generally accepted accounting principles (“GAAP”). TPL believes that EBITDA is a useful supplement to net inco me as an indicator of operating performance. EBITDA is not presented as an alternative to net income and it should not be considered i n i solation or as a substitute for net income. Please see Appendix for a reconciliation of EBITDA to net income, the most direct ly comparable financial measure calculated in accordance with GAAP. Disclaimer

 

 

| 4 NYSE: TPL The Permian Basin “ETF” NYSE: TPL $ $ $ ~19 Years Inventory Below $40/bbl Breakeven (3) $230 Million 2019 Free Cash Flow (5)(6) +130% Production Growth since 2018 (2) Balance Sheet Strength (7) No Debt Cash Balance of $304 Million 8.5% of Shares Repurchased since Jan. 2014 (8) 17 Year History of Increasing Dividends ~23,600 Core Permian Net Royalty Acres (1) ~900,000 Surface Acres Diversified Revenue Streams: Royalties, Water, and Surface 100% Texas Permian Exposure Source: Company data and RSEG. (1) Net royalty acres defined as gross royalty acres (530,400) in - basin multiplied by the average royalty per acre (4.4%). (2) Increase in daily average net well production from 1Q’18 to 4Q’19. (3) Based on total inventory with a breakeven less than $40 divided by 2018 spud count. (4) As of 12/31/19 per RSEG. (5) Free cash flow calculated as cash flow from operations less capital expenditures. Capital expenditures do not include acquisi tio ns. Robust Inventory (4) of 486 DUCs and 304 Permits (6) Normalized for one - time ~$100 million WPX land sale (applying corporate tax rate of 21%) and one - time ~$13 million costs related to a proxy contest to elect a new Trustee. (7) As of end of 12/31/19. (8) Based on 8.473 million sub - share certificates outstanding as of 1/1/14 and 7.756 million sub - share certificates outstanding as o f 12/31/19.

 

 

| 5 NYSE: TPL An Unmatched Oil and Gas Investment Source: Company data and Bloomberg as of 12/31/19. (1) Market cap as of 12/31/19. (2) EBITDA growth represents year over year growth based on last four reported quarters. (3) Debt as of last reported quarter. EBITDA represents LTM based on last four reported quarters. (4) Return on Invested Capital (ROIC) defined as (Net Operating Profit after Taxes / Average Invested Capital) based on last fou r reported quarters. (5) EBITDA margin represents LTM based on last four reported quarters. (6) Reflects adjusted EBITDA margin for 2019 and year over year 2019 vs. 2018 growth. Please see Appendix for reconciliations of non - GAAP financial measures to their most directly comparable GAAP measures. Russell 2000 Index and Public North American Oil & Gas Companies Market Cap (1) $1.0bn or Greater EBITDA Growth (2) 10% or Greater Debt / EBITDA (3) 1.5x or Less ROIC (4) 40% or Greater >80% EBITDA Margin (5) Total Companies: 2,789 992 417 135 4 1 Oil & Gas Companies: 897 159 80 26 1 1 TPL Metrics: $6.1bn 23% (6) 0.0x ~91% ~82% (6)

 

 

| 6 NYSE: TPL Unique Exposure to Full Permian Development Chain Royalties Surface Water x x x x x x x Ownership of right of way x Ownership of groundwater and subsurface injection rights x High margins with no capital Surface Provides ease of access x x Public Vehicle Positioning Business Flow Overview Maximize Surface Ownership to Operate Profitable Water Business that Facilitates Development of Royalty Acreage Royalties x Assets located in the core of the Permian x No capex or opex burden for organic production and cash flow growth x Real ownership of assets underlying cash flow generation x Demand for water disposal services and locations on TPL surface has out - paced the rest of the Permian by a factor of ~3x (1) Allows continued development Water x Provides operational solutions across sourcing and disposal x Disposal comprises significant portion of operator LOE x Royalty stream with limited capex requirements to capture additional value = Land and Resource Management = Water Services and Operations Reporting Segments: Oil & Gas Royalty Water (1) Based on a comparison of gross produced water growth since 1/1/14 assuming current surface acreage owned. Only includes horizontal well production in the Midland and Delaware Basins from 1/1/14 to 3/31/19. TPL production growth giving effect to our portfolio of ~900,000 surface acres in the Permian Basin as of 12/31/19 as if it had been owned since 1/1/14. x

 

 

| 7 NYSE: TPL 38.5% 9.0% 21.7% 11.1% 19.6% Northern Delaware Southeast Delaware Southwest Delaware Midland Other 13.3% 19.2% 12.6% 11.2% 9.6% 8.8% 7.7% 5.9% 4.6% 3.1% 2.5% 1.6% Net Wells (3) : 46.0 Royalty Interest Overview Land and Resource Management Net Royalty Position and Rigs Running on Core TPL Acreage Source: Company data, RSEG, and Enverus Rig Analytics data as of 2/26/20. Note: Rigs on TPL based on 0.25 mile buffer around TPL Royalty Acreage DSUs and TPL Surface. Rig counts include active Horizont al, Directional and Unclassified rigs per Enverus Rig Analytics. (1) Based on 753,324 combined surface and gross royalty acres and 438,912 gross royalty only acres. (2) Net royalty acres defined as gross royalty acres (530,400) multiplied by the average royalty per acre (4.4%) as of 4Q'19. (3) Includes net 31.5 PDP, 7.0 DUCs, 3.1 Completed and 4.3 Permitted wells (represents only horizontal locations). NRA (2) : ~23,600 Net Royalty Acres Distribution Key Operators with a Permian Focus Other Royalty Acreage (530,400 Gross Royalty Acres / ~23,600 Net Royalty Acres) Combined Royalty & Surface Acreage (63% of NRA (1) ) Active Rigs on TPL Royalty & Surface Acreage (89 Rigs – 46 Delaware, 43 Midland) Active Permian Rigs (393 Rigs – 225 Delaware, 160 Midland, 8 Other) Surface Acreage (~900,000 acres)

 

 

| 8 NYSE: TPL $295.2 $233.5 $227.9 $126.7 $70.5 $48.7 $36.8 $25.1 $14.8 $10.9 $10.1 $9.6 $6.1 $5.7 $5.3 $5.3 $2.1 $2.1 $1.9 $1.6 $1.3 $1.3 $1.1 $0.7 $0.3 $0.0 $0.0 Exxon Shell Chevron BP ConocoPhillips EOG Occidental Pioneer Diamondback Marathon Devon Apache Ovintiv WPX Cimarex Parsley Matador Surge Callon PDC Centennial SM Energy QEP Resources Laredo Noble Rosehill EP Energy BTA Crownquest DE3 Discovery Endeavor Fasken Four Corners Hunt Legacy Mewbourne Sabinal Sable Sequitur Sheridan Exposed to Diverse Client Base Required to Utilize TPL Surface / Water Source: Company data and FactSet as of 12/31/19. (1) Relationships established through surface operations and/or water sourcing / produced water. Existing Relationship with TPL (1) Other Permian Operators Drill on TPL NRA TPL has Existing Relationships with Over 85% of the Top E&P and also Blue - Chip Midstream Companies x High Margin, Fixed - fee Revenue Streams x Resistant to Commodity Price Fluctuations E&P Companies on TPL Midstream Companies on TPL Market Cap (in $ billions) as of 12/31/2019 Permian Private Operators

 

 

| 9 NYSE: TPL $40 $75 $125 $230 3.3 5.1 8.8 13.7 2016 2017 2018 2019 Free Cash Flow Net Production (mboe/d) Source: Company data and RSEG. Note: Land and Resource Management values inclusive of land - related surface and easement income. Water Services and Operations v alues inclusive of water - related surface and easement income. Please see Appendix for reconciliations of non - GAAP financial meas ures to their most directly comparable GAAP measures. (1) YTD production based on average daily production from 1/1/19 through 12/31/19. (2) Free cash flow calculated as cash flow from operations less capital expenditures. Capital expenditures do not include acquis itions. (3) Normalized for one - time ~$19 million sale of nonparticipating perpetual oil and gas royalty interest in approximately 812 n et royalty acres (1/8th interest). (4) Assumes corporate tax rate of 21%. (5) Normalized for one - time ~$100 million WPX land sale, one - time ~$22 million land swap and one - time ~$13 million costs related to a proxy contest to elect a new Trustee. Business Segments Overview Adjusted EBITDA 2019 Land and Resource Management 72% Water Services and Operations 28% ~$230mm (4)(5) Free Cash Flow (2) ~$302mm (5) Land and Resource Management 93% Water Services and Operations 7% Production (1) and Free Cash Flow (2) Growth (4)(5) ($ in millions, unless specified) (3)(4)

 

 

| 10 NYSE: TPL History of the Trust Source: Company data. (1) A fixed 1/16 NPRI was reserved under all lands held by the primary term of an oil and gas lease and a fixed 1/128 NPRI under all lands held by production. (2) TPWR is a 100% wholly owned subsidiary of TPL. 1871 - 1888 1889 - 2010 2011 - Present Texas & Pacific Railway bankruptcy leads to the formation of Texas Pacific Land Trust, where all land assets were placed. 1888 Texas and Pacific Abrams #1 becomes the first well to produce oil from the Permian Basin, and a few years later, the first oil pipeline is built in the basin. 1920’s The mineral estate under TPL’s land was spun - off to its shareholders under a new company named TXL Oil. TPL reserved an NPRI under certain tracts of land. (1) 1954 Texaco purchased TXL Oil which at the time held over 2 million undeveloped acres in west Texas. 1962 Rapid development across much of TPL’s acreage leads to increased royalty revenues for the Trust. 2015 Chevron acquired Texaco for $36 billion, and now performs as an operator across a large portion of TPL’s Permian position. 2001 Conversion Committee formed to evaluate if the Trust should convert into a C - corporation. 2019 Texas & Pacific Railway is created and was granted ~3.5 million acres of land from the State of Texas. 1871 The Permian Basin begins to grow production as unconventional development unlocks tremendous additional reserves. 2010’s TPL announces formation of Texas Pacific Water Resources LLC (“TPWR”) (2) . 2017 TPL listed on NYSE. TPL is among the few Depression Era companies that continue trading today, almost a century later. 1927 $

 

 

| 11 NYSE: TPL Key Investment Highlights Sustained Profitability and Pristine Balance Sheet Focus on Return On and Of Capital ETF of the Permian Basin Near Term Visible FCF Growth ■ Largest royalty company with 100% of acreage located in Texas Permian Basin ■ Three high - margin businesses linked to the development intensity of the Permian – multiple “ways to win” ■ Unparalleled position consisting of ~23,600 net royalty acres (“NRAs") (1) and ~900,000 surface acres ■ TPL interest is focused in the Delaware where rig count represents over 25% of total horizontal rigs across the U.S. ■ 17 years of increasing dividends ■ Has repurchased 8.5% of shares since Jan. 2014 (2) ■ Corporate ROIC of 91% (3) ■ Growing free cash flow generation; 475% growth in free cash flow since 2016 year end ■ Robust 2019 EBITDA (4) margin of 82% ■ No capex for organic royalty or land business growth; minimal for water ■ No debt and cash balance of ~$304 million ■ Significant undeveloped potential: only 7% of royalty acreage is developed with ~22,100 gross undeveloped locations (8) ■ High concentration in what TPL believes is the best part of the Permian, with ~19 years of inventory under $40/bbl breakeven (9) ■ Water business in the early stages of development with multiple growth opportunities available ■ Surface in frontier areas provides upside as development core expands with enhanced D&C and technology Source: Company data, Bloomberg, RSEG and Enverus as of 12/31/19. (1) Net royalty acres defined as gross royalty acres (530,400) multiplied by the average royalty per acre (4.4%). (2) Based on 8.473mm sub - share certificates outstanding as of 1/1/14 and 7.756mm shares outstanding as of 12/31/19. (3) Return on Invested Capital (ROIC) per Bloomberg and defined as (Net Operating Profit after Taxes / Average Invested Capital) fro m 9/30/18 to 9/30/19. (4) 2019 EBITDA adjusted for land sales deemed significant and one - time ~$13 million costs related to a proxy contest to elect a new Trustee. Please see Appendix for reconciliations of non - GAAP financial measures to their most directly comparable GAAP measures. Synergistic Business Segments ■ Ownership of surface provides right - of - way for continued development across TPL’s footprint ■ Rights to water and ability to promote operational solutions promotes further growth of the royalty business ■ Upside exposure to water disposal revenues as Delaware Basin production growth persists Significant Upside ■ 89 rigs active on TPL royalty and surface acreage in 3Q’19 (5) ■ Acreage in the “Core” of the Permian with production growth of ~130% since 2018 (6) ■ 486 DUCs (7) are 34% higher than at YE 2018 and Permit (7) count remains robust at 304 – providing increased visibility on significant anticipated near - term cash flow growth ramp (5) Rigs active within 0.25 miles of company Royalty DSU acreage and Surface Acreage as per Enverus Rig Analytics as of 2/26/20. (6) Increase in daily average net well production from 1Q18 to 4Q19. (7) As of 12/31/19 per RSEG. (8) Gross drilling locations based on an average lateral length of 6,930 as per the expected DSU. (9) Based on total inventory with a breakeven less than $40 divided by 2018 spud count.

 

 

| 12 NYSE: TPL Significant Undeveloped Resource in Core Areas Land and Resource Management TPL Inventory by Breakeven to Working Interest Operator TPL Inventory by IRR to Working Interest Operator (2) Source: Company data and RSEG. Note: RSEG assumes no differential for oil and NGL, a $0.70 differential for gas, and NGL pricing at 25% of WTI. Excluding areas to be considered outside of basin. Excludes DUCs and Permits. Not showing locations with negative IRRs. (1) Based on total inventory with a breakeven less than $40 divided by 2018 spud count. (2) IRRs calculated at a flat price of $55.00/bbl and $2.75/mcf of oil and gas respectively. Northern Delaware Southeast Delaware Southwest Delaware Midland ~19 years of inventory life at current rig cadence with breakevens under $40/bbl (1) ~19 years of inventory life at current rig cadence with IRRs of greater than 38% Drilling locations Drilling locations $0 $10 $20 $30 $40 $50 $60 $70 Wellhead PV - 10 Breakeven ($/bbl) 0 1,999 3,998 5,996 7,995 9,994 11,993 13,992 15,990 17,989 19,988 0 1,999 3,998 5,996 7,995 9,994 11,993 13,992 15,990 17,989 19,988 0% 20% 40% 60% 80% 100% 120% Wellhead BTax IRR

 

 

| 13 NYSE: TPL 19.1% 17.9% 14.3% 13.0% 7.4% 6.0% 22.2% COMPs 17.5% 14.9% 13.8% 8.4% 7.5% 6.9% 5.5% 25.5% 15.5% 13.8% 9.1% 8.9% 7.1% 6.6% 1.5% 37.4% Summary of Highest - Visibility Inventory Land and Resource Management Source: Company data and RSEG. Note: Permian Basin horizontal locations only as of 12/31/19. (1) Permitted well conversion rate based on wells permitted from 1/1/18 through 12/31/18 and then drilled through 12/31/19. (2) DUC well conversion rate based on wells drilled from 1/1/18 through 12/31/18 and then completed through 12/31/19. (3) Completed well conversion rates based on wells completed between 1/1/18 and 12/31/18. (4) DUCs considered to be all wells awaiting completion. Highest - Visibility Inventory with Top Operators Validates TPL’s Near - Term Production Outlook Other Northern Delaware Other Midland Southeast Delaware Southwest Delaware 100% NRI Permitted Wells ~75% of Permits are drilled within 6 months (1) ~82% of Permits are drilled within 12 months (1) Permitted Wells: 4.3 100% NRI DUC Wells ~48% of DUCs are completed within 6 months (2) ~83% of DUCs are completed within 12 months (2) DUC Wells (4) : 7.0 100% NRI Completed Wells >90% of Completed Wells are listed as producing within ~1 month (3) Completed Wells: 3.1 ` NRI by Operator NRI by Region Permitted Wells: 4.3 Completed Wells: 3.1 DUC Wells (2) : 7.0 61.6% 30.2% 5.9% 2.2% 67.2% 25.3% 4.9% 2.6% 68.9% 15.3% 14.7% 0.6% 0.5%

 

 

| 14 NYSE: TPL Undeveloped Inventory Summary Land and Resource Management Source: Company data and RSEG. Note: Locations reflect additional undeveloped locations sorted by interval and oil estimated ultimate recovery (“EUR”). Permian Basin horizontal locations only. Inclusive of DUCs, Permits and additional undeveloped wells. (1) Gross EUR in mboe for Oil EUR and mboe for Total EUR based on RSEG type curves normalized to 7,500 ft. (1.5 miles) well. (2) Total locations inclusive of additional undeveloped locations, DUCs, and Permits. Northern Delaware Southeast Delaware Southwest Delaware Midland Other Undeveloped Gross Well Locations: 21,335 10,516 898 1,872 7,272 Undeveloped 100% Net Well Locations: 403 265 22 52 55 Diverse Permian Resource with Large Net Exposure to Oily, High - Return Northern Delaware 804 1,835 794 1,864 690 1,684 637 2,173 625 2,080 540 2,465 531 1,920 473 1,551 405 2,432 672 1,032 521 841 498 742 207 268 548 1,283 433 1,028 256 871 82 1,651 13 1,886 505 790 452 900 448 698 428 745 410 783 344 505 310 529 496 1,364 778 10 2,001 721 1,344 707 1,364 Weighted Average Total EUR Net Add. Undev. Locations Oil EUR (1) Total EUR (1) 24 / DSU Add. Undev. Locations (Total Locations + PDP) / DSU (2) 10 / DSU 14 / DSU 24 / DSU 7 / DSU Northern Delaware Southeast Delaware Southwest Delaware Midland Other 25 4 63 31 17 57 29 32 6 7 8 6 0 3 11 7 16 15 5 14 6 12 8 9 2 10 Wolfcamp XY 1st Bone Spring Wolfcamp A 3rd Bone Spring Avalon Upper Wolfcamp B 2nd Bone Spring Lower Wolfcamp B Wolfcamp C 3rd Bone Spring Wolfcamp A Upper Wolfcamp B 2nd Bone Spring Wolfcamp A Wolfcamp C Upper Wolfcamp B Woodford Barnett JoMill Wolfcamp A Lower Spraberry Wolfcamp B Wolfcamp C Middle Spraberry Wolfcamp D Other 968 183 2,405 1,251 639 2,286 1,188 1,302 294 290 334 259 14 94 398 222 595 563 1,019 1,745 718 1,528 784 1,245 233 778 Wolfcamp XY 1st Bone Spring Wolfcamp A 3rd Bone Spring Avalon Upper Wolfcamp B 2nd Bone Spring Lower Wolfcamp B Wolfcamp C 3rd Bone Spring Wolfcamp A Upper Wolfcamp B 2nd Bone Spring Wolfcamp A Wolfcamp C Upper Wolfcamp B Woodford Barnett JoMill Wolfcamp A Lower Spraberry Wolfcamp B Wolfcamp C Middle Spraberry Wolfcamp D Other

 

 

| 15 NYSE: TPL Comparison of Key Statistics Land and Resource Management Source: Company data, RSEG, public filings, Enverus as of 12/31/19. (1) TPL NRA is based on 4.4% average royalty interest per acre. VNOM NRA reported in February 2020 Investor Presentation. MNRL NRA is based on 18% average royalty interest per acre as reported in the MNRL 4Q’19 Investor Presentation. (2) Midland and Delaware only. TPL based on net resource (495 Mmboe) divided by NRA (18,956) where net resource is the product o f subregion gross resource and implied NRI. VNOM based on net resource (555 Mmboe) divided by NRA (23,623), as per February 2 020 Investor Presentation. (3) Based on only horizontal wells. TPL Dev figure represents PDP only. Net Royalty Acres (NRA) (1) Permian NRA % Delaware NRA % 10,000 ~23,600 100% ~80% Percent Undeveloped (3) ~36% ~31% 3,600 Highest Permian Resource Per Acre of All Permian Peers Due to High Concentration in Stateline Area 24,304 ~97% ~47% Net Permian Resource (mboe) / NRA (2) 26.1 23.5 NM Dev 30% Undev 70% Dev 21% Undev 79% Key E&P Operators Significant Surface Ownership Dev 7% Undev 93% x (Permian only) Dev 25% Undev 75% Dev 13% Undev 87% Midland Delaware

 

 

| 16 NYSE: TPL – 250 500 750 1,000 1,250 1,500 1,750 2,000 2,250 2,500 2,750 3,000 3,250 3,500 3,750 – $20 $40 $60 $80 $100 $120 $140 $160 $180 $200 $220 $240 1Q16 2Q16 3Q16 4Q16 1Q17 2Q17 3Q17 4Q17 1Q18 2Q18 3Q18 4Q18 1Q19 2Q19 3Q19 4Q19 Cumulative Horizontal Well Count Since 2016 (3) Cumulative SLEM Revenue since 2016($mm) (2) SLEM Revenue Well Count x Extensive position allows our surface to benefit from development occurring on and adjacent to TPL land ▪ Since 2018, SLEM revenue has represented ~20% of total TPL revenues (1) ▪ Generates majority of its surface revenue from easements related to pipeline infrastructure ▪ Generates lease and material (caliche) sale revenues in addition x Majority of easements have 30+ year term but subsequently renew every ten years with an additional payment (initial fee plus ~15%) Surface Leases, Easements and Material Sales (“SLEM”) Land and Resource Management Generates Multiple Long - Term Income Streams with No Opex TPL Has Averaged ~$60,000 in SLEM Revenue for Every Well Drilled On and Surrounding its Core Permian Surface Position (1) The TPL Surface Position Can’t be Replicated Amongst Royalty and Water Companies ~900,000 Surface Acres With a Concentration in Core Permian Areas Surface procurement TPL Caliche Pad E&P Lease Road to Operations on non - TPL Surface TPL Caliche Pit E&P Oil & Gas Facility on TPL Surface Solar Farm on TPL Surface TPL Caliche Pad TPL Caliche Pad SWD on non - TPL Surface Non - TPL Surface Acreage TPL Surface SWD on TPL Surface E&P Oil & Gas Facility on non - TPL Surface T h The pictu re can't be … TPL SLEM Revenue Tracks the Region’s Well Count Source: Company data and RSEG. (1) Total revenue adjusted for one - time land swap of $22mm in 2019 and one - time land / royalty sales of $100mm and $19mm in 2019 and 2018, respectively. (2) SLEM revenue represents TPL’s cumulative easements and other surface related income from 1/1/16 through 12/31/19. (3) Cumulative horizontal well count per RSEG in TPL’s Northern Delaware Region (~950,000 acres) and TPL’s Midland Region (~250, 000 acre region around TPL’s surface in East Ector, Midland, Upton and Glasscock Counties).

 

 

| 17 NYSE: TPL Active – Current Revenue TPL Surface Acreage Salt Water Disposal Wells Permitted/Permits in Progress – Growth Opp. 665 mbbl/d 1,390 mbbl/d Non - TPL Land Permits (2) ▪ Active: ▪ Permitted: 835 mbbl/d 720 mbbl/d Water Resources Asset Overview Water Services and Operations Salt Water Disposal Wells TPL Water Sourcing Infrastructure Disposed Water Volume Growth Sustained by Highest WOR Areas Source: Company data and RSEG. Note: TPL does not operate any water disposal wells. (1) Water oil ratio (“WOR”) defined as the ratio of 12 month cumulative water production to 12 month cumulative oil production. (2) Revenue received both on and off TPL surface based on existing contracts. Sourced Water Business Driven by High Fluid Intensity Areas Reeves Loving Ward Culberson Asset TPL Land Permits 2 ▪ Active: ▪ Permitted: 2,325 mbbl/d 2,895 mbbl/d Water Oil Ratio (1) 4:1 Capacity

 

 

| 18 NYSE: TPL 17% 6% 9% 24% 27% 39% 59% 67% 52% $9.8 $24.4 $34.2 4Q17 4Q18 4Q19 Treated Water & Other Produced Water Sourced Water – 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000 4,500 2018 2019 2020 2021 2022 2023 2024 Water Volumes (mbbls / d) Existing Regional Water Production (Estimated) Forecast Regional Water Production (Estimated) Current TPL Volumes (Actual through 2019) TPL 4Q19 N. Delaware Runrate (~890 mbbls/d) Active + Permitted SWD Capacity (Assumes 75% Utilization) Growth Strategy and Competitive Advantage Water Services and Operations Revenue Growth and Change in Mix (1) Significant Produced Water Upside Source: Company data. Note: Regional water volumes based on RSEG estimated water oil ratio, historic oil production and RSEG oil type curves. Historic volumes represent horizontal wells drilled since TPWR formation in Jun. 2017. Development pace based on average ~1,180 wells drilled in the region during LTM ending 12/31/19 and held flat. (1) Inclusive of water sales and royalties and water - related easements and other surface - related income. TPWR Formed in June 2017 ($ in millions) Past TPL Future Produced Water Capture Opportunity Future Royalty Based Business Model Captures Increased Disposal Volumes in Northern Delaware Focus Area Treatment and Reuse Opportunities Provide a Natural Hedge as Majors and Large Independents Balance Disposal vs. Treatment and Produced Water Volumes Continue to Build YoY 180% YoY 103%

 

 

| 19 NYSE: TPL Source: Company data and RSEG as of 12/31/19. Note: Northern Delaware Region is defined as approximately 1,400,000 acres surrounding TPL’s Northern Delaware Surface position including ~900,000 acres in Texas and ~500,000 acres in Southern New Mexico. Capture rate defined as TPL volumes as a percentage of total volumes in the Northern Delaware Region. Regional water volumes ba sed on RSEG estimated WOR, historic oil production and RSEG oil type curves. Historic volumes represent horizontal wells dri lle d since TPWR formation in Jun. 2017. Development pace based on average ~1,180 wells drilled in the region during LTM ending 12/31/19 and held flat. (1) TPL data is the average for 4Q’19; Regional produced water volumes based on RSEG estimated water production from wells drille d s ince TPWR formation (Jun. 2017) shown through 4Q’19 based on available data. (2) TPL data is the average sourced + treated volumes for 4Q’19; Regional sourced /treated water demand based on RSEG reported we ll fluid intensity volumes for wells completed in the Northern Delaware Region shown through 4Q’19 based on available data. TPL is a Market Leader for Water in the Northern Delaware Water Services and Operations Delaware Produced Water Volumes of ~890 mbbls/d at ~$0.12/bbl (1) Total Produced Water Volumes of ~1,050 mbbls/d at ~$0.12/bbl (1) Delaware Sourced Water Volumes of ~380 mbbls/d at ~$0.58/bbl (2) Total Sourced Water Volumes of ~410 mbbls/d at ~$0.56 / bbl (2) Royalty Based Business Model Captures Increased Sourcing and Disposal Volumes in Northern Delaware Focus Area TPL’s Established Footprint Allows Optionality with SWD Operators to Negotiate Increased Economics 2018 TPL Capture Rate = 25% 2019 TPL Capture Rate = 29% 0% 10% 20% 30% 40% 50% 60% 0 200 400 600 800 1,000 1,200 1,400 1,600 Jan-18 Apr-18 Jun-18 Sep-18 Dec-18 Mar-19 Jun-19 Sep-19 Dec-19 TPWR Capture Rate Completions Volumes (mbbls / day) Northern Delaware Region Volumes (Estimated) TPL Delaware Volumes (Actuals) TPL 2018 Capture Rate = 22% TPL 2019 Capture Rate = 30% 0% 10% 20% 30% 40% 50% – 500 1,000 1,500 2,000 2,500 3,000 Jan-18 Apr-18 Jun-18 Sep-18 Dec-18 Mar-19 Jun-19 Sep-19 Dec-19 TPWR Capture Rate Produced Volumes (mbbls / day) Northern Delaware Region Volumes (Estimated) TPL Delaware Volumes (Actuals) (1) (2) Provides Irreplaceable Additional Upside as Aquifer Runs Underneath TPL Land

 

 

| 20 NYSE: TPL $1 $3 $2 $18 $45 $30 $1 $19 $48 $32 2016 2017 2018 2019 0.3 0.4 0.6 1.1 1.8 2015 2016 2017 2018 2019 Summary of Financials Source: Company data. Note: Revenue was restated retrospectively upon adoption of new revenue reconciliation guidance on 1/1/18. CAGR defined as the c ompounded annual growth rate from 2014 to 2019. Please see Appendix for reconciliations of non - GAAP financial measures to their most directly comparable GAAP measures. (1) EBITDA adjusted for land sales deemed significant, sales of oil and gas royalty interests, and one - time costs related to a p roxy contest to elect a new Trustee in 2019. (2) Calculated as average daily net production during the year divided by the average number of sub - shares outstanding during ye ar. Net Production per Sub - Share Certificate (2) Adjusted EBITDA (1) ($ in millions) 96% 95% 95% 94% 87% 82% Margin: Capex by Business Segment ($ in millions) (mboe/d per mm sub - share certificates) $51 $55 $63 $145 $245 $302 2014 2015 2016 2017 2018 2019 Water Service and Operations Land and Resource Management

 

 

| 21 NYSE: TPL $2.0 $2.0 $4.3 $2.2 $2.4 $2.5 $10.7 $31.6 $46.6 $10.7 $16.0 $20.2 $25.2 $23.0 $28.8 $33.1 $34.2 $38.4 $4.3 $12.7 $18.0 $24.5 $25.2 $25.2 $31.2 $35.6 $44.9 $70.0 $50.9 $124.1 $79.53 $95.07 $94.21 $98.02 $92.90 $48.69 $43.35 $50.78 $65.08 $57.03 $55.14 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 1Q20 Announced Dividend Dividends Share Repurchases Average WTI Price Return of Capital to Shareholders Source: Company data and FactSet Note: Average WTI price shown for 1Q20 Announced Dividend period based on average price from 1/1/2020 to 2/24/2020. (1) Dividends for 2012 includes $2.2 million of dividends for 2013 which were paid in the fourth quarter of 2012. (2) 1Q20 dividend of $124.1 million based on $10 / share regular dividend and $6 / share special dividend announced on February 2 4, 2020 and 7.756 million shares outstanding. Cumulative Return of Capital ($ in millions, except average WTI prices) (1) (1) (2) Updated 2.24.20

 

 

| 22 NYSE: TPL An Unmatched Oil and Gas Investment Russell 2000 Index and Public North American Oil & Gas Companies Market Cap (1) $1.0bn or Greater EBITDA Growth (2) 10% or Greater Debt / EBITDA (3) 1.5x or Less ROIC (4) 40% or Greater >80% EBITDA Margin (5) Total Companies: 2,789 992 417 135 4 1 Oil & Gas Companies: 897 159 80 26 1 1 TPL Metrics: $6.1bn 23% (6) 0.0x ~91% ~82% (6) Source: Company data and Bloomberg as of 12/31/19. (1) Market cap as of 12/31/19. (2) EBITDA growth represents year over year growth based on last four reported quarters. (3) Debt as of last reported quarter. EBITDA represents LTM based on last four reported quarters. (4) Return on Invested Capital (ROIC) defined as (Net Operating Profit after Taxes / Average Invested Capital) based on last fou r reported quarters. (5) EBITDA margin represents LTM based on last four reported quarters. (6) Reflects adjusted EBITDA margin for 2019 and year over year 2019 vs. 2018 growth. Please see Appendix for reconciliations of non - GAAP financial measures to their most directly comparable GAAP measures. Sustained Profitability and Pristine Balance Sheet Focus on Return On and Of Capital ETF of the Permian Basin Significant Upside Synergistic Business Segments Near Term Visible FCF Growth Summary Investment Highlights Updated 2.24.20

 

 

Appendix

 

 

| 24 NYSE: TPL Texas Pacific Land Trust Team Track Record of Shareholder Value Creation Texas Pacific Land Trust Management Team Texas Pacific Water Resources Management Team Jeremy Smith VP, Business Development Tyler Glover CEO, Secretary and General Agent Robert J. Packer CFO and General Agent Sameer Parasnis Chief Commercial Officer Chris Steddum VP, Finance and Investor Relations Robert A. Crain EVP Mr. Packer has been the Chief Financial Officer at Texas Pacific Land Trust since December 2014 and has been its Co - General Agent since November 2016 Previously, Mr. Packer served as Accounting Supervisor for Texas Pacific Land Trust, a position he held since March 2011 Formerly, he was Controller at StarCrest Realty He is a Certified Public Accountant Mr. Parasnis joined Texas Pacific Land Trust in July 2019 from Stifel’s O&G investment banking team where he served as a Managing Director and Co - Head of E&P coverage Mr. Parasnis spent most of his 17+ years finance career in O&G investment banking at Credit Suisse and has also worked with GMP Securities and Citi He started his career as a chemical engineer with Reliance Industries Ltd. in 1996 Mr. Steddum came to Texas Pacific Land Trust from Stifel’s oil and gas investment banking team where he served as a Director Mr. Steddum began his investment banking career in the O&G coverage group at Credit Suisse He earned his MBA from Rice University and Bachelors of Science in Business Administration from the University of South Carolina Honors College Robert Crain has served as Executive Vice President of Texas Pacific Water Resources since its formation in June 2017 Prior to TPWR, Mr. Crain led water resource development efforts for EOG Resources across multiple basins, including the Permian and Eagle Ford Mr. Crain holds Bachelor of Science Degree from Texas State University and M.B.A. from University of Texas at Tyler Mr. Smith came to Texas Pacific Water Resources from EOG Resources where he negotiated water sourcing and purchasing agreements across the Permian Basin and the Eagle Ford Shale Prior to EOG, Mr. Smith led a successful real estate broker service Katie Keenan VP, Land and Legal Mrs. Keenan joined Texas Pacific Land Trust in January 2017 as Land Manager and transitioned into her role as Vice President, Land and Legal at Texas Pacific Water Resources in May 2019 Previously, Mrs. Keenan worked as a Landman for BHP Billiton in the Permian Basin She earned her law degree from the University of Oklahoma and is a licensed attorney in the State of Texas Mr. Glover has been Chief Executive Officer, Co - General Agent and Secretary at Texas Pacific Land Trust since November 2016 and President and Chief Executive Officer of Texas Pacific Water Resources since its formation in June 2017 Previously, Mr. Glover served as Assistant General Agent of the Trust and an independent landman in the Permian prior thereto

 

 

| 25 NYSE: TPL TPL Revenue Streams Through the Life Cycle of a Well Surface and Royalty Ownership Allow Steady Revenue Generation Through the Entire Life Cycle of Oil & Gas Development ■ Infrastructure for oil & gas development Initial Development Phase Drilling and Completion Phase Production Phase Typical Activities TPL Revenue Sources ■ Fixed fee payments for use of TPL’s surface to build infrastructure ■ Sale of materials (caliche) used in the construction of infrastructure ■ Sourced water volumes (1) ■ Development of gathering, transportation and processing infrastructure ■ Fixed price per barrel for providing brackish groundwater and / or treated produced water ■ Fixed fee payments for the use of TPL’s surface for a variety of midstream infrastructure requirements ■ Significant produced water volumes (gathering, treating and reuse, and disposing back into the ground) ■ Royalty interest on the oil & gas produced ■ Royalty per barrel (injection fee) for allowing saltwater disposal (SWD) on TPL lands Majority of Stable Revenue Streams are Royalty, or Fixed - Fee Payments, with Limited - to - No Capital Expenditure Burden 1 2 = Land and Resource Management = Water Services and Operations 3 (1) Sourced water is water used for oil and gas development (i.e. drilling and completions).

 

 

| 26 NYSE: TPL 1.7 2.7 3.3 5.1 8.8 13.7 0 2 4 6 8 10 12 14 16 2014 2015 2016 2017 2018 2019 Average Historical Production (mboe/d) Well Positioned Assets Attract Increasing Development Focus Land and Resource Management Source: Company data and RSEG. Note: TPL production growth giving effect to our portfolio of ~23,600 net royalty acres in the Permian Basin as of 12/31/19 as i f it had been owned since 1/1/14. (1) As of 12/31/19 per RSEG. DUC figures not limited to previously used 4 month disclosure criteria. DUCs considered to be all w ells awaiting completion. DUC values shown as of period end date. Horizontal wells only. (2) LTM defined as horizontal spuds from 12/31/18 to 12/31/19. Spud rate defined as the percent of LTM spuds in basin captured o n TPL acreage compared to the percent of basin acreage owned by TPL. Net Production Gross DUC Inventory (1) Last Twelve Month Spud Rate on TPL Royalty Acreage is 5x Higher than Midland and Delaware (2) Flattening PDP Decline Stabilizes the Growth Profile with Slower DUC Growth 71 107 121 319 362 486 0 100 200 300 400 500 600 2014 2015 2016 2017 2018 2019 Gross DUC Count

 

 

| 27 NYSE: TPL Average Additional Total PDP + Total Gross Undeveloped PDP + Total Average Lat. Sub-region (1) NRI NRA DSUs PDP DUCs Permits Undeveloped Locations Locations Resource (Mmboe) Locations / DSU Length (ft.) Northern Delaware 2.3% 9,090 505 997 231 150 10,516 10,897 11,894 17,674 24 6,312 Southeast Delaware 2.1% 2,125 101 92 25 12 898 935 1,027 676 10 6,553 Southwest Delaware 3.0% 5,112 132 5 – 1 1,872 1,873 1,878 1,969 14 5,336 Delaware 2.4% 16,328 738 1,094 256 163 13,286 13,705 14,799 20,318 20 6,205 Midland 0.5% 2,628 337 603 219 134 7,272 7,625 8,228 5,969 24 8,483 Other 1.8% 4,632 127 34 11 7 778 796 830 354 7 6,054 Total 1.7% 23,588 1,202 1,732 486 304 21,335 22,125 23,857 26,641 20 6,975 Summary of Full Inventory Land and Resource Management Total Gross Locations Undeveloped Gross Locations Source: Company data and RSEG. Note: Permian Basin horizontal locations only. 1,943 vertical wells excluded. Other areas include Eastern Shelf, Western Delawar e, and Central Basin Platform. Proved developed locations inclusive of PDP locations and completed locations. (1) Gross location values shown. (2) Calculated as 100% Net Royalty Acres divided by DSU Acres. (3) Net royalty acres defined as gross royalty acres (530,400) multiplied by the average royalty per acre (4.4%). (4) As of 12/31/19 per RSEG. DUCs considered to be all wells awaiting completion. (5) Gross undeveloped resource is based on average EUR for each sub - region multiplied by the total location count in the sub - reg ion grossed up by weighted average lateral length for region compared to RSEG type curve, which is normalized to 7,500’ ft. w ell . Additional volumes from vertical wells not captured in gross undeveloped resource. Established Production Base Grounded in Conservative Assumptions High Near - Term Cash Flow Outstanding Organic Resource Other: 778 Midland: 7,272 Southwest Delaware: 1,872 Southeast Delaware: 898 Northern Delaware: 10,516 Additional Undeveloped Locations: 21,335 PDP Wells: 1,732 DUC Wells: 486 Permitted Wells: 304

 

 

| 28 NYSE: TPL Southeast Delaware Southwest Delaware Northern Delaware 0% 20% 40% 60% 80% 100% 120% 140% 0 1,284 2,568 3,852 5,136 6,420 7,704 8,988 10,272 11,556 12,840 Wellhead BTax IRR $0 $10 $20 $30 $40 $50 $60 $70 0 1,284 2,568 3,852 5,136 6,420 7,704 8,988 10,272 11,556 12,840 Wellhead Breakeven ($/bbl) Significant Undeveloped Resource in Core Areas Land and Resource Management – Delaware High Concentration of Inventory in Active Regions Working Operator Inventory IRR (1) Working Operator Inventory Breakevens (1) % Developed % Undeveloped 9% 91% 0% 100 % 7% 93% ~25 years of inventory life at current rig cadence with breakevens under $40/bbl (2) Source: Company data and RSEG. Note: Excluding areas considered outside of basin. Developed inventory includes PDP only. (1) Excludes DUCs and Permits. (2) Based on total inventory with a breakeven less than $40 divided by 2018 spud count.

 

 

| 29 NYSE: TPL 0% 20% 40% 60% 80% 100% 120% 140% 0 728 1,456 2,184 2,912 3,640 4,368 5,096 5,824 6,552 7,280 Wellhead BTax IRR $0 $10 $20 $30 $40 $50 $60 $70 0 728 1,456 2,184 2,912 3,640 4,368 5,096 5,824 6,552 7,280 Wellhead Breakeven ($/bbl) Significant Undeveloped Resource in Core Areas Land and Resource Management – Midland High Concentration of Inventory in Active Regions Working Operator Inventory IRR (1) Working Operator Inventory Breakevens (1) % Developed % Undeveloped 7% 93% Midland ~7 years of inventory life at current rig cadence with breakevens under $40/bbl (2) Source: Company data and RSEG. Note: Excluding areas considered outside of basin. Developed inventory includes PDP only. (1) Excludes DUCs and Permits. (2) Based on total inventory with a breakeven less than $40 divided by 2018 spud count.

 

 

| 30 NYSE: TPL Gross Royalty Acres Royalty Key Terms Land and Resource Management Net Royalty Acres (Normalized to 1/8) Net Royalty Acres Drilling Space Units (“DSUs”) Implied Average Net Revenue Interest per Well Description How’s It Calculated ■ The full, undivided ownership of the oil, gas, and mineral underneath one acre of land ■ Total Texas Pacific Land Trust acreage 530,400 ■ Gross Royalty Acres standardized to 12.5% (or 1/8) oil and gas lease royalty ■ Gross Royalty Acres standardized on a 100% (or 8/8) oil and gas lease royalty basis ■ Areas designated in a spacing order or unit designation as a unit and within which operators drill wellbores to develop our oil and natural gas rights ■ Number of 100% oil and gas lease royalty acres per gross DSU acre ■ Gross Royalty Acres * Avg. royalty / (1/8) 186,701 = 530,400 * 4.4% / (1/8) ■ Gross Royalty Acres * Avg. royalty 23,588 = 530,400 * 4.4% ■ Total number of gross DSU acres 1,423,673 ■ Net Royalty Acres / Gross DSU Acres 1.7% = 23,588 / 1,423,673 Source: Company data and RSEG. Note: Other areas include Eastern Shelf, Western Delaware, and Central Basin Platform. (1) Excluding acres which are considered to be outside of Basin. Focus Area (1) Gross Royalty Acres Net Royalty Acres Average Royalty Gross DSU Acres Implied Average Net Revenue Interest per Well Northern Delaware 152,958 9,090 5.9% 397,135 2.3% Southeast Delaware 34,285 2,125 6.2% 101,993 2.1% Southwest Delaware 81,795 5,112 6.3% 168,459 3.0% Delaware 269,038 16,328 6.1% 667,587 2.4% Midland 150,434 2,628 1.7% 497,469 0.5% Other 110,928 4,632 4.2% 258,617 1.8% Total 530,400 23,588 4.4% 1,423,673 1.7%

 

 

| 31 NYSE: TPL Water Resources Overview Water Services and Operations Water Resources Provide “Royalty - Like” Injection Fees, while Promoting Operator Development on TPL Land Provides Critical Infrastructure for E&P Operators Full - Service Water Solutions for Permian Basin Oil & Gas Operations Producing Oil & Gas Wells Completions TPL Fresh/Brackish Water Storage TPL Water Supply Well TPL Treated Produced Water Storage Oil & Gas Facility Non - TPL Surface Acreage Salt Water Disposal Facility ■ TPL Surface ownership provides access to source water, disposal rights and right - of - way for critical water infrastructure ■ Strong relationships with E&P operators allow TPL to enter attractive contracts for sourcing, treatment and disposal ■ TPL is exposed to a royalty - like water revenue stream across entire Permian position, which is highlighted by the prolific Northern Delaware region Key Sourcing Contract Terms ■ Multiple Right of First Refusal, Take or Pay and Water Treatment contracts with blue chip operators − Includes several minimum volume commitments totaling ~100 mmbbls over next 2 – 5 years − Total contract coverage region exceeds 350,000 acres ■ Typical Terms range from 2 – 15 years − Sourcing prices average $0.50 - $0.60/bbl (1) − Treatment prices average $0.50 - $0.65/bbl (1) Key Disposal Contract Terms ■ TPL has 80+ SWDs contracts or LOUs with 5 to 10 - year terms including an option to extend on the majority − 35+ active SWDs (~955 mbbls/d capacity) − 62+ permitted SWDs (~2,265 mbbls/d capacity) − Option extensions typically include 15% price escalation ■ Disposal Royalties / Fees average $0.10 - $0.20/bbl Source: Company data. (1) Sourcing and Treatment prices shown represent average range; however, prices can vary significantly by region.

 

 

| 32 NYSE: TPL Historical Financial Summary Source: Company data. Year ended December 31, Three months ended, Year ended ($ in millions) 2016 2017 2018 1Q19 2Q19 3Q19 4Q19 December 31, 2019 Total Acres 887,553 887,698 902,177 892,627 901,939 901,862 901,787 901,787 Revenues: Oil and gas royalties $28.4 $58.4 $123.8 $33.2 $39.6 $38.3 $43.6 $154.7 Easements and other surface-related income 26.2 70.0 88.7 31.4 22.4 33.9 27.7 115.4 Water sales and royalties 8.1 25.5 63.9 23.0 20.4 21.6 20.0 85.0 Land sales 2.9 0.2 4.4 103.6 4.8 4.6 22.0 135.0 Sale of oil and gas royalty interests – – 18.9 – – – – – Other operating revenue 0.5 0.5 0.5 0.1 0.1 0.1 0.1 0.4 Total Revenues $66.1 $154.6 $300.2 $191.3 $87.3 $98.5 $113.4 $490.5 Expenses: Salaries and related employee expenses 1.4 3.8 18.4 6.5 7.7 8.5 12.3 35.0 Water service-related expenses – 0.5 11.2 4.6 5.7 5.1 5.4 20.8 General and administrative expenses 0.9 1.5 4.7 2.1 2.1 2.9 2.7 9.8 Legal and professional fees 0.9 3.5 2.5 1.8 7.9 5.6 1.1 16.4 Depreciation, depletion and amortization 0.0 0.4 2.6 1.2 1.5 2.6 3.6 8.9 Total operating expenses $3.2 $9.7 $39.4 $16.2 $24.9 $24.7 $25.1 $90.9 Operating income (loss) $62.9 $144.9 $260.8 $175.1 $62.4 $73.8 $88.3 $399.6 Margin (%) 95.2% 93.7% 86.9% 91.5% 71.5% 74.9% 77.9% 81.5% Other income, net 0.0 0.1 0.9 0.4 0.5 0.9 0.9 2.7 Income before income taxes $62.9 $145.0 $261.7 $175.5 $62.9 $74.7 $89.2 $402.3 Income tax expense 20.6 47.8 52.0 35.5 13.3 14.7 20.1 83.6 Net income $42.3 $97.2 $209.7 $140.0 $49.6 $60.0 $69.1 $318.7 Margin (%) 64.0% 62.9% 69.9% 73.2% 56.8% 60.9% 60.9% 65.0% Key balance sheet items: 2016 2017 2018 1Q19 2Q19 3Q19 4Q19 2019 Cash and cash equivalents $49.4 $79.6 $119.6 $113.3 $155.4 $249.9 $303.6 $303.6 Total debt – – – – – – – – Total capital 52.7 105.1 244.7 333.8 383.4 443.4 512.2 512.2 Total assets 59.4 120.0 285.1 404.9 463.6 522.0 598.2 598.2 Total liabilities 6.7 14.9 40.4 71.1 80.2 78.6 86.0 86.0

 

 

| 33 NYSE: TPL Non - GAAP Reconciliations Source: Company data. Note: Numbers may not foot due to immaterial rounding. (1) Land swap of ~$22 million in 4Q19, Land sale in Upton County in 1Q15 of ~$20 million and sale to WPX in 1Q19 of ~$100 millio n. (2) Sale of nonparticipating perpetual oil and gas royalty interest in approximately 812 net royalty acres (1/8 th interest) of ~$19 million. (3) Costs related to proxy contest to elect a new Trustee, settlement agreement and conversion exploration committee. TPL antici pates a partial reimbursement of costs under coverage provided by its director and officer insurance policy. (4) Excludes land sales deemed significant and sales of oil and gas royalty interests. Land and Resource Management Water Services and Operations Total Year Ended December 31, Three months ended, ($ in millions) 2014 2015 2016 2017 2018 1Q19 2Q19 3Q19 4Q19 December 31, 2019 December 31, 2019 December 31, 2019 Net income $34.8 $50.0 $42.3 $97.2 $209.7 $140.0 $49.6 $60.0 $69.1 $258.4 $60.3 $318.7 Adjustments: Income taxes 16.7 25.2 20.6 47.8 52.0 35.5 13.3 14.7 20.1 66.8 16.7 83.6 Depreciation, depletion and amortization 0.0 0.0 0.0 0.4 2.6 1.2 1.5 2.6 3.6 1.2 7.7 8.9 EBITDA $51.5 $75.3 $62.9 $145.4 $264.3 $176.7 $64.4 $77.3 $92.8 $326.4 $84.7 $411.2 Revenue $53.7 $78.1 $66.1 $154.6 $300.2 $191.3 $87.3 $98.5 $113.4 $363.3 $127.2 $490.5 EBITDA Margin 95.9% 96.4% 95.2% 94.0% 88.0% 92.4% 73.7% 78.5% 81.8% 89.8% 66.6% 83.8% Adjusted EBITDA: EBITDA $51.5 $75.3 $62.9 $145.4 $264.3 $176.7 $64.4 $77.3 $92.8 $326.4 $84.7 $411.2 Other Adjustments: Less: land sales deemed significant (1) - (19.8) - - - (100.0) - - (22.0) (122.0) - (122.0) Less: sale of oil and gas royalty interests (2) - - - - (18.9) - - - - - - - Add: proxy contests, settlement, and conversion exploration committee costs (3) - - - - - 0.6 6.7 4.9 0.8 13.0 - 13.0 Adjusted EBITDA $51.5 $55.5 $62.9 $145.4 $245.4 $77.3 $71.1 $82.2 $71.5 $217.4 $84.7 $302.1 Adjusted Revenue (4) $53.7 $58.3 $66.1 $154.6 $281.3 $91.3 $87.3 $98.5 $91.4 $241.3 $127.2 $368.5 Adjusted EBITDA Margin 95.9% 95.2% 95.2% 94.0% 87.2% 84.7% 81.4% 83.5% 78.2% 90.1% 66.6% 82.0%