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Texas Pacific Land (NYSE: TPL) lifts Q1 profit and adds Horizon’s Peter Doyle to board

Filing Impact
(High)
Filing Sentiment
(Neutral)
Form Type
8-K

Rhea-AI Filing Summary

Texas Pacific Land Corporation reported strong first quarter 2026 results, with total revenue of $236.8 million and net income of $142.9 million, or $2.07 per diluted share. Adjusted EBITDA was $181.4 million and free cash flow was $136.4 million, reflecting high-margin, capital-light operations.

Oil and gas royalty revenue reached $118.2 million on production of 37.1 thousand Boe per day, while Water Services and Operations generated $46.9 million of water sales and $33.5 million of produced water royalties. The company closed a data center–related land transaction with aggregate consideration of $42.5 million, recognizing $20.9 million of land sale revenue and a financing receivable, and declared a $0.60 per share quarterly dividend. The board entered into a Board Representative Agreement with Horizon Kinetics and appointed its co-founder Peter Doyle as a director and member of the strategic acquisitions committee, with re‑election expected at the 2026 annual meeting.

Positive

  • Strong Q1 2026 financial performance: revenue grew to $236.8 million from $196.0 million a year earlier, with net income rising to $142.9 million and free cash flow reaching $136.4 million, underscoring the high-margin, capital-light business model.

Negative

  • None.

Insights

Record-like Q1 growth, capital-light model and new strategic director are incrementally positive.

Texas Pacific Land delivered notable Q1 2026 expansion: revenue rose to $236.8 million from $196.0 million a year earlier, and net income increased to $142.9 million. Growth was broad-based across oil and gas royalties, water sales, produced water royalties and land sales.

The model remains highly cash generative, with Adjusted EBITDA of $181.4 million and free cash flow of $136.4 million, helped by low operating expenses and a capital-light royalty and surface portfolio. The data center–linked land sale and associated water agreement highlight emerging optionality in power and digital infrastructure.

Corporate developments also matter: the Board Representative Agreement with Horizon Kinetics and appointment of its co-founder Peter Doyle to the board and strategic acquisitions committee formally integrates the company’s largest shareholder into governance. Future disclosures around the November 2026 and May 2027 annual meetings may show how this influences capital allocation and growth initiatives.

Item 1.01 Entry into a Material Definitive Agreement Business
The company signed a significant contract such as a merger agreement, credit facility, or major partnership.
Item 2.02 Results of Operations and Financial Condition Financial
Disclosure of earnings results, typically an earnings press release or preliminary financials.
Item 5.02 Departure of Directors or Certain Officers; Election of Directors; Appointment of Certain Officers Governance
Key personnel changes including departures, elections, or appointments of directors and executive officers.
Item 7.01 Regulation FD Disclosure Disclosure
Material non-public information disclosed under Regulation Fair Disclosure, often investor presentations or guidance.
Item 9.01 Financial Statements and Exhibits Exhibits
Financial statements, pro forma financial information, and exhibit attachments filed with this report.
Total revenue $236.8 million Three months ended March 31, 2026
Net income $142.9 million Three months ended March 31, 2026
Diluted EPS $2.07 per share Three months ended March 31, 2026
Adjusted EBITDA $181.4 million Q1 2026 non-GAAP metric
Free cash flow $136.4 million Q1 2026 non-GAAP metric
Oil & gas royalty revenue $118.2 million Q1 2026
Data center land consideration $42.5 million Aggregate consideration; $20.9 million recognized as land sale revenue
Quarterly dividend $0.60 per share Declared May 5, 2026, payable June 15, 2026
Adjusted EBITDA financial
"Adjusted EBITDA(2) of $181.4 million"
Adjusted EBITDA is a way companies measure how much money they make from their core operations, like running a business, by removing certain costs or income that aren’t part of regular business activities. It helps investors see how well a company is doing without distractions from unusual expenses or gains, making it easier to compare companies or track performance over time.
Free cash flow financial
"Free cash flow(2) of $136.4 million"
Free cash flow is the amount of money a company has left over after paying all its expenses and investing in its business, like buying equipment or updating facilities. It shows how much cash is available to reward shareholders, pay down debt, or save for future growth. This helps investors understand if a company is financially healthy and able to grow.
produced water royalties financial
"Produced water royalties | $ | 33,529"
non-GAAP performance measures financial
"NON-GAAP PERFORMANCE MEASURES AND DEFINITIONS"
drilled but uncompleted wells ("DUCs") technical
"9.6 net drilled but uncompleted wells (“DUCs”)"
Board Representative Agreement regulatory
"entered into a Board Representative Agreement (the “Agreement”)"
Revenue $236.8 million vs $196.0 million in Q1 2025
Net income $142.9 million vs $120.7 million in Q1 2025
Diluted EPS $2.07 vs $1.75 in Q1 2025
Adjusted EBITDA $181.4 million vs $169.4 million in Q1 2025
Free cash flow $136.4 million vs $126.6 million in Q1 2025
Understanding 8-K Material Events →
0001811074FalseCHX00018110742026-05-052026-05-050001811074exch:XNYS2026-05-052026-05-050001811074exch:XCHI2026-05-052026-05-05


UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C.  20549

 
FORM 8-K

CURRENT REPORT
Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
 Date of report (Date of earliest event reported): May 5, 2026

Commission File Number: 1-39804
  
Exact name of registrant as specified in its charter:
TEXAS PACIFIC LAND CORPORATION

State or other jurisdiction of incorporation or organization:IRS Employer Identification No.:
Delaware75-0279735

Address of principal executive offices:
 2699 Howell Street, Suite 800 Dallas, Texas 75204
  
Registrant’s telephone number, including area code: 
214-969-5530
 
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions:
☐Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)
☐Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)
☐Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))
☐Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))
 
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 or Rule 12b-2 of the Securities Exchange Act of 1934.
 
Emerging growth company    ☐
 
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.    ☐

Securities registered pursuant to Section 12(b) of the Act:
Title of each classTrading Symbol(s)Name of each exchange on which registered
Common Stock
(par value $.01 per share)		TPLNew York Stock Exchange
NYSE Texas, Inc.



Item 1.01.Entry into a Material Definitive Agreement.
Board Representative Agreement

On May 5, 2026, Texas Pacific Land Corporation, a Delaware corporation (the “Company”), entered into a Board Representative Agreement (the “Agreement”) with Horizon Kinetics Holding Corporation (“Horizon Kinetics”) and Horizon Kinetics Asset Management LLC (together with Horizon Kinetics and collectively with their respective affiliates, including the HK Funds (as defined in the Agreement), “Horizon”). Pursuant to the Agreement, the Company has agreed to, among other things, nominate a designee of Horizon (the “HK Designee”) for election to the board of directors of the Company (the “Board”), subject to the approval of the nominating and corporate governance committee of the Board, at the Company’s 2026 annual meeting of stockholders (the “2026 Annual Meeting”). Pursuant to the Agreement, Peter Doyle has been selected as the HK Designee.

The foregoing description of the Agreement is qualified in its entirety by the full text of the Agreement, which is attached hereto as Exhibit 10.1 and is incorporated by reference herein.

Item 2.02.Results of Operations and Financial Condition.
The Company hereby incorporates by reference the contents of a press release announcing financial results for the three months ended March 31, 2026, which was released to the press on May 6, 2026. A copy of the press release is furnished as Exhibit 99.1 to this current Report on Form 8-K.

Item 5.02.
Departure of Directors or Certain Officers; Election of Directors; Appointment of Certain Officers; Compensatory Arrangements of Certain Officers.

Appointment of Director

On May 5, 2026, the Board appointed Peter Doyle to the Board. Mr. Doyle will stand for re-election at the 2026 Annual Meeting. Mr. Doyle was also appointed to serve on the strategic acquisitions committee of the Board.

Mr. Doyle is a co-founder and the Co-Chief Executive Officer of Horizon Kinetics (OTCQX: HKHC). He is a senior member of the Horizon Kinetics research team and a member of its investment committee and its board of directors. Mr. Doyle is also the President of Kinetics Mutual Funds, Inc., a series of investment companies managed by the Horizon Kinetics, and is a Co-Portfolio Manager for several other registered investment companies, private funds, and separately managed accounts. Mr. Doyle also serves as the Chairman and Co-Chief Executive Officer of FRMO Corp. (OTCID: FRMO). Previously, Mr. Doyle was with Bankers Trust Company (1985-1994) as a Senior Investment Officer, where he also served on the Finance, Utility and REIT Research sub-group teams. Mr. Doyle received a BS from St. John’s University and an MBA from Fordham University.

Mr. Doyle will receive the Company’s standard compensation for non-employee directors, which is described in the Company’s Definitive Proxy Statement on Schedule 14A filed with the Securities and Exchange Commission on September 26, 2025. Other than the Agreement described above, there are no arrangements or understandings between Mr. Doyle and any other person pursuant to which Mr. Doyle was named a director of the Company. Mr. Doyle does not have any direct or indirect material interest in any transaction or proposed transaction required to be reported under Item 404(a) of Regulation S-K.

Item 7.01.
Regulation FD Disclosure.
On May 6, 2026, the Company posted to the Company’s website at www.texaspacific.com an updated investor presentation to be used, in whole or in part, from time to time in meetings with investors and analysts. A copy of the updated investor presentation is furnished as Exhibit 99.2 to this Current Report on Form 8-K and is incorporated by reference herein. The Company included a link in the updated investor presentation (Exhibit 99.2) to a video of Tyler Glover, the Chief Executive Officer of the Company, and others discussing the Company. The video is also available on the Company’s website at www.TexasPacific.com.

On May 6, 2026, the Company issued a press release announcing the appointment of Mr. Doyle to the Board. A copy of the press release is furnished as Exhibit 99.3 to this Current Report on Form 8-K and is incorporated by reference herein.

The information included in this Item 7.01 of this Current Report on Form 8-K, including the attached Exhibits 99.1, 99.2, and 99.3 shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended (the “Exchange


Act”), or incorporated by reference in any filing under the Securities Act of 1933, as amended, or the Exchange Act, except as shall be expressly set forth by specific reference in such filing.
 
Item 9.01.
Financial Statements and Exhibits.
 
 (d)  Exhibits.
 
10.1
Board Representative Agreement, dated as of May 5, 2026.
    
99.1
Press release including financial results of Texas Pacific Land Corporation for the Three Months Ended March 31, 2026 and 2025.
99.2
Investor Presentation May 2026.
99.3
Press release dated May 6, 2026 (furnished pursuant to Item 7.01).
104Cover Page Interactive Data File (embedded within the Inline XBRL document).




SIGNATURE
 
Pursuant to the requirements of the Securities Exchange Act of 1934, the Company has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
 
 TEXAS PACIFIC LAND CORPORATION
  
   
Date: May 6, 2026By:/s/ Chris Steddum
  Chris Steddum
  Chief Financial Officer



Exhibit 99.1
logo_texas2a.jpg

TEXAS PACIFIC LAND CORPORATION ANNOUNCES FIRST QUARTER RESULTS
–Earnings Call to be Held Thursday, May 7, 2026 at 9:30 am CT
DALLAS, TX (May 6, 2026) – Texas Pacific Land Corporation (NYSE: TPL) (the “Company,” “TPL,” “we,” “our,” or “us”), one of the largest landowners in the State of Texas with surface and royalty ownership that provides revenue opportunities through the support of energy production, today announced its financial and operating results for the first quarter of 2026.
First Quarter 2026 Highlights
•Entered into an arrangement with a developer of a power generation plant to support data center operations. In conjunction with this arrangement, we sold land for aggregate consideration of $42.5 million pursuant to a financing arrangement with the developer, resulting in immediate recognition of $20.9 million in land sale revenue and the recording of a financing receivable. Additionally, we entered into a separate agreement to supply water to the project.

•On May 5, 2026, TPL’s board of directors (the “Board”) appointed Peter Doyle to the Board. Mr. Doyle is a co-founder and the Co-Chief Executive Officer of Horizon Kinetics, which, through various owned subsidiaries, is TPL’s largest shareholder.

•Oil and gas royalty production of 37.1 thousand barrels of oil equivalent (“Boe”) per day

•As of March 31, 2026, TPL’s royalty acreage had an estimated 5.8 net well permits, 9.6 net drilled but uncompleted wells (“DUCs”), and 5.2 net completed but not producing wells (“CUPs”), totaling 20.7 net wells.(1) TPL had 124.4 net producing wells as of March 31, 2026, and net producing wells added during the quarter had an average lateral length of approximately 10,650 feet.

•Land and Resource Management segment revenues of $153.6 million

•Water Services and Operations segment revenues of $83.3 million

•Consolidated net income of $142.9 million, or $2.07 per share (diluted)

•Adjusted EBITDA(2) of $181.4 million

•Free cash flow(2) of $136.4 million

•Quarterly cash dividend of $0.60 per share was paid on March 16, 2026

(1) Total may not foot due to rounding.
(2) Reconciliations of non-GAAP performance measures are provided in the tables below.

“For the first quarter of 2026, TPL’s core business performance remained strong, and we are closing in on significant milestones in our emerging opportunities in produced water desalination and land opportunities involving data centers and power generation,” said Tyler Glover, Chief Executive Officer of the Company. “TPL generated record quarterly revenue and net income this quarter, supported by robust volumes across oil and gas royalties, water sales, and produced water royalties. With our unhedged commodity position, we will fully capture the upside from elevated commodity prices. During the quarter, we completed a land sale related to a large-scale data center and power generation project. As part of that transaction, TPL secured a water supply agreement for the gas-powered generation and an option to provide additional water to the data center facility. The urgency amongst hyperscalers, AI labs, and developers to advance projects in West Texas has noticeably increased compared to a year ago, and our ongoing commercial conversations in this area are progressing well. In addition, our 10,000 barrel per day produced water desalination R&D test facility in Orla, Texas is nearing completion and is on track to receive its first inlet barrels in the coming weeks.”

1

Financial Results for the First Quarter of 2026 - Sequential

The Company reported net income of $142.9 million for the first quarter of 2026 compared to net income of $123.3 million for the fourth quarter of 2025.

Total revenues for the first quarter of 2026 were $236.8 million compared to $211.6 million for the fourth quarter of 2025. The increase in total revenues was primarily due to a $21.4 million increase in oil and gas royalty revenue and a $20.9 million increase in land sale revenue, partially offset by a $13.9 million decrease in water sales compared to the fourth quarter of 2025. The Company’s average realized price was $37.06 per Boe in the first quarter of 2026 compared to $29.33 per Boe in the fourth quarter of 2025, and the Company’s share of production was 37.1 thousand Boe per day for the first quarter of 2026 compared to 37.5 thousand Boe per day for the fourth quarter of 2025. Water sales decreased due to a decrease in both water sales volumes and pricing. TPL’s revenue streams are directly impacted by commodity prices and development and operating decisions made by its customers.

Total operating expenses were $54.5 million for the first quarter of 2026 compared to $62.3 million for the fourth quarter of 2025. The decrease in operating expenses was principally related to a $7.9 million decrease in depreciation, depletion and amortization expense and a $3.2 million decrease in water service-related expenses, partially offset by a $2.2 million increase in general and administrative expenses during the first quarter of 2026 compared to the fourth quarter of 2025.

Financial Results for the First Quarter of 2026 - Year Over Year

The Company reported net income of $142.9 million for the first quarter of 2026 compared to net income of $120.7 million for the first quarter of 2025.

Total revenues for the first quarter of 2026 were $236.8 million compared to $196.0 million for the first quarter of 2025. The increase in total revenues was primarily due to a $20.9 million increase in land sales, an $8.1 million increase in water sales, a $6.9 million increase in oil and gas royalty revenue, and a $5.8 million increase in produced water royalties during the first quarter of 2026 compared to the same period of 2025. The Company’s share of production was 37.1 thousand Boe per day for the first quarter of 2026 compared to 31.1 thousand Boe per day for the same period of 2025, and the Company’s average realized price was $37.06 per Boe for the first quarter of 2026 compared to $41.58 per Boe for the same period of 2025. Produced water royalties increased due to increased produced water volumes, and water sales increased due to both increased volumes and pricing. TPL’s revenue streams are directly impacted by commodity prices and development and operating decisions made by its customers.

Total operating expenses were $54.5 million for the first quarter of 2026 compared to $45.9 million for the same period of 2025. The increase in operating expenses was principally related to an increase of $3.2 million in water service-related expenses, an increase of $2.6 million in general and administrative expenses, and a $2.1 million increase in depreciation, depletion and amortization.

Quarterly Dividend Declared

On May 5, 2026, the Company’s Board of Directors declared a quarterly cash dividend of $0.60 per share, payable on June 15, 2026 to stockholders of record at the close of business on June 1, 2026.

Appointment of Director

On May 5, 2026, TPL’s Board appointed Peter Doyle to the Board. Mr. Doyle will stand for re-election at the 2026 Annual Meeting. Mr. Doyle was also appointed to serve on the strategic acquisitions committee of the Board. Mr. Doyle is a co-founder and the Co-Chief Executive Officer of Horizon Kinetics (OTCQX: HKHC).

2026 and 2027 Annual Meetings of Stockholders

The Company intends to hold its 2026 Annual Meeting of Stockholders on November 5, 2026 in Dallas, Texas. The Company also intends to hold its 2027 Annual Meeting of Stockholders on May 6, 2027. Additional details, including the deadlines for stockholder proposals, will be provided in the applicable proxy statements to be filed by the Company with the Securities and Exchange Commission (“SEC”) and in other filings the Company makes with the SEC.

2

Conference Call and Webcast Information

The Company will hold a conference call on Thursday, May 7, 2026 at 9:30 a.m. Central Time to discuss first quarter results. A live webcast of the conference call will be available on the Investors section of the Company’s website at www.TexasPacific.com. To listen to the live broadcast, go to the site at least 15 minutes prior to the scheduled start time in order to register and install any necessary audio software.

The conference call can also be accessed by dialing 1-877-407-4018 or 1-201-689-8471. The telephone replay can be accessed by dialing 1-844-512-2921 or 1-412-317-6671 and providing the conference ID# 13759098. The telephone replay will be available starting shortly after the call through May 21, 2026.

About Texas Pacific Land Corporation

Texas Pacific Land Corporation is one of the largest landowners in the State of Texas with approximately 881,000 acres of land, with the majority of its ownership concentrated in the Permian Basin. The Company is not an oil and gas producer, but its surface and royalty ownership provides revenue opportunities throughout the life cycle of a well. These revenue opportunities include fixed fee payments for use of the Company’s land, revenue for sales of materials (caliche) used in the construction of infrastructure, providing sourced water and/or treated produced water, revenue from the Company’s oil and gas royalty interests, and revenue related to saltwater disposal on the Company’s land. The Company also generates revenue from pipeline, power line and utility easements, commercial leases and temporary permits principally related to a variety of land uses including, but not limited to, midstream infrastructure projects and hydrocarbon processing facilities.

Visit TPL at www.TexasPacific.com.

Cautionary Statement Regarding Forward-Looking Statements

Certain statements in this news release are, and certain statements made on the related conference call may be, 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, that are based on TPL’s beliefs, as well as assumptions made by, and information currently available to, TPL, and therefore involve risks and uncertainties that are difficult to predict. Generally, future or conditional verbs such as “will,” “would,” “should,” “could,” or “may” and the words “believe,” “anticipate,” “continue,” “intend,” “expect,” and similar expressions or the negative of such terms identify forward-looking statements. Forward-looking statements include, but are not limited to, references to strategies, plans, objectives, expectations, intentions, assumptions, future operations, and prospects; statements regarding anticipated benefits of recent acquisitions or the Permian Basin’s future drilling inventory and energy resources; and other statements that are not historical facts. You should not place undue reliance on forward-looking statements. Although TPL believes that plans, intentions and expectations reflected in or suggested by any forward-looking statements made herein are reasonable, TPL may be unable to achieve such plans, intentions or expectations and actual results, and performance or achievements may differ materially from those set forth in the forward-looking statements due to a number of factors, including, but not limited to: the initiation or outcome of potential litigation; any changes in general economic and/or industry specific conditions; and the other risks discussed in TPL’s Annual Report on Form 10-K and its Quarterly Reports on Form 10-Q. You can access TPL’s filings with the SEC through the SEC’s website at www.sec.gov and TPL strongly encourages you to do so. These forward-looking statements are based only on information available to TPL and speak only as of the date hereof. Except as required by applicable law, TPL undertakes no obligation to update any forward-looking statements or other statements herein for revisions or changes after this communication is made.

Contact:
Investor Relations
IR@TexasPacific.com
3


FINANCIAL AND OPERATIONAL RESULTS
(unaudited)

Oil and Gas Activity

The table below provides financial and operational data by royalty stream:

Three Months Ended
March 31,
2026		December 31,
2025		March 31,
2025
Company’s share of production volumes (1):
Oil (MBbls)
1,345 1,320 1,123 
Natural gas (MMcf)
5,794 6,328 5,230 
NGL (MBbls)
1,028 1,078 807 
Equivalents (MBoe)
3,339 3,453 2,801 
Equivalents per day (MBoe/d)
37.1 37.5 31.1 
Oil and gas royalty revenue (in thousands):
Oil royalties$90,627 $74,998 $76,179 
Natural gas royalties9,803 3,856 17,561 
NGL royalties17,737 17,867 17,505 
Total oil and gas royalties$118,167 $96,721 $111,245 
Realized prices (1):
Oil ($/Bbl)
$70.57 $59.48 $71.05 
Natural gas ($/Mcf)
$1.83 $0.66 $3.63 
NGL ($/Bbl)
$18.65 $17.92 $23.46 
Equivalents ($/Boe)
$37.06 $29.33 $41.58 
(1)TermDefinition
BblOne stock tank barrel of 42 U.S. gallons liquid volume used herein in reference to crude oil, condensate or NGL.
BoeOne barrel of oil equivalent.
MBblsOne thousand barrels of crude oil, condensate or NGL.
MBoeOne thousand Boe.
MBoe/dOne thousand Boe per day.
McfOne thousand cubic feet of natural gas.
MMcfOne million cubic feet of natural gas.
NGLNatural gas liquids. Hydrocarbons found in natural gas that may be extracted as liquefied petroleum gas and natural gasoline.

4

Water Services and Operations Activity

The table below provides financial and operational data for water sales and produced water royalties:

Three Months Ended
March 31,
2026		December 31,
2025		March 31,
2025
Water volumes (in MBbls) (1):
Water sales73,747 92,072 71,264
Produced water royalties414,450 443,578 335,656
Water volumes in barrels per day (in MBbls/d) (2):
Water sales819 1,001 792
Produced water royalties4,605 4,822 3,730
Water revenue (in thousands):
Water sales$46,863 $60,733 $38,813 
Produced water royalties$33,529 $33,513 $27,700 
(1)MBbl = 1 thousand barrels of water.
(2)MBbl/d = 1 thousand barrels of water per day.
5


CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(in thousands, except share and per share amounts) (unaudited)


 Three Months Ended
 March 31,
2026		December 31,
2025		March 31,
2025
Revenues:
Oil and gas royalties$118,167 $96,721 $111,245 
Water sales46,863 60,733 38,813 
Produced water royalties33,529 33,513 27,700 
Easements and other surface-related income17,315 20,612 18,225 
Land sales20,944 — — 
Total revenues236,818 211,579 195,983 
Expenses:
Salaries and related employee expenses14,987 14,894 14,572 
Water service-related expenses14,287 17,523 11,126 
General and administrative expenses8,631 6,424 6,072 
Depreciation, depletion and amortization14,043 21,930 11,941 
Ad valorem and other taxes2,542 1,562 2,199 
Total operating expenses54,490 62,333 45,910 
Operating income182,328 149,246 150,073 
Interest expense(992)(690)— 
Other income, net2,228 3,209 4,321 
Income before income taxes183,564 151,765 154,394 
Income tax expense40,662 28,419 33,742 
Net income$142,902 $123,346 $120,652 
Net income per share of common stock
Basic$2.07 $1.79 $1.75 
Diluted$2.07 $1.79 $1.75 
Weighted average number of shares of common stock outstanding
Basic68,959,013 68,938,230 68,942,085 
Diluted69,009,942 69,020,805 69,017,541 

6


SEGMENT OPERATING RESULTS
(dollars in thousands) (unaudited)


 Three Months Ended
 March 31,
2026		December 31,
2025
Land and Resource ManagementWater Services and OperationsConsolidatedLand and Resource ManagementWater Services and OperationsConsolidated
Revenues:
Oil and gas royalties$118,167 $— $118,167 $96,721 $— $96,721 
Water sales— 46,863 46,863 — 60,733 60,733 
Produced water royalties— 33,529 33,529 — 33,513 33,513 
Easements and other surface-related income14,449 2,866 17,315 16,662 3,950 20,612 
Land sales20,944 — 20,944 — — — 
Total revenues153,560 83,258 236,818 113,383 98,196 211,579 
Expenses:
Salaries and related employee expenses7,558 7,429 14,987 7,457 7,437 14,894 
Water service-related expenses— 14,287 14,287 — 17,523 17,523 
General and administrative expenses5,495 3,136 8,631 3,966 2,458 6,424 
Depreciation, depletion and amortization9,194 4,849 14,043 17,276 4,654 21,930 
Ad valorem and other taxes2,530 12 2,542 1,551 11 1,562 
Total operating expenses24,777 29,713 54,490 30,250 32,083 62,333 
Operating income128,783 53,545 182,328 83,133 66,113 149,246 
Interest expense(793)(199)(992)(552)(138)(690)
Other income, net1,581 647 2,228 2,527 682 3,209 
Income before income taxes129,571 53,993 183,564 85,108 66,657 151,765 
Income tax expense28,648 12,014 40,662 15,566 12,853 28,419 
Net income$100,923 $41,979 $142,902 $69,542 $53,804 $123,346 
7

SEGMENT OPERATING RESULTS (Continued)
(dollars in thousands) (unaudited)


 Three Months Ended
 March 31,
2026		March 31,
2025
Land and Resource ManagementWater Services and OperationsConsolidatedLand and Resource ManagementWater Services and OperationsConsolidated
Revenues:
Oil and gas royalties$118,167 $— $118,167 $111,245 $— $111,245 
Water sales— 46,863 46,863 — 38,813 38,813 
Produced water royalties— 33,529 33,529 — 27,700 27,700 
Easements and other surface-related income14,449 2,866 17,315 15,336 2,889 18,225 
Land sales20,944 — 20,944 — — — 
Total revenues153,560 83,258 236,818 126,581 69,402 195,983 
Expenses:
Salaries and related employee expenses7,558 7,429 14,987 7,404 7,168 14,572 
Water service-related expenses— 14,287 14,287 — 11,126 11,126 
General and administrative expenses5,495 3,136 8,631 3,313 2,759 6,072 
Depreciation, depletion and amortization9,194 4,849 14,043 7,689 4,252 11,941 
Ad valorem and other taxes2,530 12 2,542 2,189 10 2,199 
Total operating expenses24,777 29,713 54,490 20,595 25,315 45,910 
Operating income128,783 53,545 182,328 105,986 44,087 150,073 
Interest expense(793)(199)(992)— — — 
Other income, net1,581 647 2,228 3,416 905 4,321 
Income before income taxes129,571 53,993 183,564 109,402 44,992 154,394 
Income tax expense28,648 12,014 40,662 23,858 9,884 33,742 
Net income$100,923 $41,979 $142,902 $85,544 $35,108 $120,652 

8

NON-GAAP PERFORMANCE MEASURES AND DEFINITIONS

In addition to amounts presented in accordance with GAAP, we also present certain supplemental non-GAAP performance measurements. These measurements are not to be considered more relevant or accurate than the measurements presented in accordance with GAAP. In compliance with the requirements of the SEC, our non-GAAP measurements are reconciled to net income, the most directly comparable GAAP performance measure. For all non-GAAP measurements, neither the SEC nor any other regulatory body has passed judgment on these non-GAAP measurements.

EBITDA, Adjusted EBITDA, and Free Cash Flow

EBITDA is a non-GAAP financial measurement of earnings before interest expense, taxes, depreciation, depletion and amortization. The purpose of presenting EBITDA is to highlight earnings without finance, taxes, and depreciation, depletion and amortization expense, and its use is limited to specialized analysis.

The purpose of presenting Adjusted EBITDA is to highlight earnings without non-cash activity such as share-based compensation and other non-recurring or unusual items, if applicable. Additionally, Adjusted EBITDA is a metric used by the compensation committee of our Board to evaluate the Company’s performance in determining the short-term and long-term incentive compensation of our executive officers on an annual basis. We calculate Adjusted EBITDA as EBITDA plus employee share-based compensation, less land sale with financing arrangement and pension curtailment and settlement gain, as applicable to the periods presented.

The purpose of presenting free cash flow is to provide investors a metric to measure the funds available for investing in future acquisitions and returning capital to our stockholders through dividends and share repurchases after current income tax expense and purchases of fixed assets. Additionally, free cash flow is a metric used by the compensation committee of our Board to evaluate the Company’s performance in determining the short-term and long-term incentive compensation of our executive officers. To calculate free cash flow, net income is adjusted by adding back income tax expense, depreciation, depletion and amortization and employee share-based compensation, less the cash outflows of current income tax expenses, land sale with financing arrangement, purchases of fixed assets and pension curtailment and settlement gain, as applicable to the periods presented.

We have presented EBITDA, Adjusted EBITDA, and free cash flow because we believe that these metrics are useful supplements to net income in analyzing the Company’s operating performance, ability to fund future acquisitions, ability to return capital to our stockholders and explaining how our executive officers are compensated. Our definitions of EBITDA, Adjusted EBITDA, and free cash flow may differ from computations of similarly titled measures of other companies.

The following table presents a reconciliation of net income to EBITDA and Adjusted EBITDA for the three months ended March 31, 2026, December 31, 2025, and March 31, 2025 (in thousands):
Three Months Ended
March 31,
2026		December 31,
2025		March 31,
2025
 Net income $142,902 $123,346 $120,652 
 Add:
Interest expense992 690 — 
Income tax expense 40,662 28,419 33,742 
Depreciation, depletion and amortization14,043 21,930 11,941 
 EBITDA 198,599 174,385 166,335 
 Add (deduct):
Employee share-based compensation3,742 3,756 3,083 
Land sale with financing arrangement(20,944)— — 
Adjusted EBITDA$181,397 $178,141 $169,418 

9

The following table presents a reconciliation of net income to free cash flow for the three months ended March 31, 2026, December 31, 2025, and March 31, 2025 (in thousands):

Three Months Ended
March 31,
2026		December 31,
2025		March 31,
2025
 Net income $142,902 $123,346 $120,652 
 Add (deduct):
Income tax expense 40,662 28,419 33,742 
Depreciation, depletion and amortization14,043 21,930 11,941 
Employee share-based compensation3,742 3,756 3,083 
Current income tax expense(37,078)(26,968)(32,954)
Land sale with financing arrangement(20,944)— — 
Purchases of fixed assets(7,348)(28,653)(8,966)
Decrease (increase) in accounts payable related to purchases of fixed assets430 (2,973)(942)
Free cash flow$136,409 $118,857 $126,556 

10
Texas Pacific Land Corporation NYSE: TPL Investor Presentation – May 2026 Exhibit 99.2

 

Disclaimers This presentation has been designed to provide general information about Texas Pacific Land Corporation and its subsidiaries (“TPL” or the “Company”). Any information contained or referenced herein is suitable only as an introduction to the Company. The recipient is strongly encouraged to refer to and supplement this presentation with information the Company has filed with the Securities and Exchange Commission (“SEC”). The Company makes no representation or warranty, express or implied, as to the accuracy or completeness of the information contained 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 Company and the data contained or referred to herein. Unless otherwise stated, statements in this presentation are made as of the date of this presentation, and nothing shall create an implication that the information contained herein is correct as of any time after such date. TPL reserves the right to change any of its opinions expressed herein at any time as it deems appropriate. The Company disclaims any obligations to update the data, information or opinions contained herein or to notify the market or any other party of any such changes, other than required by law. Industry and Market Data The Company has neither sought nor obtained consent from any third party for the use of previously published information. Any such statements or information should not be viewed as indicating the support of such third party for the views expressed herein. The Company shall not be responsible or have any liability for any misinformation contained in any third party report, SEC or other regulatory filing. The industry in which the Company operates is subject to a high degree of uncertainty and risk due to a variety of factors, which could cause our results to differ materially from those expressed in these third-party publications. Some of the data included in this presentation is based on TPL’s good faith estimates, which are derived from TPL’s review of internal sources as well as the third party sources described above. All registered or unregistered service marks, trademarks and trade names referred to in this presentation are the property of their respective owners, and TPL’s use herein does not imply an affiliation with, or endorsement 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 based on TPL’s beliefs, as well as assumptions made by, and information currently available to, TPL, and therefore involve risks and uncertainties that are difficult to predict. These statements include, but are not limited to, statements about strategies, plans, objectives, expectations, intentions, expenditures and assumptions and other statements that are not historical facts. When used in this document, words such as “anticipate,” “believe,” “estimate,” “expect,” “intend,” “plan” and “project” and similar expressions 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 in 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 concerning 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 document 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 the Company’s common stock 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 development 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 construed as 1) investment, financial, tax or legal advice, 2) a recommendation to buy or sell any security, or 3) an offer or solicitation to subscribe for or purchase any security. These materials do not consider the investment objective, financial situation, suitability or the particular need or circumstances of any specific individual who may receive or review this presentation, and may not be taken as advice on the merits of any investment decision. Although TPL believes the information herein to be reliable, the Company and persons acting on its behalf make no representation or warranty, express or implied, as to the accuracy or completeness of those statements or any other written or oral communication it makes, safe as provided for by law, and the Company expressly disclaims any liability relating to those statements or communications (or any inaccuracies or omissions therein). These cautionary statements qualify all forward-looking statements attributable to us or persons acting on our behalf. Non-GAAP Financial Measures In addition to amounts presented in accordance with generally accepted accounting principles in the United States of America (“GAAP”), this presentation includes certain supplemental non-GAAP measurements. These non- GAAP measurements are not to be considered more relevant or accurate than the measurements presented in accordance with GAAP. In compliance with requirements of the SEC, our non-GAAP measurements are reconciled to net income, the most directly comparable GAAP performance measure. In this presentation, TPL utilizes earnings before interest expense, taxes, depreciation, depletion and amortization (“EBITDA”), Adjusted EBITDA and free cash flow (“FCF”). TPL believes that EBITDA, Adjusted EBITDA and FCF are useful supplements as an indicator of operating and financial performance. EBITDA, Adjusted EBITDA and FCF are not presented as an alternative to net income and they should not be considered in isolation or as a substitute for net income. See Appendix for a reconciliation of these non-GAAP measures to net income, the most directly comparable financial measure calculated in accordance with GAAP. 2

 

2025 2026 1Q 2Q 3Q 4Q 1Q Selected consolidated financials ($MM): Oil and gas royalties 111.2$ 95.0$ 108.7$ 96.7$ 118.2$ Water sales 38.8 25.6 44.6 60.7 46.9 Produced water royalties 27.7 30.7 32.3 33.5 33.5 Easements and other surface income 18.2 36.2 16.7 20.6 17.3 Land sales - - 0.8 - 20.9 Total revenues 196.0$ 187.5$ 203.1$ 211.6$ 236.8$ Adj. EBITDA 169.4$ 166.2$ 173.6$ 178.1$ 181.4$ Adjusted EBITDA margin 86% 89% 85% 84% 77% % inc/(dec) - sequential Q/Q 5% (2%) 4% 3% 2% Free cash flow 126.6$ 130.1$ 122.9$ 118.9$ 136.4$ FCF Margin 65% 69% 60% 56% 58% % inc/(dec) - sequential Q/Q 2% 3% (6%) (3%) 15% Selected balance sheet data ($MM): Cash and cash equivalents 460.4$ 543.9$ 531.8$ 144.8$ 247.6$ Debt - - - - - Selected segment data ($MM): Land and Resource Management Revenue 126.6$ 128.5$ 122.3$ 113.4$ 153.6$ Adj. EBITDA 119.0 122.2 115.9 105.3 120.9 Net Income 85.5 86.6 80.8 69.5 100.9 Water Service and Operations Revenue 69.4$ 59.0$ 80.8$ 98.2$ 83.3$ Adj. EBITDA 50.5 44.0 57.8 72.8 60.5 Net Income 35.1 29.6 40.5 53.8 42.0 $71.05 $63.99 $65.14 $59.48 $70.57 1Q 2025 2Q 2025 3Q 2025 4Q 2025 1Q 2026 12.5 13.3 14.0 14.4 14.9 9.7 10.4 11.1 11.5 10.7 9.0 9.5 11.2 11.7 11.4 31.1 33.2 36.3 37.5 37.1 0.0 5.0 10.0 15.0 20.0 25.0 30.0 35.0 40.0 1Q 2025 2Q 2025 3Q 2025 4Q 2025 1Q 2026 Oil Gas NGL 792 482 775 1,001 819 0.0 200.0 400.0 600.0 800.0 1,000.0 1Q 2025 2Q 2025 3Q 2025 4Q 2025 1Q 2026 1Q 2026 Summary Financial and Operating Update 3 O&G Royalty Production Total Water Sales Volumes1 Oil Realizations Produced Water Royalty Volumes (mboe/d) (mbbl/d) ($/bbl) (mbbl/d) 3,730 4,248 4,357 4,822 4,605 2,000.0 2,500.0 3,000.0 3,500.0 4,000.0 4,500.0 5,000.0 1Q 2025 2Q 2025 3Q 2025 4Q 2025 1Q 2026 Notes: Adjusted EBITDA and Free Cash Flow are non-GAAP measures. See Appendix for reconciliations of these non-GAAP measures to net income. mboe/d: thousands of barrels of oil equivalent per day mbbl/d: thousands of barrels per day (1) Reflects sourced, treated produced, and brokered water sales volumes

 

(1%) 1% 15% 19% 29% -12% -2% 8% 18% 28% WTI SPY Nasdaq TPL fsfsdfsfs 4 $37 $78 $160 $258 $128 $209 $365 $307 $315 $322 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 $5 $19 $50 $60 $48 $61 $81 $99 $139 $159 $0 $20 $40 $60 $80 $100 $120 $140 $160 $180 $200 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 Value Creation Culture and Proven Performance Land & Resource Management Net Income ($ millions) Average Annual Total Return Since 2017 (Compounded annual return from 1/1/2017 to 12/31/2025) (Composite) WTI Oil S&P Oil & Gas E&P Index Ctrl + click to play Water Services & Operations Net Income ($ millions) Note: Annual total return data per Factset. Video can be accessed at https://texaspacific.com/tpl-intro

 

Unique Permian Basin Pure-Play $ $ Positioned to capture upside $687 Million 2025 Adjusted EBITDA Balance Sheet Strength No Debt Cash Balance of $248 Million ~28,000 Core Permian Net Royalty Acres ~881,000 Surface Acres Diversified Revenue Streams: Royalties, Water, and Surface 100% Permian Exposure Efficient conversion of revenues to cash $498 Million 2025 Free Cash Flow Robust Inventory of 914 DUCs and 468 Permits Decades of Cash Flow Runway Across Multiple Businesses ~390% Production growth since 2018 $$ 5Note: Operating data as of 12/31/2025. Balance sheet and well inventory data as of 3/31/2026.

 

$40 $80 $160 $234 $188 $278 $452 $415 $461 $498 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 Texas Pacific Land Corporation (NYSE: TPL) TPL by the Numbers1 Market Value ($MM) $30,128 Cash & Equivalents ($MM) $248 Debt ($MM) $0 Net Royalty Acres (100% net basis) ~28,000 Normalized to 1/8th ~224,000 Surface Acres ~881,000 2025 Adj. EBITDA Margin 86% 2025 FCF Margin 62% Average daily trading volume (1-yr avg) ~447,000 Free Cash Flow ($MM)FY 2025 Revenues ($MM)  One of the largest landowners in Texas with approximately 881,000 acres located in the Permian Basin  TPL was originally organized in 1888 as a business trust to manage the property of the Texas and Pacific Railway Company; for nearly 130 years, this management was mostly passive  In 2016, the Company embarked on a new strategy to maximize the value of its footprint through active management of surface and royalty interests  Today, the business consists of numerous high-margin, capital-light revenue streams linked to Permian oil and gas development – Oil and Gas Royalties: high-margin royalty revenue derived from oil and gas production with no capital and minimal operating expense burden – Surface Leases, Easements and Material (“SLEM”): monetizes 3rd party development activities occurring on surface and royalty acreage – Texas Pacific Water Resources (“TPWR”): supplies brackish and treated produced water for oil and gas activities and facilitates produced water disposal solutions Adjusted EBITDA ($MM) 62% 38% Land & Resource Management Water Service & Operations $798M $63 $145 $245 $302 $239 $388 $592 $541 $611 $687 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 6 Note: Adjusted EBITDA and Free Cash Flow are non-GAAP measures. See Appendix for reconciliations of these non-GAAP measures to net income. (1) Balance sheet data as of 3/31/2026. Market value and average daily trading volume as of 4/27/2026. Market value calculated using basic shares outstanding. Royalty acreage figures excludes out of basin assets.

 

TPL History and Evolution Bankrupt Railroad to Liquidating Trust (1871-2009) Modern Enterprise Texas & Pacific Railway bankruptcy leads to the formation of Texas Pacific Land Trust, where land grant assets were placed. Trust certificates are listed on NYSE 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 Mineral estate was spun-off to shareholders (TXL Oil). TPL reserved royalty interests on tracts under lease at the time. Texaco purchases TXL Oil in 1962 (Texaco acquired by Chevron in 2001) 1954 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 shale reserves 2010’s TPL forms Texas Pacific Water Resources LLC (“TPWR”) 2017 TPL sub-share certificates listed on NYSE. TPL is among the few Depression Era companies that continue trading today, almost a century later 1927 $ TPL’s reorganization to a C-Corp is completed 2021 New management team hired to focus on modernizing operations to actively drive value 2016 Shale Revolution (2010s) Professionalize corporate and operating functions; employ talented industry personnel Execute on a capital allocation approach predicated on maximizing shareholder value Actively pursue “next-gen” opportunities Deploy technology, software, and automation tools to create efficiencies, scale, and opportunities Expand on TPL’s unique position to consolidate high quality surface, water, and royalties/minerals in a value enhancing manner Ensure shareholders own among the best oil and gas assets anywhere in the world Strengthening TPL for Durable Success Over the Long Term 7

 

Unmatched Permian Footprint Combined With Premier Operators Royalty Acreage Combined Royalty & Surface Surface and Easement Acreage 37% 35% 28% Revenue Contribution1 (FY 2025) Super- majors Large-cap independents Other (1) Permian supermajors include Chevron, Exxon, ConocoPhillips, BP and their respective subsidiaries. Large-cap independents include independent energy companies in the S&P 500. Other includes all companies that do not fall under the other two criteria, primarily made up of publicly traded mid-caps and large privates. 8

 

~65,000 ~34,000 ~13,000 ~5,000 ~3,000 ~3,000 0 10,000 20,000 30,000 40,000 50,000 60,000 70,000 Permian Montney Eagle Ford Williston Anadarko DJ Permian Basin is a World-Class Resource Source: US EIA, OPEC, Baker Hughes, Enverus and Company data. Production figures represent 4Q 2025 averages. Note: mmbbl/d: millions of barrels per day Estimated Remaining Well Locations with <$60/bbl Breakeven Economics Permian dominates US shale activity due to attractive drilling economics combined with massive undeveloped well inventory Permian is a top-tier focus area for many energy super-major and large-caps with multi- basin portfolios Permian is a major contributor to global oil, natural gas, and NGL markets – Permian production would rank as one of the largest oil producing nations globally 3.3 4.4 5.9 1.5 2.6 3.2 3.4 4.1 6.7 7.2 9.3 10.0 Permian US ex- Permian OPEC Nigeria Kuwait Iran UAE Iraq Permian US ex- Permian Russia Saudia Arabia C R U D E (M M b b l/d ) N G Ls (M M b b l/d ) Permian vs Major Oil Producer Nations US Rig Counts by Oil Basin Delaware Midland 9 0 50 100 150 200 250 300 350 400 Permian Williston DJ-Niobrara Eagle Ford Cana Woodford

 

$13 $18 $24 $25 $25 $31 $36 $45 $70 $51 $202 $105 $335 $143 $376 $156 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 Dividends Share repurchases Capital Allocation Framework Focused on Maximizing Shareholder Value RETURN CAPITAL Return substantial amounts of capital through dividends and repurchases PROTECT CAPITAL Maintain strong balance sheet to preserve financial flexibility INVEST CAPITAL Balance capital returns with attractive, high-return opportunities No Debt $248M Cash $1 9 $5 0 $6 0 $4 8 $6 1 $8 1 $9 9 $1 39 $1 59 2017 2018 2019 2020 2021 2022 2023 2024 2025 $689 MM of cumulative net income since inception Surface and easement acquisitions Capital expenditures$229 million $213 million Water Services & Operations capex and related surface investments from 2017-2025 ($ in millions) Also generates significant SLEM cash flow Water Services & Operations Net Income ($ in millions) 10Note: Debt and cash balance as of 3/31/2026. Undrawn $500M Credit Facility

 

$2.29 $3.34 $2.69 $3.99 $6.49 $6.01 $6.68 $7.22 $- $1.00 $2.00 $3.00 $4.00 $5.00 $6.00 $7.00 $8.00 $9.00 2018 2019 2020 2021 2022 2023 2024 2025 Focused on Allocating Capital Towards Highest Returns Growing Free Cash Flow per Share is the Key to Generating Value Growing free cash flow per share would further expand TPL’s capacity to return more capital to shareholders via buybacks and dividends Other Dividends Share Repurchases Acquisitions & Investments Capital Expenditures We believe the key to maximizing shareholder value is to maximize intrinsic value per share, which can also be expressed by long-term free cash flow per share Extract maximum value from legacy assets TPL FY 2025 Capital Allocation Share repurchases Organic opportunities M&A Employ highly-capable personnel, cultivate value-add culture, and deploy technology to maximize commercial potential and operating efficiency Buyback shares of TPL when intrinsic value is not being fully recognized in the market Buy 3rd party-owned surface, water, and/or royalty/mineral assets of similar or better quality to TPL’s legacy base at valuations that generate attractive returns Utilize our expertise, personnel, and legacy asset base to make strategic, high-return investments TPL Free Cash Flow per Share 11Note: Free Cash Flow is a non-GAAP measure. See Appendix for reconciliation of this non-GAAP measure to net income.

 

63% 72% 100% (31%) (45%) (60%) (40%) (20%) 0% 20% 40% 60% 80% 100% SLEM Produced Water Water Sales WTI Oil Henry Hub Natural Gas TPL’s Unique Combination of Surface and Royalties SURFACE WATER ROYALTIES Performance – FY 2025 versus FY 2022 TPL Revenue Spot Prices 12 ― ― ― Comparison of Significant Revenue Generation by Asset Type Effective commercialization of surface ownership provides (i) incremental enterprise cash flow and (ii) built-in hedges to oil and gas royalties’ direct exposure to commodity price volatility minimal (<1 mbo/d1) (1) mbo/d: thousands of barrels of oil per day Substantial surface and water related revenue growth despite O&G price declines since FY 2022 ― ― ― ― ― ―

 

TPL Maintains Top Tier Profitability Margins 8% 18% 13% 15% 52% 60% Oilfield Services (OIH) Midstream (ENFR) S&P O&G (XOP) S&P 500 TPL Water Services & Operations TPL consolidated Net Income Margin Comparison Source: Bloomberg and Company data. Note: OIH, ENFR, XOP, and S&P 500 data reflects last-twelve-months actuals as of February 2026. Figures for OIH, ENFR, XOP, and S&P 500 represent constituent equal-weighted averages; excludes constituents with negative net income margins. Histogram excludes S&P 500 constituents with negative net income margins. Consolidated TPL TPL Water Services & Operations Net Income Margin N u m b er o f C on st it u en ts 0 20 40 60 80 100 120 Net Income Margin Distribution for S&P 500 Constituents Consolidated TPL 60% FY 2025 net income margin TPL Land & Resource Management 66% FY 2025 net income margin TPL Water Services & Operations 52% FY 2025 net income margin TPL Water Services & Operations 13

 

TPL Water Sales Volumes (mbbl/d) 21.3 23.5 26.8 34.6 0.0 5.0 10.0 15.0 20.0 25.0 30.0 35.0 40.0 2022 2023 2024 2025 462 563 736 763 0 100 200 300 400 500 600 700 800 900 2022 2023 2024 2025 1,957 2,510 3,435 4,292 0 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000 4,500 5,000 2022 2023 2024 2025 Capital Efficient Growth Through the Commodity Cyle 14 TPL O&G Royalty Production (mboe/d) TPL Produced Water Royalties Volumes (mbbl/d) +29% 2025 YOY Growth +4% 2025 YOY Growth +25% 2025 YOY Growth +17% 3-yr CAGR +18% 3-yr CAGR +30% 3-yr CAGR $95 $78 $76 $65 $0 $10 $20 $30 $40 $50 $60 $70 $80 $90 $100 2022 2023 2024 2025 (15%) 2 25 YOY Growth (12%) 3-yr CAGR Oil Prices (WTI Cushing Spot, $/bbl) Countercyclical growth achieved without issuing debt or equity1 (1) Excluding shares related to employee compensation

 

Permian Activity Overview 15 2,040 868 646 2,399 1,000 658 2,272 951 769 0 500 1000 1500 2000 2500 3000 3500 ≤ 6 months 6 months < x ≤ 1.5 years 1.5 years < x ≤ 4 years 2025 2024 2023 - 1.0 2.0 3.0 4.0 5.0 6.0 7.0 1,504 1,528 1,486 1,485 1,475 1,481 1,567 1,423 1,340 4Q 2023 1Q 2024 2Q 2024 3Q 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 4Q 2025 ≤ 6 months 6 months < x ≤ 1.5 years > 1.5 years 1,687 2,000 2,002 1,936 1,840 1,759 1,770 1,556 1,811 1Q 2024 2Q 2024 3Q 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 4Q 2025 1Q 2026 Delaware Midland Permian Other Permian Well PermitsPermian Horizontal Rig CountsPermian Oil Production Permian Completion Counts (Grouped by DUC age at completion date) (mmbbl/d) 301 302 294 289 289 273 238 230 222 1Q 2024 2Q 2024 3Q 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 4Q 2025 1Q 2026 DUCs as of December 31, Permian DUC Counts (Historical counts and grouped by age) Source: US EIA, OPEC, Baker Hughes, Enverus and Company data Notes: DUC = Drilled-but-Uncompleted Well. DUC counts based on well activity date stamps. DUC Counts and Completion Counts for 1Q 2026 not shown due to incomplete industry data.

 

Investment Highlights 16 Permian Basin is a world class resource – Midland and Delaware Basins each possess tens of thousands of future undrilled well inventory Unique combination of surface and royalty ownership generates revenue throughout the entire lifecycle of a well Disciplined, value-creation approach to capital allocation: focus on maximizing both intrinsic value and free cash flow per share Talented, experienced team of domain experts: land asset managers, water business development and operations, reservoir engineers, GIS, information technology, and corporate personnel critical to extract maximum value Efficient conversion of revenues to cash flow – FY 2025 EBITDA and FCF margin of 86% and 62%, respectively Significant investments into technology enhance productivity and provide platform to scale efficiently Attractive opportunities to extract additional value from legacy asset base and from strategic investments in growth Dedication to optimizing capital allocation towards highest-returns, with a commitment to growing capital returns through dividends and buybacks

 

17 Jay Gould Founder - Texas and Pacific Railway

 

18 Orla Field Camp for survey team (June 1930) Survey team (June 1930) El Capitan peak – Culberson County Survey marker (northwest corner of Section 39, Block 62, Township 2) Survey team in sand dunes near Guadalupe Mountains “Old Red” Camp Delaware

 

TPL Currently Has Four Primary Revenue Streams O&G Royalties Revenue  Primarily own Non-Participating Royalty Interests (NPRI), which represents a real property right and is entitled to a fixed percentage of oil and gas production on a property  Royalties are not burdened by capital expenditures (e.g., drilling and completions costs), or most operating expense (e.g., lease operating expense)  Revenue stream contained in Land & Resource Management segment  Surface acreage provides multiple income streams from leases, easements, and caliche/materials, among others  Opportunity for new revenue streams from emerging technologies (e.g., solar, wind, and carbon capture)  Majority of SLEM revenues flow into Land & Resource Management segment, with a relatively smaller amount in Water Services & Operations  Facilitates disposal of water produced from oil and gas wells  By allowing use of its surface acreage for produced water disposal infrastructure, TPL generates a volumetric royalty fee on produced water barrels  TPL does not own or operate produced water disposal wells  Revenue stream contained in Water Services & Operations $28 $58 $124 $155 $138 $286 $452 $357 $373 $412 O&G ROYALTIES SURFACE LEASES, EASEMENTS AND MATERIAL (“SLEM”) WATER SALES PRODUCED WATER ROYALTIES  Surface acreage provides ownership of water rights and opportunities to supply brackish and treated produced water for use in oil and gas well development  TPL owns and operates a network of water wells, storage/frac ponds and pipelines that can source and deliver water to customers  Revenue stream contained in Water Services & Operations $26 $42 $71 $76 $41 $38 $48 $71 $73 $92 SLEM Revenue $8 $26 $64 $85 $55 $68 $85 $112 $151 $170 Water Sales $0 $6 $17 $39 $51 $58 $72 $84 $104 $124 Produced Water Royalties Revenue of Consolidated Revenues (FY 2025) 52% of Consolidated Revenues (FY 2025) 11% of Consolidated Revenues (FY 2025) 21% of Consolidated Revenues (FY 2025) 16% 19 ($ in millions) ($ in millions) ($ in millions) ($ in millions)

 

Oil and Gas Royalties Overview and Management TPL Producing Horizontal Wells (Net) by OperatorRevenue Mechanics and Management By interfacing directly with operators across SLEM and Water, TPL incentivizes operators to accelerate development on TPL’s royalty acreage Advocate for royalty ownership during disputes (e.g., revenue deductions, pricing realization, ad valorem payments, etc) Experienced reservoir engineers leverage TPL’s proprietary data for internal initiatives and evaluation of external opportunities Actively monitor check stub accuracy and compliance Internally developed software applications that integrate proprietary and third-party data and software, GIS systems and capabilities, and other tools to help drive further automation, efficiency, and effectiveness Continuously screening for operator well activity updates and utilizing that data to cross-sell TPL services How TPL is Delivering Value Oil and gas royalties represent real property interests entitling the owner to a portion of the proceeds derived from the production of oil and gas TPL receives a percentage of gross revenues from oil and gas wells drilled on TPL royalty acreage Royalties are not burdened by capital costs or most operating expenses (although natural gas and NGLs may have a small set of allowable deductions) associated with well development Mineral and royalty interests exist into perpetuity Overriding royalty interests (“ORRIs”) can be an exception as they are generally tied to leases and may not exist into perpetuity (TPL owns de minimis amount of ORRIs) Responsibility of royalty owner to (i) verify “decimals” (i.e., revenue interest); (ii) ensure timely pay; (iii) inspect check stubs for production, pricing, and deductions accuracy, (iv) track development status of pre-production wells, (v) extract and analyze well reservoir performance 20 Note: Company data as of 12/31/2025. PDP: proved developed producing FY 2025 Production Volume Splits Net PDPs: 116.1 Other 39% 31% 30% Oil Natural Gas NGLs

 

45.0 47.1 47.8 50.1 52.4 54.5 59.3 62.3 64.3 68.4 71.1 74.7 76.6 13.4 14.5 14.0 16.2 16.8 17.7 18.8 23.4 24.7 25.7 27.4 38.9 45.1 59.4 62.6 62.8 67.2 70.2 73.3 79.2 86.8 90.2 95.4 100.5 116.1 124.4 10.00 30.00 50.00 70.00 90.00 110.00 130.00 1Q 2023 2Q 3Q 4Q 1Q 2024 2Q 3Q 4Q 1Q 2025 2Q 3Q 4Q 1Q 2026 Delaware Midland Permian Other TPL Royalty Production and Inventory Detail 0% 20% 40% 60% 80% 100% 120% 140% 1Q 2023 2Q 3Q 4Q 1Q 2024 2Q 3Q 4Q 1Q 2025 2Q 3Q 4Q 1Q 2026 Oil as % of WTI Gas as % of Henry Hub NGLs as % of WTI 5.0 4.9 6.7 4.5 5.1 6.3 6.9 6.4 5.9 6.0 6.1 5.6 5.8 7.8 8.2 7.9 9.7 10.3 9.5 11.8 13.2 12.9 11.1 9.9 9.8 9.6 3.3 2.3 5.2 2.8 2.2 4.0 3.4 3.0 5.4 5.1 3.1 4.0 5.2 16.1 15.4 19.8 17.0 17.6 19.8 22.1 22.6 24.3 22.2 19.0 19.5 20.7 0.0 5.0 10.0 15.0 20.0 25.0 1Q 2023 2Q 3Q 4Q 1Q 2024 2Q 3Q 4Q 1Q 2025 2Q 3Q 4Q 1Q 2026 Permits DUCs Completed 1.7 2.7 3.3 5.1 8.8 13.7 16.2 18.6 21.3 23.5 26.8 34.6 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 2024 2025 TPL Net Royalty Production (mboe/d) TPL Average Lateral Lengths (feet) – New Spuds1 TPL Commodity Price Realizations vs Benchmarks 9,757 10,134 10,347 11,034 10,912 11,315 12,058 2019 2020 2021 2022 2023 2024 2025 21 TPL Producing Wells (net)TPL Inventory (net) Note: Totals may not foot due to immaterial rounding (1) Enverus well data as of 03/31/2026.

 

22 TPL source water infrastructure

 

23 TPL source water pond

 

RAW LAND DOES NOT MONETIZE ITSELF (i) Operational and legal expertise of surface estate ownership within the oil and gas industry and (ii) proactive execution are requisite towards extracting substantial cash flow from raw land Surface Estate Ownership Leveraging Ownership of Raw Surface into Cash Flow  Unlike O&G royalties, there is no statutory revenue / lease / royalty rate for activities that occur within a surface estate  Revenue opportunities require continual pursuit, negotiation, and commercialization $386MM FY 2025 Revenue 48% of TPL consolidated revenue Surface estate ownership allows for control over surface access, aquifers, and sub-surface pore space TPL derives three major revenue streams from its surface estate ownership SLEM Water Sales Produced Water  Revenue derived by providing customers access-to or use-of TPL surface  Revenue sources include pipeline easements, wellbore easements, commercial leases, and caliche/sand/materials sales  Renewables and various “next generation” opportunities, including grid-connected batteries and carbon capture, provide additional potential for revenue growth  TPL owns and operates infrastructure to provide water for use in oil and gas development activities  TPL provides both brackish groundwater and recycled/treated water for customers both on and off TPL surface  Operated model allows for sustainable management of aquifer resource  TPL provides surface access to operators and midstream companies for necessary infrastructure  TPL receives a volumetric royalty payment for produced water barrels that move across or are injected into TPL surface and has offtake rights to treat and resell produced water  TPL does not own or operate produced water disposal wells 1 2 3 Aggregate Contribution From Surface Estate + Active Management 24

 

47% 10% 19% 12% 12% Surface, Leases, Easements and Materials (SLEM) Overview and Management $78MM Pipeline easements Caliche / materials Commercial leases Wellbore easements Other Provide operators/customers access-to or use- of TPL surface for infrastructure and materials TPL utilizes standardized forms and payment structures and delivers quick turnaround to operator customers TPL easements typically have initial 10-year term with additional 10-year renewal options for the life of the infrastructure Easement renewal payments generally the greater of 115% or CPI-escalation from the previous easement payment Installed infrastructure tends to be long-lived and/or permanent Amount of revenue opportunities generally correlates to development activity in the Permian Leveraging technology such as advanced GIS, satellite imaging, and automation tools to monitor surface activity Experienced, specialized land asset managers dedicated to all aspects of surface commercialization provide consistent operator interaction, contract execution, and trespass monitoring New activity developments on TPL land is shared across business groups for lead generation and revenue opportunities Employs numerous personnel focused on identifying and developing opportunities for new revenue streams Before active management, operators often trespassed and/or underpaid for activities on TPL land How TPL is Delivering ValueTPL SLEM Revenue Breakdown (FY 2025) Term Easement Renewals Schedule (FY 2026-2035)1 Revenue Mechanics and Management 25 $- $25 $50 FY 2036-2045 will feature term easements potential renewals from (i) 2nd 10- year extension of 2016-2025 term easement vintages and (ii) 1st 10-year extension of 2026-2035 term easement vintages ($ in millions) Represents potential $250+M renewal revenue from term easements executed in 2016-2025 (1) Estimated values assumes annual 2% CPI escalator post-2025. Assumes all term easements renew.

 

TPL has developed the largest source water infrastructure network in the northern Delaware Basin TPL deploys professional hydrologists, advanced sensors, and monitoring systems to ensure aquifers are managed sustainably Sales team competes actively throughout the basin to leverage TPL water capabilities, while dedicated operations team ensures delivered water assurance and performance Provides water for development of oil and gas wells on TPL royalty acreage, while also securing significant water sales outside of TPL acreage Ability to provide both brackish and treated/recycled water solutions Water Sales provides substantial incremental cash flow to the overall enterprise Water Sales Overview and Management 44 258 371 369 414 462 563 736 763 2017 2018 2019 2020 2021 2022 2023 2024 2025 Surface estate ownership includes access to water aquifers O&G upstream/E&P operators use water to complete (i.e., “frac”) wells TPL develops, owns and operates infrastructure to extract, store, and transport brackish and treated produced water for oil and gas activities TPL provides recycled/treated produced water for reuse in completion activities Sales price per barrel generally ranges from $0.50 - $1.00 versus a direct operating expense per barrel of $0.10 - $0.20; pricing and expenses dependent on services provided, location, transportation costs, and other factors Annual maintenance capital of ~$10 – $20 million How TPL is Delivering ValueTPL Water Sales Volumes1Revenue Mechanics and Management (mbbl/d) 26 (1) Reflects sourced, treated produced, and brokered sales volumes

 

Water Sales Asset Map storage capacity 900+ mbbl/d ~38 mmbbl source water pipelines482 miles 331 357 393 413 426 455 481 488 522 - 100 200 300 400 500 600 2017 2018 2019 2020 2021 2022 2023 2024 2025 Average Fluid Used per Delaware Well Completion Average O&G well in the Delaware requires an increasing volume of water (~500k bbl water per well) TPL has developed and currently operates the largest source water infrastructure network in the northern Delaware TPL sells substantial water both on and off of TPL acreage TPL Source Water Network 27 Notes: Enverus and Company data as of 12/31/2025. (mbbls) sourced & produced water treatment capacity

 

Intentionally commercialized to generate high- quality, high-margin cash flow stream Facilitating produced water solutions allows operators to execute on upstream O&G development plans TPL undertakes conservative approach to siting produced water infrastructure on TPL land; focus on sustainable management of pore space resource and other environmental and geologic factors Negotiated agreements with operators covering ~450,000-acre dedication allow TPL to capture significant produced water volumes Contracts provide TPL with optionality and upside to pursue produced water recycling/treatment and beneficial reuse opportunities Long runway of volumes and cash flow growth, with minimal capex contributions from TPL Produced Water Royalties Overview and Management 88 433 922 1,206 1,595 1,957 2,510 3,435 4,292 0 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000 4,500 2017 2018 2019 2020 2021 2022 2023 2024 2025 “Produced water” refers to water that flows from a producing O&G well; given solids content and salinity, produced water generally must either be injected or treated/recycled The Delaware Basin is characterized by a high water- oil-ratio: for every crude oil barrel produced from a well, approximately 4 produced water barrels will also flow out TPL receives a volumetric royalty payment on produced water via negotiated commercial agreements with upstream and midstream operators and has off take rights to treat and resell produced water Average royalty fee of ~$0.07 - $0.10 per barrel TPL does not operate saltwater disposal (“SWD”) wells TPL’s produced water royalties are a commercially unique cash flow stream – high-margin, capex-free cash flow stream derived from an oil and gas by- product TPL retains flexibility to provide treatment / recycling and beneficial reuse of produced water How TPL is Delivering ValueRevenue Mechanics and Management TPL Produced Water Royalty Volumes (mbbl/d) 28

 

~690 ~1,220 ~180 ~310 First 12 months production First 36 months production 11.2 14.6 17.8 17.7 18.3 21.0 23.1 24.3 24.9 (2.0) 3.0 8 .0 13.0 18 .0 23.0 28.0 2017 2018 2019 2020 2021 2022 2023 2024 2025 Produced Water Royalties Delaware Upstream Activity + High Water-Cuts to Drive Produced Water Volume Growth Water vs Oil Production – Average Well in Delaware Basin1 Permian Produced Water ~70% of overall Permian produced water comes from the Delaware Continued O&G development and growth in Delaware will drive produced water volume growth Produced Water Oil Produced Water Oil (mbbl) Delaware O&G wells have relatively high water-cuts, ~4 barrels of produced water per barrel of oil on average (mmbbl/d) Drilling Rig TPL Produced Water AMI 29 TPL has executed numerous AMI (Area of Mutual Interest) agreements with operators – produced water volumes within the AMI are subject to a royalty fee TPL also generates significant revenue from water that originates from wells located off TPL acreage, including from New Mexico Source: Enverus and Company Data. Most recent data as of February 2026. (1) Delaware oil and water volumes based on horizontal wells completed since 1/1/2018

 

TPL Captures Revenue Over the Well Lifecycle 30 Permit Development Production E&P/upstream operators procure regulatory permits; prepare future well site and develop infrastructure ■ Fixed fees for use of TPL’s surface for the construction and operation of infrastructure (e.g., well sites, wellbores, pipelines) ■ Sale of materials (caliche) used in the construction of infrastructure ■ Price per barrel for providing brackish groundwater and / or treated produced water ■ Royalty per barrel for allowing produced water disposal related infrastructure on TPL surface ■ TPL royalty interests generate a fixed percentage of the oil & gas produced 1 2 3 SLEM Water Sales Produced Water O&G Royalties Operators spud/drills new wells. After drilling concludes, next step is to frac/complete Once completed, a well will be placed-on-production (“POP”) and begin generating production and revenue SLEM ■ Contracted payments to TPL as infrastructure on TPL land continues to be utilized

 

Permian’s Massive Resource Potential Enormous Acreage Extent and Stacked Pay Potential 31 ~26,000 square miles ~17,000,000 acres 10+ geologic formations for each Midland and Delaware Enormous Acreage Extent Stacked Pay Reserves Midland and Delaware Basins Greater Permian Basin Extent Combined Midland and Delaware Footprint

 

0 5 10 15 20 25 2015 2017 2019 2021 2023 2025 Permian Produced Water Growth Driven by Multiple Factors 32 Water-to-Oil Ratio (“WOR”) by Permian Well Vintage 2.5 3.0 3.5 4.0 4.5 5.0 0 12 24 36 48 60 72 84 96 Months on production 2017 2018 2019 2020 2021 2022 2023 2024 Permian Produced Water (mmbbl/d) Delaware Midland Permian Other Delaware Water-to-Oil Ratio by Bench Permian Oil Production (mmbbl/d) - 2.0 4.0 6.0 8.0 4.3x 3.7x 5.7x 6.6x 5.7x Current Permian Wolfcamp A Wolfcamp B Wolfcamp C Wolfcamp D Delaware Basin (12 month WOR) Source: US EIA, Enverus, and Company data and estimates. WOR generally increases as wells age Delaware benches generally have higher WOR Overall Permian oil production growth generates produced water

 

TPL Innovation | Produced Water Desalination and Beneficial Reuse 33 TPL has developed a process for produced water desalination that leverages the differing water freeze points across salinity levels Close collaboration with top-tier technology partner in the industrial freezing industry Fractional freezing more energy efficient than alternative desalination techniques Continue to make equipment and process optimizations Successful R&D trial at TPL facility in Midland; constructing larger test facility with capacity of ~10,000 barrels of water per day (Phase 2B) TPL Desalination Project Overview Key Milestones 2027+ 2027+ 1H 2026 2026 Reduces produced water subsurface injection Long-term, sustainable produced water solution Beneficial reuse and commercial/industrial applications Produced Water Desalination Benefits Proof of concept: freeze produced water desalination works and pathway to affordable cost Collaborating with a top-tier technology and manufacturing partner in the industrial refrigeration and freezing industry Secured exclusive use-rights for equipment towards produced water applications Filed a process patent utilizing fractional freeze desalination to treat produced water and surface discharge Granted Land Application Pilot Permit by RRC to grow alfalfa from treated water in Midland Research partnership with New Mexico State University & Texas Tech to analyze water quality & process improvement Validation of water quality acceptability for use with aquatic species and agriculture Receive 2nd Land Application Permit from RRC for Orla Native grassland restoration & quail habitat enhancement with TX PW Consortium & Quail Safe Receive draft Texas Pollutant Discharge Elimination System (“TPDES”) permit through Texas Commission on Environmental Quality (“TCEQ”) Commission Phase 2 facility (~10k bbl/d capacity) Evaluate synergies with behind-the-grid gas to electric generation for use in microgrids and/or data centers Equipment procurement of commercial-scale facility ~100k bbl/d facility (Phase 3) Advance full scale commercial operations throughout the Permian Phase 1 desalination test unit TPL beneficial reuse greenhouse Phase 2 desalination facility (Orla, TX)

 

West Texas Emerging as a Major Data Center and Power Infrastructure Hub 34 Natural gas 22+ bcf/d of Permian gas production, expected to grow 8+ bcf/d over next 5-10 years; 1 bcf/d of natural gas could power ~6 GW of combined cycle gas plants Solar 11+ GW current generation in ERCOT West Texas, with 11+ GW expected online in next 3 years Wind 27+ GW current generation in ERCOT West Texas, with 2+ GW expected online in next 3 years Batteries 4+ GW current generation in ERCOT West Texas, with 5+ GW expected online in next 3 years Pro-growth regulatory environment State regulators, local ISOs (e.g., ERCOT, SPP) and local industry aligned to develop large scale technology infrastructure Skilled workforce O&G industry has regularly maintained a highly-skilled workforce of hundreds-of-thousands in West Texas Water Availability of local aquifer water that does not compete with large metro or municipalities Freeze desalination colocation efficiencies TPL’s potential commercial scale freeze desalination could provide substantial colocation benefits for data centers TBD Source: US EIA, ERCOT, Enverus, and Company data and estimates

 

35

 

Appendix

 

Summary of Highest-Visibility Inventory Notes: Per Company data. Permian Basin horizontal locations as of 3/31/26. Percentages may not total to 100% due to immaterial rounding. Permitted well conversion rate based on wells permitted from 4/1/24 through 3/31/25 and then drilled through 3/31/26. DUC well conversion rate based on wells drilled from 4/1/24 through 3/31/25 and then drilled through 3/31/26. Completed well conversion rates based on wells completed between 4/1/24 through 3/31/25. DUCs considered to be all wells awaiting completion. 100% NRI Permitted Wells 100% NRI DUC Wells 100% NRI Completed Wells 14% 5% 30% 4% 9% 5% 8% 25% 65% 33% 2% 12% 8% 20% 4%5%12% 3% 8% 28% 62% 35% 3% 76% 23% 1% 3% 8% 18% 9% 19%2% 3% 38% N R I b y R eg io n N R I b y O p er at or ~83% of Permits are drilled within 6 months ~92% of Permits are drilled within 12 months ~41% of DUCs are completed within 6 months ~85% of DUCs are completed within 12 months ~69% of Completed Wells are listed as producing within ~1 month Midland Delaware Other Permitted Wells: 5.8 DUC Wells: 9.6 Completed Wells: 5.2 Permitted Wells: 5.8 Completed Wells: 5.2 DUC Wells: 9.6 Other 37

 

The Basics of Royalties Ownership 100% Lease Operator (i.e., E&P) Mineral/Royalties Capital Costs and Most Operating Expenses Revenue / Production Illustrative Economic Model – Minerals/Royalties vs Lease Interest 38 Key Terms and Comparison: Royalties/Minerals vs Lease Interest PARTICIPANTS NOMENCLATURE OWNERSHIP Real property interest/ownership of minerals Can develop minerals itself or lease the right to extract minerals to an external party Leases acreage from mineral estate for the right to extract subsurface minerals (e.g., oil and gas) CAPITAL COSTS Simply and generally just referred to as royalty/mineral owners Companies that own lease interests are also generally referred to as E&P (exploration & production), upstream and/or working interest companies (e.g., Occidental, EOG) Generally not responsible for capital costs to drill a well Generally responsible for 100% of the capital costs to drill and complete a well (“D&C”) OPERATING EXPENSES For oil production, generally no operating expense deductions For gas and NGL production, may have limited expense deductions Responsible for operating expenses such as gathering, transportation, processing, and marketing OTHER Generally incur severance and ad valorem taxes Mineral/royalty estate can be severed from surface estate OWNERSHIP DURATION Perpetual (though certain exclusions) Expiration subject to lease terms ROYALTIES / MINERALS LEASE INTEREST REVENUE INTEREST In Texas, mineral/royalty estate in aggregate generally receives 25% of gross production; minerals leased by federal government generally receive 12.5% - 18.5% Working interest percentages are expressed before mineral/royalty-take (i.e., 100% working interest owner would only net 75% of total well production/revenue) 75% 25%

 

Compensation Incentives Aligned With Shareholder Value Creation 39 Mix (% of Total)1 Intent Key Performance Dimensions Base Salary  Deliver competitive fixed cash compensation for day-to-day job performance  Based on individual role, level of experience and performance Annual Incentive Plan  Incentivize executives to achieve important near-term financial and operational goals  Reward individual and Company performance  Adjusted EBITDA (25% weight)  Free cash flow per share (50% weight)  Strategic objectives (25% weight) Long-Term Incentive Plan Performance- Based Restricted Stock Units (PSUs)  Reward performance that drives long-term value creation  Align interests of executives with shareholders  Three-year cumulative free cash flow per share  Relative TSR vs. SPDR S&P Oil & Gas Exploration & Production ETF Time-Based Restricted Stock Units (RSUs)  Incentivize long-term value creation  Align interests of executives with shareholders  Retention  Long-term stock price appreciation Fi xe d (1 6% )1 V ar ia b le (8 4 % )1 13% (1) Reflects target CEO compensation for 2025 as disclosed in the 2025 10-K. 15% 36% 36%

 

Sustainability is Embedded in Our Strategy 40 Key Opportunities Carbon Management  Government policies incentivize sustainable energy projects (e.g., carbon capture, utilization and storage) and TPL can reposition its business to take advantage of the opportunities created by these policies Water Management  Produced water recycling capabilities allow operators to minimize freshwater usage; ongoing water asset electrification can reduce diesel reliance and manage emissions profile Environmental Management  Adoption of new technology can reduce our costs and environmental impact  Allowance of easements on land to construct electricity infrastructure supports emissions reductions from our land operators Renewable Development  Expanding efforts to encourage wind and solar development on our surface and exploring all options to increase our existing renewable footprint Investing in Our People  Comprehensive, job-specific training and development opportunities; high employee retention and low turnover rates, with annual employee satisfaction surveys  Demonstrated commitment to enhancing diversity - 39% of workforce are women and continual assessment of organizational dynamics to cultivate a more inclusive workforce

 

Our Environmental Management Initiatives 41 Incidents and Spill Prevention Control  Implementation of Spill Prevention, Control, and Countermeasure plan and protocol for water assets, which are equipped with tech / containment protections  Thorough tracking and monitoring of all spills; information is entered into centralized database to allow easy tracking and data management  Prioritization of continued education and engagement of employees and contractors Environmental Impact Assessments  Prior to acquiring additional surface acreage, on-site Phase 1 Environmental Site Assessments are regularly conducted by environmental consultants to gauge property condition  Regularly scheduled pipeline maintenance checkups of existing pipeline assets; Health, Safety and Environment team closely monitors assets for spills, leaks or any other release Ecological and Biodiversity Partnerships  Partnership with New Mexico Bureau of Land Management to obtain biodiversity impact guidance  Contractual requirement for grazing tenants to use proper grazing and stockman standards and participate in conservation, range and wildlife improvement programs Operator and Lessee Requirements  Prioritization of consistent engagement and communications with operators and lessees on TPL’s land to ensure maintenance of environmental due diligence  Requirement of reclamation process to verify land has been restored to environmental condition stipulated by contractual agreement

 

ESG Update Category 2021 2022 2023 2024 2025 Emissions Scope 1 CO2 Emissions 16,159 10,590 13,819 14,945 13,361 Scope 2 CO2 Emissions 6,596 11,492 10,572 14,663 17,314 Total Scope 1 + Scope 2 22,755 22,082 24,391 29,608 30,675 Methane Emissions 0 0 0 0 0 $303 $451 $667 $632 $706 $798 24.1 22.8 22.1 24.4 29.6 30.7 0 10 20 30 40 50 60 70 80 $0 $100 $200 $300 $400 $500 $600 $700 $800 $900 2020 2021 2022 2023 2024 2025 TPL Revenue ($ million) Total Scope 1 + Scope 2 Emissions (metrics tons of CO2 equivalents) Emissions vs RevenueKey Statistics Spills Produced water spills (bbls) 0 0 0 0 0 Other spills (bbls) 45 0 0 0 0 Please visit the TPL Website for our full ESG Disclosures Energy Management – TPWR Operations Total energy consumed (Gigajoules) 287,140 263,289 304,622 362,562 Percentage grid – electricity 16% 29% 24% 27% Percentage grid – renewables 6% 13% 11% 14% Percentage grid – fuel 78% 58% 65% 59% (1) (2) (1) These 45 bbls underwent full and successful remediation efforts (2) Calculated based on 2023 ERCOT data Safety Incidents Employee and Contractor Total Recordable Incident Rate –TRIR 1.59 0 0 0 0 Employee lost time incident rate 0.79 0 0 0 0 42

 

Royalty Key Terms 43 Gross Royalty Acres Net Royalty Acres (Normalized to 1/8) Net Royalty Acres Drilling Spacing Units (“DSUs”) Implied Average Net Revenue Interest per Well ■ An undivided ownership of the oil, gas, and minerals underneath one acre of land ■ Total Texas Pacific Land Corporation acreage 1,136,500 ■ 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) 224,000 = 1,136,500 * 2.5% / (1/8) ■ Gross Royalty Acres * Avg. royalty 28,000 = 1,136,500 * 2.5% ■ Total number of gross DSU acres 2,840,300 ■ Net Royalty Acres / Gross DSU Acres 1.0% = 28,000 / 2,840,300 Description How’s It Calculated Note: Gross DSU acres based on current and projected DSU shapes. Figures as of 12/31/2025. Numbers may not foot due to immaterial rounding. Focus Area Gross Royalty Acres Net Royalty Acres (8/8th) Average Royalty Gross DSU Acres Implied Avg Net Revenue Interest per well Delaware Basin 396,200 19,700 5.0% 1,066,800 1.9% Midland Basin 706,000 6,600 0.9% 1,707,600 0.4% Other 34,300 1,700 5.0% 65,900 2.6% Total 1,136,500 28,000 2.5% 2,840,300 1.0%

 

Non-GAAP Reconciliations - Consolidated Source: Company data. Note: Numbers may not foot due to immaterial rounding. 1. Land swap of ~$22 million in 4Q19, and sale to WPX in 1Q19 of ~$100 million. 2. Costs related to proxy contest to elect a new Trustee, settlement agreement and corporate reorganization. 3. Excludes land sales deemed significant 44

 

Non-GAAP Reconciliations - Segment 45 Source: Company data. Note: Numbers may not foot due to immaterial rounding.

 

Historical Financial Summary 46 Source: Company data. Note: Numbers may not foot due to immaterial rounding.

 

2699 Howell Street, Suite 800 Dallas, Texas 75204 Texas Pacific Land Corporation

 

Exhibit 99.3 TPL ANNOUNCES THE APPOINTMENT OF PETER DOYLE TO THE BOARD DALLAS, TX (May 6, 2026) – Texas Pacific Land Corporation (NYSE: TPL) (“TPL” or the “Company”) and the Company’s Board of Directors (“Board”) announced today that Peter Doyle has been appointed to the Board. Mr. Doyle is a Co-Founder and the Co-Chief Executive Officer of Horizon Kinetics Holding Corporation (OTC: HKHC), which, through various owned subsidiaries, is TPL’s largest shareholder. He is a senior member of the Horizon Kinetics research team and a member of its investment committee and its board of directors. Mr. Doyle is also the President of Kinetics Mutual Funds, Inc., a series of investment companies managed by the Horizon Kinetics, and is a Co- Portfolio Manager for several other registered investment companies, private funds, and separately managed accounts. Mr. Doyle was also appointed to serve on the strategic acquisitions committee of the Board. Mr. Doyle will stand for re-election at the 2026 Annual Meeting. Ty Glover, CEO of TPL, said, “I have known Peter for many years as he has long been an engaged and active shareholder on behalf of Horizon Kinetics. Peter understands our business and industry well, and I look forward to his continued engagement and support of the Company now as a director. He will bring excellent expertise and perspective into our boardroom.” Peter Doyle stated, “This is a bittersweet privilege on the heels of Murray Stahl’s sudden passing. I fully intend on preserving Murray’s legacy and advocating on behalf of Horizon Kinetics and all shareholders, and I will endeavor as the newest director to serve the Board with the utmost dedication and ability. TPL has long been, and will continue to be, a major holding across our investment funds and vehicles, and we remain of the steadfast belief that TPL’s best days are ahead.” About Texas Pacific Land Corporation Texas Pacific Land Corporation is one of the largest landowners in the State of Texas with approximately 881,000 acres of land, with the majority of its ownership concentrated in the Permian Basin. The Company is not an oil and gas producer, but its surface and royalty ownership provides revenue opportunities throughout the life cycle of a well. These revenue opportunities

 

include fixed fee payments for use of the Company’s land, revenue for sales of materials (caliche) used in the construction of infrastructure, providing sourced water and/or treated produced water, revenue from the Company’s oil and gas royalty interests, and revenue related to saltwater disposal on the Company’s land. The Company also generates revenue from pipeline, power line and utility easements, commercial leases and temporary permits principally related to a variety of land uses including, but not limited to, midstream infrastructure projects and hydrocarbon processing facilities. Visit TPL at http://www.TexasPacific.com. Cautionary Statement Regarding Forward-Looking Statements Certain statements in this news release are, and certain statements made on the related conference call may be, 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, that are based on TPL’s beliefs, as well as assumptions made by, and information currently available to, TPL, and therefore involve risks and uncertainties that are difficult to predict. Generally, future or conditional verbs such as “will,” “would,” “should,” “could,” or “may” and the words “believe,” “anticipate,” “continue,” “intend,” “expect,” and similar expressions or the negative of such terms identify forward-looking statements. Forward-looking statements include, but are not limited to, references to strategies, plans, objectives, expectations, intentions, assumptions, future operations, and prospects; statements regarding anticipated benefits of recent acquisitions or the Permian Basin’s future drilling inventory and energy resources; and other statements that are not historical facts. You should not place undue reliance on forward-looking statements. Although TPL believes that plans, intentions and expectations reflected in or suggested by any forward-looking statements made herein are reasonable, TPL may be unable to achieve such plans, intentions or expectations and actual results, and performance or achievements may differ materially from those set forth in the forward-looking statements due to a number of factors, including, but not limited to: the initiation or outcome of potential litigation; any changes in general economic and/or industry specific conditions; and the other risks discussed in TPL’s Annual Report on Form 10-K and its Quarterly Reports on Form 10-Q. You can access TPL’s filings with the SEC through the SEC’s website at www.sec.gov and TPL strongly encourages you to do so. These forward-looking statements are based only on information available to TPL and speak only as of the date hereof. Except as required by applicable law, TPL undertakes no obligation to update any forward-looking statements or other statements herein for revisions or changes after this communication is made. Contact: Investor Relations IR@TexasPacific.com

 

Source: View Original Filing on SEC EDGAR

FAQ

How did Texas Pacific Land (TPL) perform financially in Q1 2026?

Texas Pacific Land reported strong Q1 2026 results with revenue of $236.8 million and net income of $142.9 million. Earnings were $2.07 per diluted share, supported by higher oil and gas royalties, water revenues, and new land sale income.

What were Texas Pacific Land’s key royalty and water metrics in Q1 2026?

In Q1 2026, Texas Pacific Land generated $118.2 million of oil and gas royalty revenue on 37.1 thousand Boe per day. Water sales were $46.9 million and produced water royalties totaled $33.5 million, reflecting continued growth in Permian activity.

What major land and data center transaction did TPL complete in Q1 2026?

Texas Pacific Land entered an arrangement with a power plant developer supporting data center operations, with $42.5 million aggregate land consideration. It recognized $20.9 million as land sale revenue, recorded a financing receivable, and signed a separate water supply agreement for the project.

What non-GAAP metrics did Texas Pacific Land highlight for Q1 2026?

For Q1 2026, Texas Pacific Land reported Adjusted EBITDA of $181.4 million and free cash flow of $136.4 million. These non-GAAP measures adjust net income for interest, taxes, depreciation, depletion, amortization, share-based compensation and specific land sale and capital items.

What dividend did Texas Pacific Land declare for Q2 2026?

On May 5, 2026, Texas Pacific Land’s board declared a quarterly cash dividend of $0.60 per share, payable on June 15, 2026 to stockholders of record as of June 1, 2026, continuing the company’s pattern of returning cash to shareholders.

Who is Peter Doyle and what role will he play at Texas Pacific Land?

Peter Doyle, Co-Founder and Co-Chief Executive Officer of Horizon Kinetics Holding Corporation, was appointed to Texas Pacific Land’s board and its strategic acquisitions committee. As Horizon Kinetics’ leader, he represents TPL’s largest shareholder and will stand for re-election at the 2026 annual meeting.

What upcoming stockholder meetings has Texas Pacific Land scheduled?

Texas Pacific Land intends to hold its 2026 Annual Meeting on November 5, 2026 in Dallas, Texas and its 2027 Annual Meeting on May 6, 2027. More details, including proposal and nomination deadlines, will appear in future proxy statements filed with the SEC.

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