February 18, 20260001811074FalseCHX00018110742026-02-182026-02-180001811074exch:XNYS2026-02-182026-02-180001811074exch:XCHI2026-02-182026-02-18


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

 
FORM 8-K

CURRENT REPORT
Pursuant to Section 13 or 15(d) of the Securities Exchange Act of 1934
 Date of report (Date of earliest event reported): February 18, 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 2.02.Results of Operations and Financial Condition.
Texas Pacific Land Corporation (the “Company”) hereby incorporates by reference the contents of a press release announcing financial results for the three months and year ended December 31, 2025, which was released to the press on February 18, 2026. A copy of the press release is furnished as Exhibit 99.1 to this current Report on Form 8-K.

Item 7.01.
Regulation FD Disclosure.
On February 18, 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.

The information included in this Item 7.01 of this Current Report on Form 8-K, including the attached Exhibits 99.1 and 99.2, 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.
 
    
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: February 18, 2026By:/s/ Chris Steddum
  Chris Steddum
  Chief Financial Officer
Exhibit 99.1
logo_texas2a.jpg

TEXAS PACIFIC LAND CORPORATION ANNOUNCES FOURTH QUARTER AND FULL YEAR 2025 RESULTS
–Achieved Record Fiscal Year Consolidated Revenues, Net Income, and Free Cash Flow
–Achieved Record Quarterly Oil and Gas Royalties Production, Water Sales Volumes, and Produced Water Royalties Volumes
–Declared a 12.5% Increase to the Regular Dividend
–Earnings Call to be Held Thursday, February 19, 2026 at 9:30 am CT
DALLAS, TX (February 18, 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 fourth quarter and full year of 2025.
Fourth Quarter 2025 Highlights
•Acquired 17,306 net royalty acres (standardized to 1/8th) located primarily in the Midland Basin for an aggregate purchase price of $450.7 million, net of post-closing adjustments, in an all-cash transaction.

•Invested $50.0 million in Bolt Data & Energy, Inc., a data infrastructure company, pursuant to a strategic agreement to develop and enable large scale data center campuses and supporting infrastructure across TPL land.

•Entered into a $500 million revolving credit facility.

•Effected a three-for-one stock split on December 22, 2025.

•Achieved record performance results, including:

◦Oil and gas royalty production of 37.5 thousand barrels of oil equivalent (“Boe”) per day

◦Water sales revenue of $60.7 million and water sales volumes of 1.0 million barrels (“bbl”) per day

◦Produced water royalties revenue of $33.5 million and produced water royalty volumes of 4.8 million bbl per day

◦Water Services and Operations segment revenues of $98.2 million

•As of December 31, 2025, TPL’s royalty acreage had an estimated 5.6 net well permits, 9.8 net drilled but uncompleted wells (“DUCs”), and 4.0 net completed but not producing wells (“CUPs”), totaling 19.5 net wells(1). TPL had 116.1 net producing wells as of December 31, 2025, and net producing wells added during the quarter had an average lateral length of approximately 10,910 feet.(2)

•Land and Resource Management segment revenues of $113.4 million

•Consolidated net income of $123.3 million, or $1.79 per share (diluted)

•Adjusted EBITDA(3) of $178.1 million

•Free cash flow(3) of $118.9 million

•Quarterly cash dividend of $0.53 per share was paid on December 15, 2025

1

Full Year 2025 Highlights
•Oil and gas royalty production of 34.6 thousand Boe per day

•Produced water royalties revenue of $124.2 million

•Land and Resource Management segment revenues of $490.7 million

•Water Services and Operations segment revenues of $307.5 million

•Consolidated net income of $481.4 million, or $6.97 per share (diluted)

•Adjusted EBITDA(3) of $687.4 million

•Free cash flow(3) of $498.3 million

•$147.8 million of total cash dividends paid through December 31, 2025

•$8.4 million of common stock repurchases through December 31, 2025

(1) Total may not foot due to rounding.
(2) Numbers reflected exclude recent royalty acquisition.
(3) Reconciliations of non-GAAP performance measures are provided in the tables below.

“Fourth quarter 2025 represents an excellent finish to a record year for TPL,” said Tyler Glover, Chief Executive Officer of the Company. “Oil and gas royalty production, water sales volumes, and produced water royalties volumes set records for this quarter and for the fiscal year. We also delivered fiscal year records for consolidated revenue, net income, and free cash flow. Our differentiated scale across royalties, land, and water enabled us to expand capture rates and generate growth despite broader commodity price headwinds. In addition, we have made substantial progress with next-generation opportunities in data centers and produced water desalination, and we plan to continue deploying resources to accelerate commercialization. TPL still maintains a net cash position and a fully undrawn $500 million credit facility, providing the Company ample liquidity to invest countercyclically across royalty, land, and water and to expand shareholder return of capital. We remain steadfastly focused on maximizing long-term intrinsic value per share, and the opportunity set in front of us today across our legacy and next-gen businesses is robust as ever.”

Financial Results for the Fourth Quarter of 2025 - Sequential

The Company reported net income of $123.3 million for the fourth quarter of 2025 compared to net income of $121.2 million for the third quarter of 2025.

Total revenues for the fourth quarter of 2025 were $211.6 million compared to $203.1 million for the third quarter of 2025. The increase in total revenues was primarily due to a $16.2 million increase in water sales and a $3.9 million increase in easements and other surface-related income, partially offset by a $12.0 million decrease in oil and gas royalty revenue compared to the third quarter of 2025. The Company’s share of production was 37.5 thousand Boe per day for the fourth quarter of 2025 compared to 36.3 thousand Boe per day for the third quarter of 2025, and the Company’s average realized price was $29.33 per Boe in the fourth quarter of 2025 compared to $34.10 per Boe in the third quarter of 2025. TPL’s revenue streams are directly impacted by commodity prices and development and operating decisions made by its customers.

Total operating expenses were $62.3 million for the fourth quarter of 2025 compared to $54.0 million for the third quarter of 2025. The increase in operating expenses was principally related to a $7.0 million increase in depreciation, depletion and amortization expense and a $1.1 million increase in water service-related expenses during the fourth quarter of 2025 compared to the third quarter of 2025.

Financial Results for the Year Ended December 31, 2025

The Company reported net income of $481.4 million for the year ended December 31, 2025 compared to net income of $454.0 million for the year ended December 31, 2024.

Total revenues for the year ended December 31, 2025 were $798.2 million compared to $705.8 million for the year ended December 31, 2024. The increase in total revenues was primarily due to a $38.3 million increase in oil and gas royalty revenue, a $20.1 million
2

increase in produced water royalties, a $19.0 million increase in water sales, and an $18.5 million increase in easements and other surface-related income compared to the same period of 2024. The Company’s share of production was 34.6 thousand Boe per day for the year ended December 31, 2025 compared to 26.8 thousand Boe per day for the same period of 2024, and the average realized price was $34.18 per Boe for the year ended December 31, 2025 compared to $39.87 per Boe for the same period of 2024. Produced water royalties increased due to increased produced water volumes, while 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 $206.0 million for the year ended December 31, 2025 compared to $166.7 million for the same period of 2024. The increase in operating expenses was principally related to a $33.0 million increase in depletion expense associated with oil and gas royalty interests acquired during the second half of 2025 and 2024.

Quarterly Dividend Declared

On February 10, 2026, the Company’s Board of Directors declared a quarterly cash dividend of $0.60 per share, payable on March 16, 2026 to stockholders of record at the close of business on March 2, 2026. This represents a 12.5% increase from the prior quarter regular dividend.

Conference Call and Webcast Information

The Company will hold a conference call on Thursday, February 19, 2026 at 9:30 a.m. Central Time to discuss fourth quarter and year end 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# 13757644. The telephone replay will be available starting shortly after the call through March 5, 2026.

About Texas Pacific Land Corporation

Texas Pacific Land Corporation is one of the largest landowners in the State of Texas with approximately 882,000 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 Securities and Exchange Commission (“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
3

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
4


FINANCIAL AND OPERATIONAL RESULTS
(unaudited)

Oil and Gas Activity

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

Three Months Ended
Years Ended
December 31,
2025		September 30,
2025		December 31,
2025		December 31,
2024
Company’s share of production volumes (1):
Oil (MBbls)
1,320 1,284 4,936 4,118 
Natural gas (MMcf)
6,328 6,142 23,359 17,074 
NGL (MBbls)
1,078 1,031 3,784 2,841 
Equivalents (MBoe)
3,453 3,338 12,613 9,804 
Equivalents per day (MBoe/d)
37.5 36.3 34.6 26.8 
Oil and gas royalty revenue (in thousands):
Oil royalties$74,998 $79,860 $304,930 $298,074 
Natural gas royalties3,856 11,441 37,432 18,512 
NGL royalties17,867 17,404 69,315 56,745 
Total oil and gas royalties$96,721 $108,705 $411,677 $373,331 
Realized prices (1):
Oil ($/Bbl)
$59.48 $65.14 $64.69 $75.80 
Natural gas ($/Mcf)
$0.66 $2.01 $1.73 $1.17 
NGL ($/Bbl)
$17.92 $18.25 $19.81 $21.60 
Equivalents ($/Boe)
$29.33 $34.10 $34.18 $39.87 
(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.

5

Water Services and Operations Activity


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

Three Months Ended
Years Ended
December 31,
2025		September 30,
2025		December 31,
2025		December 31,
2024
Water volumes (in MBbls) (1):
Water sales92,072 71,332 278,564269,281
Produced water royalties443,578 400,804 1,566,5881,257,246
Water volumes in barrels per day (in MBbls/d) (2):
Water sales1,001 775 763736
Produced water royalties4,822 4,357 4,2923,435
Water revenue (in thousands):
Water sales$60,733 $44,578 $169,701 $150,724 
Produced water royalties$33,513 $32,268 $124,218 $104,123 
(1)MBbl = 1 thousand barrels of water.
(2)MBbl/d = 1 thousand barrels of water per day.
6


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


 Three Months Ended
Years Ended
 December 31,
2025		September 30,
2025		December 31,
2025		December 31,
2024
Revenues:
Oil and gas royalties$96,721 $108,705 $411,677 $373,331 
Water sales60,733 44,578 169,701 150,724 
Produced water royalties33,513 32,268 124,218 104,123 
Easements and other surface-related income20,612 16,715 91,775 73,257 
Land sales— 819 819 4,388 
Total revenues211,579 203,085 798,190 705,823 
Expenses:
Salaries and related employee expenses14,894 14,387 57,925 53,621 
Water service-related expenses17,523 16,428 53,528 46,124 
General and administrative expenses6,424 5,591 23,780 34,483 
Depreciation, depletion and amortization21,930 14,963 62,533 25,162 
Ad valorem and other taxes1,562 2,625 8,263 7,295 
Total operating expenses62,333 53,994 206,029 166,685 
Operating income149,246 149,091 592,161 539,138 
Interest expense(690)— (690)— 
Other income, net3,209 6,088 18,858 39,683 
Income before income taxes151,765 155,179 610,329 578,821 
Income tax expense28,419 33,941 128,953 124,861 
Net income$123,346 $121,238 $481,376 $453,960 
Net income per share of common stock
Basic$1.79 $1.76 $6.98 $6.58 
Diluted$1.79 $1.76 $6.97 $6.57 
Weighted average number of shares of common stock outstanding
Basic68,938,230 68,954,649 68,949,240 68,958,591 
Diluted69,020,805 69,030,773 69,027,492 69,059,252 

7


SEGMENT OPERATING RESULTS
(dollars in thousands) (unaudited)


 Three Months Ended
 December 31,
2025		September 30,
2025
Land and Resource ManagementWater Services and OperationsConsolidatedLand and Resource ManagementWater Services and OperationsConsolidated
Revenues:
Oil and gas royalties$96,721 $— $96,721 $108,705 $— $108,705 
Water sales— 60,733 60,733 — 44,578 44,578 
Produced water royalties— 33,513 33,513 — 32,268 32,268 
Easements and other surface-related income16,662 3,950 20,612 12,741 3,974 16,715 
Land sales— — — 819 — 819 
Total revenues113,383 98,196 211,579 122,265 80,820 203,085 
Expenses:
Salaries and related employee expenses7,457 7,437 14,894 7,298 7,089 14,387 
Water service-related expenses— 17,523 17,523 — 16,428 16,428 
General and administrative expenses3,966 2,458 6,424 3,431 2,160 5,591 
Depreciation, depletion and amortization17,276 4,654 21,930 10,453 4,510 14,963 
Ad valorem and other taxes1,551 11 1,562 2,614 11 2,625 
Total operating expenses30,250 32,083 62,333 23,796 30,198 53,994 
Operating income83,133 66,113 149,246 98,469 50,622 149,091 
Interest expense(552)(138)(690)— — — 
Other income, net2,527 682 3,209 4,827 1,261 6,088 
Income before income taxes85,108 66,657 151,765 103,296 51,883 155,179 
Income tax expense15,566 12,853 28,419 22,536 11,405 33,941 
Net income$69,542 $53,804 $123,346 $80,760 $40,478 $121,238 
8

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


 Years Ended
 December 31,
2025		December 31,
2024
Land and Resource ManagementWater Services and OperationsConsolidatedLand and Resource ManagementWater Services and OperationsConsolidated
Revenues:
Oil and gas royalties$411,677 $— $411,677 $373,331 $— $373,331 
Water sales— 169,701 169,701 — 150,724 150,724 
Produced water royalties— 124,218 124,218 — 104,123 104,123 
Easements and other surface-related income78,230 13,545 91,775 63,074 10,183 73,257 
Land sales819 — 819 4,388 — 4,388 
Total revenues490,726 307,464 798,190 440,793 265,030 705,823 
Expenses:
Salaries and related employee expenses29,184 28,741 57,925 27,493 26,128 53,621 
Water service-related expenses— 53,528 53,528 — 46,124 46,124 
General and administrative expenses14,358 9,422 23,780 25,531 8,952 34,483 
Depreciation, depletion and amortization44,555 17,978 62,533 10,968 14,194 25,162 
Ad valorem and other taxes8,218 45 8,263 7,257 38 7,295 
Total operating expenses96,315 109,714 206,029 71,249 95,436 166,685 
Operating income394,411 197,750 592,161 369,544 169,594 539,138 
Interest expense(552)(138)(690)— — — 
Other income, net14,926 3,932 18,858 31,707 7,976 39,683 
Income before income taxes408,785 201,544 610,329 401,251 177,570 578,821 
Income tax expense86,370 42,583 128,953 86,350 38,511 124,861 
Net income$322,415 $158,961 $481,376 $314,901 $139,059 $453,960 

9

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 Named Executive Officers on an annual basis. We calculate Adjusted EBITDA as EBITDA plus employee share-based compensation less pension curtailment and settlement gain. The pension curtailment and settlement gain are related to a buyout by a third party of defined benefit obligations under our pension plan and the subsequent freezing of our pension plan, both of which occurred in the fourth quarter of 2024. We have excluded the pension curtailment and settlement gain from the calculation of Adjusted EBITDA as such gain is a non-recurring item and is not related to our core business.

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 Named 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, purchases of fixed assets and pension curtailment and settlement gain.

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 Named 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 December 31, 2025 and September 30, 2025 and for the years ended December 31, 2025 and December 31, 2024 (in thousands):
Three Months Ended
Years Ended
December 31,
2025		September 30,
2025		December 31,
2025		December 31,
2024
 Net income $123,346 $121,238 $481,376 $453,960 
 Add:
Interest expense690 — 690 — 
Income tax expense 28,419 33,941 128,953 124,861 
Depreciation, depletion and amortization21,930 14,963 62,533 25,162 
 EBITDA 174,385 170,142 673,552 603,983 
 Add (deduct):
Employee share-based compensation3,756 3,493 13,817 11,364 
Pension curtailment and settlement gain— — — (4,616)
Adjusted EBITDA$178,141 $173,635 $687,369 $610,731 

10

The following table presents a reconciliation of net income to free cash flow for the three months ended December 31, 2025 and September 30, 2025 and for the years ended December 31, 2025 and December 31, 2024 (in thousands):

Three Months Ended
Years Ended
December 31,
2025		September 30,
2025		December 31,
2025		December 31,
2024
 Net income $123,346 $121,238 $481,376 $453,960 
 Add (deduct):
Income tax expense 28,419 33,941 128,953 124,861 
Depreciation, depletion and amortization21,930 14,963 62,533 25,162 
Employee share-based compensation3,756 3,493 13,817 11,364 
Pension curtailment and settlement gain— — — (4,616)
Current income tax expense(26,968)(30,166)(122,398)(120,257)
Purchases of fixed assets(28,653)(18,601)(59,531)(29,696)
(Increase) decrease in accounts payable related to purchases of fixed assets(2,973)(2,005)(6,417)273 
Free cash flow$118,857 $122,863 $498,333 $461,051 

11
Texas Pacific Land Corporation NYSE: TPL Investor Presentation – February 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

 
2024 2025 4Q 1Q 2Q 3Q 4Q Selected consolidated financials ($MM): Oil and gas royalties 97.0$ 111.2$ 95.0$ 108.7$ 96.7$ Water sales 36.7 38.8 25.6 44.6 60.7 Produced water royalties 28.1 27.7 30.7 32.3 33.5 Easements and other surface income 21.8 18.2 36.2 16.7 20.6 Land sales and other 2.2 - - 0.8 - Total revenues 185.8$ 196.0$ 187.5$ 203.1$ 211.6$ Adj. EBITDA 161.3$ 169.4$ 166.2$ 173.6$ 178.1$ Adjusted EBITDA margin 87% 86% 89% 85% 84% % inc/(dec) - sequential Q/Q 12% 5% (2%) 4% 3% Free cash flow 123.7$ 126.6$ 130.1$ 122.9$ 118.9$ FCF Margin 67% 65% 69% 60% 56% % inc/(dec) - sequential Q/Q 16% 2% 3% (6%) (3%) Selected balance sheet data ($MM): Cash and cash equivalents 369.8$ 460.4$ 543.9$ 531.8$ 144.8$ Debt - - - - - Selected segment data ($MM): Land and Resource Management Revenue 118.6$ 126.6$ 128.5$ 122.3$ 113.4$ Adj. EBITDA 110.7 119.0 122.2 115.9 105.3 Net Income 81.9 85.5 86.6 80.8 69.5 Water Service and Operations Revenue 67.2$ 69.4$ 59.0$ 80.8$ 98.2$ Adj. EBITDA 50.7 50.5 44.0 57.8 72.8 Net Income 36.4 35.1 29.6 40.5 53.8 $70.73 $71.05 $63.99 $65.14 $59.48 4Q 2024 1Q 2025 2Q 2025 3Q 2025 4Q 2025 12.1 12.5 13.3 14.0 14.4 8.6 9.7 10.4 11.1 11.5 8.3 9.0 9.5 11.2 11.7 29.1 31.1 33.2 36.3 37.5 0.0 5.0 10.0 15.0 20.0 25.0 30.0 35.0 40.0 4Q 2024 1Q 2025 2Q 2025 3Q 2025 4Q 2025 Oil Gas NGL 737 792 482 775 1,001 0.0 200.0 400.0 600.0 800.0 1,000.0 4Q 2024 1Q 2025 2Q 2025 3Q 2025 4Q 2025 4Q 2025 Summary Financial and Operating Update 3 O&G Royalty Production Total Water Sales Volumes1 Oil Realizations Produced Water Royalty Volumes (mboe/d) (mbbl/d) ($/bbl) (mbbl/d) 3,955 3,730 4,248 4,357 4,822 2,000.0 2,500.0 3,000.0 3,500.0 4,000.0 4,500.0 5,000.0 4Q 2024 1Q 2025 2Q 2025 3Q 2025 4Q 2025 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

 
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 4 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

 
(1%) 1% 15% 19% 29% -12% -2% 8% 18% 28% WTI SPY Nasdaq TPL fsfsdfsfs 5 $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 $145 Million ~28,000 Core Permian Net Royalty Acres ~882,000 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 827 DUCs and 460 Permits Decades of Cash Flow Runway Across Multiple Businesses ~390% Production growth since 2018 $$ 6Note: Operating data as of 12/31/2025. Balance sheet and well inventory data as of 12/31/2025.

 
$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) $24,354 Cash & Equivalents ($MM) $145 Debt ($MM) $0 Net Royalty Acres (100% net basis) ~28,000 Normalized to 1/8th ~224,000 Surface Acres ~882,000 2025 Adj. EBITDA Margin 86% 2025 FCF Margin 62% Average daily trading volume (1-yr avg) ~407,000 Free Cash Flow ($MM)FY 2025 Revenues ($MM)  One of the largest landowners in Texas with approximately 882,000 acres located in the Permian Basin  TPL was originally organized in 1888 as a business trust to manage the property of the Texas and Pacific Railway Company; for nearly 130 years, this management was mostly passive  In 2016, the Company embarked on a new strategy to maximize the value of its footprint through active management of surface and royalty interests  Today, the business consists of numerous high-margin, capital-light revenue streams linked to Permian oil and gas development – Oil and Gas Royalties: high-margin royalty revenue derived from oil and gas production with no capital and minimal operating expense burden – Surface Leases, Easements and Material (“SLEM”): monetizes 3rd party development activities occurring on surface and royalty acreage – Texas Pacific Water Resources (“TPWR”): supplies brackish and treated produced water for oil and gas activities and facilitates produced water disposal solutions Adjusted EBITDA ($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 7 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 12/31/2025. Market value and average daily trading volume as of 01/29/2026. 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 8

 
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. 9

 
~66,000 ~41,000 ~17,000 ~15,000 ~6,000 ~5,000 0 10,000 20,000 30,000 40,000 50,000 60,000 70,000 Permian Montney Marcellus Eagle Ford SCOOP | Stack 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 10 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 $145M 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) 11Note: Debt and cash balance as of 12/31/2025. 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 12Note: 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 13 ― ― ― 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 [0%, 5%] (5%, 10%] (10%, 15%] (15%, 19%] (19%, 24%] (24%, 29%] (29%, 34%] (34%, 39%] (39%, 43%] (43%, 48%] (48%, 53%] (53%, 58%] (58%, 63%] (63%, 67%] (67%, 72%] (72%, 77%] 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 14

 
Permian Activity Overview 15 2,869 337 303 3,546 285 273 3,486 249 325 ≤ 1 year 1 year < x ≤ 2 years 2 year < x ≤ 4 years 2025 2024 2023 - 1.0 2.0 3.0 4.0 5.0 6.0 7.0 1,452 1,528 1,423 1,555 1,521 1,444 1,563 1,595 1,537 3Q 2023 4Q 2023 1Q 2024 2Q 2024 3Q 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 <1 year 1 year < x ≤ 2 years > 2 years 1,399 1,678 2,039 1,983 1,907 1,839 1,764 1,768 1,531 4Q 2023 1Q 2024 2Q 2024 3Q 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 4Q 2025 Delaware Midland Permian Other Permian Well PermitsPermian Horizontal Rig CountsPermian Oil Production Permian Completion Counts (Grouped by DUC age at completion date) (mmbbl/d) 301 301 302 294 289 289 273 238 230 4Q 2023 1Q 2024 2Q 2024 3Q 2024 4Q 2024 1Q 2025 2Q 2025 3Q 2025 4Q 2025 DUCs as of September 30, 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 4Q 2025 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 13.4 14.5 14.0 16.2 16.8 17.7 18.8 23.4 24.7 25.7 27.4 38.9 59.4 62.6 62.8 67.2 70.2 73.3 79.2 86.8 90.2 95.4 100.5 116.1 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 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 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 7.8 8.2 7.9 9.7 10.3 9.5 11.8 13.2 12.9 11.1 9.9 9.8 3.3 2.3 5.2 2.8 2.2 4.0 3.4 3.0 5.4 5.1 3.1 4.0 16.1 15.4 19.8 17.0 17.6 19.8 22.1 22.6 24.3 22.2 19.0 19.5 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 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 9,725 10,110 10,386 11,012 10,826 11,318 12,052 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 12/31/2025.

 
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 $- $50 FY 2036-2045 will feature term easements potential renewals from (i) 2nd 10- year extension of 2016-2025 term easement vintages and (ii) 1st 10-year extension of 2026-2035 term easement vintages ($ 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 27+ 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 12/31/25. Percentages may not total to 100% due to immaterial rounding. Permitted well conversion rate based on wells permitted from 1/1/24 through 12/31/24 and then drilled through 12/31/25. DUC well conversion rate based on wells drilled from 1/1/24 through 12/31/24 and then drilled through 12/31/25. Completed well conversion rates based on wells completed between 1/1/24 through 12/31/24. DUCs considered to be all wells awaiting completion. 100% NRI Permitted Wells 100% NRI DUC Wells 100% NRI Completed Wells 11% 3% 25% 3% 5%8% 12% 33% 71% 25% 4% 9% 7% 21% 3% 5%15% 3% 7% 30% 69% 29% 2% 73% 26% 1% 2% 11% 17% 19% 8%5% 1% 37% N R I b y R eg io n N R I b y O p er at or ~81% of Permits are drilled within 6 months ~90% of Permits are drilled within 12 months ~22% of DUCs are completed within 6 months ~87% of DUCs are completed within 12 months ~96% of Completed Wells are listed as producing within ~1 month Midland Delaware Other Permitted Wells: 5.6 DUC Wells: 9.8 Completed Wells: 4.0 Permitted Wells: 5.6 Completed Wells: 4.0 DUC Wells: 9.8 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 Scope 2 CO2 Emissions 6,596 11,492 10,572 14,663 Total Scope 1 + Scope 2 22,755 22,082 24,391 29,608 Methane Emissions 0 0 0 0 $303 $451 $667 $632 $706 24.1 22.8 22.1 24.4 29.6 0 10 20 30 40 50 60 70 80 $0 $100 $200 $300 $400 $500 $600 $700 $800 2020 2021 2022 2023 2024 TPL Revenue ($ 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 Other spills (bbls) 45 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 Employee lost time incident rate 0.79 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