November 6, 20240001811074False00018110742024-11-062024-11-06
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): November 6, 2024
Commission File Number: 1-39804
Exact name of registrant as specified in its charter:
TEXAS PACIFIC LAND CORPORATION
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| State or other jurisdiction of incorporation or organization: | | IRS Employer Identification No.: |
| Delaware | | 75-0279735 |
Address of principal executive offices:
1700 Pacific Avenue, Suite 2900 Dallas, Texas 75201
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:
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| ☐ | | Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425) |
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| ☐ | | Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12) |
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| ☐ | | Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b)) |
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| ☐ | | Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c)) |
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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:
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| Title of each class | | Trading Symbol(s) | | Name of each exchange on which registered |
Common Stock
(par value $.01 per share) | | TPL | | New York Stock Exchange |
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| 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 and nine months ended September 30, 2024, which was released to the press on November 6, 2024. A copy of the press release is furnished as Exhibit 99.1 to this Report on Form 8-K.
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Item 7.01. | Regulation FD Disclosure. |
On November 6, 2024, the Company posted to the Company’s website at www.texaspacific.com an updated investor presentation to be used from time to time in meetings with investors and analysts. A copy of the 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 TPL. The video is also available on the Company's website at https://www.texaspacific.com/.
The information included in this Item 7.01 of this Current Report on Form 8-K, including the attached Exhibit 99.2, shall not be deemed “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, or incorporated by reference in any filing under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended, except as shall be expressly set forth by specific reference in such filing.
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| Item 9.01. | Financial Statements and Exhibits. |
| | (d) | | Exhibits.
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| | | 104 | | Cover 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.
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| | | TEXAS PACIFIC LAND CORPORATION |
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| Date: | November 6, 2024 | By: | /s/ Chris Steddum |
| | | | Chris Steddum |
| | | | Chief Financial Officer |
TEXAS PACIFIC LAND CORPORATION ANNOUNCES THIRD QUARTER RESULTS
Earnings Call to be held 7:30 am CT on Thursday, November 7, 2024
DALLAS, TX (November 6, 2024) – Texas Pacific Land Corporation (NYSE: TPL) (the “Company” or “TPL”) today announced its financial and operating results for the third quarter of 2024.
Third Quarter 2024 Highlights
•Acquired mineral interests across approximately 4,106 net royalty acres located in the northern Delaware Basin for a purchase price of $120.3 million, net of post-close adjustments, in an all-cash transaction
•Acquired approximately 4,120 surface acres and other surface-related assets located in the core of the Midland Basin for a purchase price of $45.0 million, in an all-cash transaction
•Royalty production of 28.3 thousand barrels of oil equivalent (“Boe”) per day
•As of September 30, 2024, TPL’s royalty acreage had an estimated 6.9 net well permits, 11.8 net drilled but uncompleted wells, 3.4 net completed wells, and 79.2 net producing wells. Net producing wells added during the quarter had an average lateral length of approximately 7,659 ft.
•Consolidated net income of $106.6 million, or $4.63 per share (diluted)
•Adjusted EBITDA(1) of $144.1 million
•Free cash flow (1) of $106.9 million
•Special cash dividend of $10.00 per share was paid on July 15, 2024
•Quarterly cash dividend of $1.17 per share was paid on September 17, 2024
Nine Months Ended September 30, 2024 Highlights
•The Company announced the development of a new energy-efficient method of produced water desalination and treatment. The Company has successfully conducted a technology pilot and is progressing towards the construction of a larger test facility with an initial capacity of 10,000 barrels of produced water per day.
•Three-for-one stock split effected March 26, 2024
•Royalty production of 26.0 thousand Boe per day
•Consolidated net income of $335.6 million, or $14.58 per share (diluted)
•Adjusted EBITDA(1) of $449.4 million
•Free cash flow (1) of $337.3 million
•$310.6 million of total cash dividends paid through September 30, 2024 (composed of a $10.00 per share special dividend and $1.17 per share in regular quarterly cash dividends)
•$22.7 million of common stock repurchases
(1) Reconciliations of Non-GAAP measures are provided in the tables below.
“Our strong results this quarter showcase the benefit of a strategy predicated on robust active management on our legacy assets combined with opportunistic growth,” said Tyler Glover, Chief Executive Officer of the Company. “Record royalty production during the quarter was driven by our outstanding legacy royalty position, and we anticipate that our recently announced acquisitions will also meaningfully enhance our royalty production going forward. In addition, we continue to execute on new opportunities leveraging our surface and water assets, with prior acquisitions of strategic surface acreage and pore-space easements facilitating numerous new commercial agreements with high-quality operator customers. The 37% increase to the regular dividend announced today is largely supported by our recent acquisitions, which we expect to provide a substantial uplift to our near-term financial results and to strengthen our long-term growth outlook.”
Financial Results for the Third Quarter of 2024 - Sequential
The Company reported net income of $106.6 million for the third quarter of 2024 compared to net income of $114.6 million for the second quarter of 2024.
Total revenues for the third quarter of 2024 were $173.6 million compared to $172.3 million for the second quarter of 2024. The increase in revenues was primarily due to a $4.6 million increase in oil and gas royalty revenue and a $2.4 million increase in produced water royalties, partially offset by a $4.4 million decrease in water sales compared to the second quarter of 2024. The decrease in water sales was principally due to a decrease of 9.0% in water sales volumes for the third quarter of 2024 compared to the second quarter of 2024. The Company’s share of production was 28.3 thousand Boe per day for the third quarter of 2024 versus 24.9 thousand Boe per day for the second quarter of 2024, and the average realized price was $38.04 per Boe in the third quarter of 2024 compared to $41.44 per Boe in the second quarter of 2024. TPL's revenue streams are directly impacted by commodity prices and development and operating decisions made by its customers.
Total operating expenses were $46.2 million for the third quarter of 2024 compared to $39.1 million for the second quarter of 2024. The change in operating expenses was principally related to an increase in legal and professional fees during the third quarter of 2024, partially offset by a decrease in water service-related expenses over the same period.
Financial Results for the Third Quarter of 2024 - Year Over Year
Total revenues for the nine months ended September 30, 2024 were $520.0 million compared to $464.9 million for the same period of 2023. All revenue streams, except land sales and easements and other surface-related income, increased for the nine months ended September 30, 2024 with the $28.2 million increase in water sales being the biggest contributor. The growth in water sales was principally due to an increase of 27.6% in water sales volumes for the nine months ended September 30, 2024 compared to the same period of 2023. Additionally, oil and gas royalty revenue increased $17.7 million primarily due to higher production volumes for the nine months ended September 30, 2024 compared to the same period of 2023. Oil and gas royalty revenue for the nine months ended September 30, 2023 included an $8.7 million settlement with an operator with respect to unpaid oil and gas royalties for older production periods. Excluding the impact of the $8.7 million settlement on oil and gas royalty revenues for the nine months ended September 30, 2023, oil and gas royalty revenue for the nine months ended September 30, 2024 increased $26.4 million over the same period of 2023. The Company’s share of production was 26.0 thousand Boe per day for the nine months ended September 30, 2024 versus 22.6 thousand Boe per day for the same period of 2023. The average realized price was $40.60 per Boe for the nine months ended September 30, 2024 versus $42.49 per Boe for the same period of 2023. TPL’s revenue streams are directly impacted by commodity prices and development and operating decisions made by its customers.
Total operating expenses were $123.4 million for the nine months ended September 30, 2024 compared to $112.7 million for the same period of 2023. The change in operating expenses was principally related to an increase in water service-related expenses due to the 27.6% increase in water sales volumes for the nine months ended September 30, 2024 compared to the same period of 2023.
Quarterly Dividend Declared
On November 4, 2024, the Company's Board of Directors declared a quarterly cash dividend of $1.60 per share, payable on December 16, 2024 to stockholders of record at the close of business on December 2, 2024.
Conference Call and Webcast Information
The Company will hold a conference call on Thursday, November 7, 2024 at 7:30 a.m. Central Time to discuss third 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# 13745174. The telephone replay will be available starting shortly after the call through November 21, 2024.
About Texas Pacific Land Corporation
Texas Pacific Land Corporation is one of the largest landowners in the State of Texas with approximately 873,000 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 provide revenue opportunities throughout the life cycle of a well. These revenue opportunities include fixed fee payments for use of our land, revenue for sales of materials (caliche) used in the construction of infrastructure, providing sourced water and/or treated produced water, revenue from our oil and gas royalty interests, and revenues related to saltwater disposal on our land. The Company also generates revenue from pipeline, power line and utility easements, commercial leases and temporary permits related to a variety of land uses including midstream infrastructure projects and hydrocarbon processing facilities.
Visit TPL at www.TexasPacific.com.
Cautionary Statement Regarding Forward-Looking Statements
This news release may contain 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 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 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 vary materially and adversely from those envisaged in this news release due to a number of factors including, but not limited to: the initiation or outcome of potential litigation; and any changes in general economic and/or industry specific conditions. These risks, as well as other risks associated with TPL are also more fully discussed in our Annual Report on Form 10-K and our 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. 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
FINANCIAL AND OPERATIONAL RESULTS
(unaudited)
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| | Three Months Ended
| | Nine Months Ended | | |
| | September 30,
2024 | | June 30,
2024 | | September 30,
2024 | | September 30, 2023(2) | | | | |
Company’s share of production volumes(1): | | | | | | | | | | | | |
Oil (MBbls) | | 1,046 | | | 967 | | | 3,003 | | | 2,642 | | | | | |
Natural gas (MMcf) | | 4,654 | | | 3,851 | | | 12,312 | | | 10,405 | | | | | |
NGL (MBbls) | | 779 | | | 661 | | | 2,073 | | | 1,784 | | | | | |
Equivalents (MBoe) | | 2,600 | | | 2,270 | | | 7,128 | | | 6,160 | | | | | |
Equivalents per day (MBoe/d) | | 28.3 | | | 24.9 | | | 26.0 | | | 22.6 | | | | | |
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Oil and gas royalty revenue (in thousands): | | | | | | | | | | | | |
| Oil royalties | | $ | 75,427 | | | $ | 74,747 | | | $ | 222,788 | | | $ | 193,969 | | | | | |
| Natural gas royalties | | 4,201 | | | 2,367 | | | 13,630 | | | 23,210 | | | | | |
| NGL royalties | | 14,816 | | | 12,699 | | | 39,959 | | | 32,800 | | | | | |
| Total oil and gas royalties | | $ | 94,444 | | | $ | 89,813 | | | $ | 276,377 | | | $ | 249,979 | | | | | |
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Realized prices (1): | | | | | | | | | | | | |
Oil ($/Bbl) | | $ | 75.53 | | | $ | 80.93 | | | $ | 77.68 | | | $ | 76.88 | | | | | |
Natural gas ($/Mcf) | | $ | 0.98 | | | $ | 0.66 | | | $ | 1.20 | | | $ | 2.41 | | | | | |
NGL ($/Bbl) | | $ | 20.57 | | | $ | 20.78 | | | $ | 20.84 | | | $ | 19.88 | | | | | |
Equivalents ($/Boe) | | $ | 38.04 | | | $ | 41.44 | | | $ | 40.60 | | | $ | 42.49 | | | | | |
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| (1) | Term | | Definition |
| Bbl | | One stock tank barrel of 42 U.S. gallons liquid volume used herein in reference to crude oil, condensate or NGLs. |
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| MBbls | | One thousand barrels of crude oil, condensate or NGLs. |
| MBoe | | One thousand Boe. |
| MBoe/d | | One thousand Boe per day. |
| Mcf | | One thousand cubic feet of natural gas. |
| MMcf | | One million cubic feet of natural gas. |
| NGL | | Natural gas liquids. Hydrocarbons found in natural gas that may be extracted as liquefied petroleum gas and natural gasoline. |
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| (2) | The metrics and dollars provided for the nine months ended September 30, 2023 exclude the impact of an $8.7 million settlement with an operator with respect to unpaid oil and gas royalties. |
CONDENSED CONSOLIDATED STATEMENTS OF INCOME
(in thousands, except share and per share amounts) (unaudited)
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| | | Three Months Ended
| | Nine Months Ended | | | | | | |
| | | September 30,
2024 | | June 30,
2024 | | September 30,
2024 | | September 30,
2023 | | | | | | | | |
| Revenues: | | | | | | | | | | | | | | | | |
| Oil and gas royalties | | $ | 94,444 | | | $ | 89,813 | | | $ | 276,377 | | | $ | 258,644 | | | | | | | | | |
| Water sales | | 36,211 | | | 40,650 | | | 113,987 | | | 85,799 | | | | | | | | | |
| Produced water royalties | | 27,727 | | | 25,301 | | | 76,034 | | | 61,824 | | | | | | | | | |
| Easements and other surface-related income | | 14,280 | | | 16,570 | | | 51,496 | | | 51,865 | | | | | | | | | |
| Land sales | | 901 | | | — | | | 2,145 | | | 6,806 | | | | | | | | | |
| Total revenues | | 173,563 | | | 172,334 | | | 520,039 | | | 464,938 | | | | | | | | | |
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| Expenses: | | | | | | | | | | | | | | | | |
| Salaries and related employee expenses | | 14,030 | | | 12,771 | | | 39,262 | | | 32,688 | | | | | | | | | |
| Water service-related expenses | | 11,731 | | | 14,824 | | | 36,767 | | | 24,496 | | | | | | | | | |
| General and administrative expenses | | 4,029 | | | 3,673 | | | 12,626 | | | 10,738 | | | | | | | | | |
| Legal and professional fees | | 8,316 | | | 2,307 | | | 14,680 | | | 28,471 | | | | | | | | | |
| Ad valorem and other taxes | | 2,189 | | | 1,444 | | | 5,990 | | | 5,425 | | | | | | | | | |
| Land sales expenses | | 175 | | | — | | | 425 | | | 49 | | | | | | | | | |
| Depreciation, depletion and amortization | | 5,762 | | | 4,093 | | | 13,695 | | | 10,881 | | | | | | | | | |
| Total operating expenses | | 46,232 | | | 39,112 | | | 123,445 | | | 112,748 | | | | | | | | | |
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| Operating income | | 127,331 | | | 133,222 | | | 396,594 | | | 352,190 | | | | | | | | | |
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| Other income, net | | 8,086 | | | 13,220 | | | 31,249 | | | 20,239 | | | | | | | | | |
| Income before income taxes | | 135,417 | | | 146,442 | | | 427,843 | | | 372,429 | | | | | | | | | |
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| Income tax expense | | 28,823 | | | 31,853 | | | 92,243 | | | 79,894 | | | | | | | | | |
| Net income | | $ | 106,594 | | | $ | 114,589 | | | $ | 335,600 | | | $ | 292,535 | | | | | | | | | |
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Net income per share of common stock (1) | | | | | | | | | | | | | | | | |
| Basic | | $ | 4.64 | | | $ | 4.99 | | | $ | 14.60 | | | $ | 12.69 | | | | | | | | | |
| Diluted | | $ | 4.63 | | | $ | 4.98 | | | $ | 14.58 | | | $ | 12.68 | | | | | | | | | |
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Weighted average number of shares of common stock outstanding (1) | | | | | | | | | | | | | | | | |
| Basic | | 22,979,781 | | | 22,987,971 | | | 22,990,213 | | | 23,054,073 | | | | | | | | | |
| Diluted | | 23,012,169 | | | 23,013,793 | | | 23,016,733 | | | 23,072,955 | | | | | | | | | |
(1)All share and share price amounts reflect the three-for-one stock split effected on March 26, 2024.
SEGMENT OPERATING RESULTS
(dollars in thousands) (unaudited)
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended
| | |
| | September 30,
2024 | | June 30,
2024 | | | | |
| Revenues: | | | | | | | | | | | | | | | | |
| Land and resource management: | | | | | | | | | | | | | | | | |
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| Oil and gas royalties | | $ | 94,444 | | | 54 | % | | $ | 89,813 | | | 52 | % | | | | | | | | |
| Easements and other surface-related income | | 11,303 | | | 7 | % | | 14,219 | | | 8 | % | | | | | | | | |
| Land sales | | 901 | | | — | % | | — | | | — | % | | | | | | | | |
| Total land and resource management revenue | | 106,648 | | | 61 | % | | 104,032 | | | 60 | % | | | | | | | | |
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| Water services and operations: | | | | | | | | | | | | | | | | |
| Water sales | | 36,211 | | | 21 | % | | 40,650 | | | 24 | % | | | | | | | | |
| Produced water royalties | | 27,727 | | | 16 | % | | 25,301 | | | 15 | % | | | | | | | | |
| Easements and other surface-related income | | 2,977 | | | 2 | % | | 2,351 | | | 1 | % | | | | | | | | |
| Total water services and operations revenue | | 66,915 | | | 39 | % | | 68,302 | | | 40 | % | | | | | | | | |
| Total consolidated revenues | | $ | 173,563 | | | 100 | % | | $ | 172,334 | | | 100 | % | | | | | | | | |
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| Net income: | | | | | | | | | | | | | | | | |
| Land and resource management | | $ | 71,870 | | | 67 | % | | $ | 80,129 | | | 70 | % | | | | | | | | |
| Water services and operations | | 34,724 | | | 33 | % | | 34,460 | | | 30 | % | | | | | | | | |
| Total consolidated net income | | $ | 106,594 | | | 100 | % | | $ | 114,589 | | | 100 | % | | | | | | | | |
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| | | | Nine Months Ended |
| | | | | | September 30,
2024 | | September 30,
2023 |
| Revenues: | | | | | | | | | | | | | | | | |
| Land and resource management: | | | | | | | | | | | | | | | | |
| | | | | | | | | | | | | | | | |
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| Oil and gas royalties | | | | | | | | | | $ | 276,377 | | | 54 | % | | $ | 258,644 | | | 56 | % |
| Easements and other surface-related income | | | | | | | | | | 43,643 | | | 8 | % | | 49,826 | | | 11 | % |
| Land sales | | | | | | | | | | 2,145 | | | — | % | | 6,806 | | | 1 | % |
| Total land and resource management revenue | | | | | | | | | | 322,165 | | | 62 | % | | 315,276 | | | 68 | % |
| | | | | | | | | | | | | | | | |
| Water services and operations: | | | | | | | | | | | | | | | | |
| Water sales | | | | | | | | | | 113,987 | | | 22 | % | | 85,799 | | | 19 | % |
| Produced water royalties | | | | | | | | | | 76,034 | | | 15 | % | | 61,824 | | | 13 | % |
| Easements and other surface-related income | | | | | | | | | | 7,853 | | | 1 | % | | 2,039 | | | — | % |
| Total water services and operations revenue | | | | | | | | | | 197,874 | | | 38 | % | | 149,662 | | | 32 | % |
| Total consolidated revenues | | | | | | | | | | $ | 520,039 | | | 100 | % | | $ | 464,938 | | | 100 | % |
| | | | | | | | | | | | | | | | |
| Net income: | | | | | | | | | | | | | | | | |
| Land and resource management | | | | | | | | | | $ | 232,970 | | | 69 | % | | $ | 217,860 | | | 74 | % |
| Water services and operations | | | | | | | | | | 102,630 | | | 31 | % | | 74,675 | | | 26 | % |
| Total consolidated net income | | | | | | | | | | $ | 335,600 | | | 100 | % | | $ | 292,535 | | | 100 | % |
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NON-GAAP PERFORMANCE MEASURES AND DEFINITIONS
In addition to amounts presented in accordance with generally accepted accounting principles in the United States of America (“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. Its purpose is to highlight earnings without finance, taxes, and depreciation, depletion and amortization expense, and its use is limited to specialized analysis. We calculate Adjusted EBITDA as EBITDA plus employee share-based compensation. Its purpose is to highlight earnings without non-cash activity such as share-based compensation and other non-recurring or unusual items, if applicable. We calculate Free Cash Flow as Adjusted EBITDA less current income tax expense and capital expenditures. Its purpose is to provide an additional measure of operating performance. 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. 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, Adjusted EBITDA and Free Cash Flow for the three months ended September 30, 2024 and June 30, 2024 and for the nine months ended September 30, 2024 and September 30, 2023 (in thousands):
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Three Months Ended
| | Nine Months Ended |
| | September 30,
2024 | | June 30,
2024 | | September 30,
2024 | | September 30,
2023 | | | | |
| Net income | | $ | 106,594 | | | $ | 114,589 | | | $ | 335,600 | | | $ | 292,535 | | | | | |
| Add: | | | | | | | | | | | | |
| Income tax expense | | 28,823 | | | 31,853 | | | 92,243 | | | 79,894 | | | | | |
| Depreciation, depletion and amortization | | 5,762 | | | 4,093 | | | 13,695 | | | 10,881 | | | | | |
| EBITDA | | 141,179 | | | 150,535 | | | 441,538 | | | 383,310 | | | | | |
| Add: | | | | | | | | | | | | |
| Employee share-based compensation | | 2,935 | | | 2,700 | | | 7,855 | | | 7,217 | | | | | |
| | | | | | | | | | | | |
| | | | | | | | | | | | |
| | | | | | | | | | | | |
| Adjusted EBITDA | | 144,114 | | | 153,235 | | | 449,393 | | | 390,527 | | | | | |
| Less: | | | | | | | | | | | | |
| | | | | | | | | | | | |
| | | | | | | | | | | | |
| Current income tax expense | | (27,416) | | | (30,766) | | | (90,080) | | | (80,928) | | | | | |
| Capital expenditures | | (9,833) | | | (6,499) | | | (21,994) | | | (10,387) | | | | | |
| Free Cash Flow | | $ | 106,865 | | | $ | 115,970 | | | $ | 337,319 | | | $ | 299,212 | | | | | |
Texas Pacific Land Corporation (NYSE: TPL) Investor Presentation – November 2024 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
$82.45 $78.46 $76.77 $80.93 $75.53 60.0 65.0 70.0 75.0 80.0 85.0 3Q 2023 4Q 2023 1Q 2024 2Q 2024 3Q 2024 9.2 11.5 10.9 10.6 11.4 6.0 7.5 7.0 7.1 8.4 6.6 7.3 7.0 7.3 8.5 21.8 26.3 24.8 24.9 28.3 - 5.0 10.0 15.0 20.0 25.0 30.0 3Q 2023 4Q 2023 1Q 2024 2Q 2024 3Q 2024 Oil Gas NGL 545 517 687 800 720 0 200 400 600 800 3Q 2023 4Q 2023 1Q 2024 2Q 2024 3Q 2024 3Q 2024 Summary Financial and Operating Update 3 O&G Royalty Production Total Water Sales Volumes1 Oil Realizations Produced Water Royalty Volumes (mboe/d) (mbbl/d) ($/bbl) (mbbl/d) 2,497 2,747 2,807 3,321 3,649 1000 1500 2000 2500 3000 3500 4000 3Q 2023 4Q 2023 1Q 2024 2Q 2024 3Q 2024 Note: Adjusted EBITDA and Free Cash Flow are non-GAAP measures. See Appendix for reconciliations of these non-GAAP measures to net income. (1) Reflects sourced, treated, and brokered sales volumes 3Q 2023 4Q 2023 1Q 2024 2Q 2024 3Q 2024 Selected consolidated financials ($MM): Oil and gas royalties 87.1$ 98.8$ 92.1$ 89.8$ 94.4$ Water sales 26.4 26.4 37.1 40.7 36.2 Produced water royalties 20.8 22.4 23.0 25.3 27.7 Easements and other surface income 18.2 19.1 20.6 16.6 14.3 Land sales and other 5.4 - 1.2 - 0.9 Total revenues 158.0$ 166.7$ 174.1$ 172.3$ 173.6$ Adj. EBITDA 141.0$ 150.9$ 152.0$ 153.2$ 144.1$ Adjusted EBITDA margin 89% 91% 87% 89% 83% % inc/(dec) - sequential Q/Q 6% 7% 1% 1% (6%) Free cash flow 106.1$ 116.3$ 114.5$ 116.0$ 106.9$ FCF Margin 67% 70% 66% 67% 62% % inc/(dec) - sequential Q/Q 1% 10% (2%) 1% (8%) Selected balance sheet data ($MM): Cash and cash equivalents 654.2$ 725.2$ 837.1$ 894.7$ 533.9$ Debt - - - - - Selected segment data ($MM): Land and Resource Management Revenue 109.9$ 116.8$ 111.5$ 104.0$ 106.6$ Adj. EBITDA 108.0 115.7 105.2 104.8 95.2 Net Income 82.9 88.8 81.0 80.1 71.9 Water Service and Operations Revenue 48.0$ 49.8$ 62.7$ 68.3$ 66.9$ Adj. EBITDA 33.0 35.2 46.8 48.5 48.9 Net Income 22.7 24.3 33.4 34.5 34.7
4
(1%) 4% 13% 17% 29% -10% 0% 10% 20% 30% WTI SPY Nasdaq TPL fsfsdfsfs 5 $37 $78 $160 $258 $128 $209 $365 $307 2016 2017 2018 2019 2020 2021 2022 2023 $5 $19 $50 $60 $48 $61 $81 $99 2016 2017 2018 2019 2020 2021 2022 2023 Value Creation Culture and Proven Performance Land & Resource Management Net Income ($ millions) Average Annual Total Return Since 2017 (Compounded annual return from 1/1/2017 to 12/31/2023) (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 $541 Million 2023 Adjusted EBITDA Balance Sheet Strength No Debt Cash Balance of $534 Million ~24,800 Core Permian Net Royalty Acres ~873,000 Surface Acres Diversified Revenue Streams: Royalties, Water, and Surface 100% Texas Permian Exposure Efficient conversion of revenues to cash $415 Million 2023 Free Cash Flow Robust Inventory of 673 DUCs and 496 Permits Decades of Cash Flow Runway Across Multiple Businesses ~270% Production growth since 2018 $$ 6Note: Operating data as of 12/31/2023. Balance Sheet and well inventory data as of 9/30/2024.
Texas Pacific Land Corporation (NYSE: TPL) TPL by the Numbers1 Market Value ($MM) $25,086 Cash & Equivalents ($MM) $534 Debt ($MM) $0 Net Royalty Acres (100% net basis) ~24,800 Normalized to 1/8th ~198,000 Surface Acres ~873,000 2023 Adj. EBITDA Margin 86% 2023 FCF Margin 66% Average daily trading volume (1-yr avg) ~104,000 Free Cash Flow ($MM)FY 2023 Revenues ($MM) One of the largest landowners in Texas with approximately 873,000 acres located in the Permian Basin TPL was originally organized in 1888 as a business trust to manage the property of the Texas and Pacific Railway Company; for nearly 130 years, this management was mostly passive In 2016, the Company embarked on a new strategy to maximize the value of its footprint through active management of surface and royalty interests Today, the business consists of numerous high-margin, capital-light revenue streams linked to Permian oil and gas development – Oil and Gas Royalties: high-margin royalty revenue derived from oil and gas production with no capital and minimal operating expense burden – Surface Leases, Easements and Material (“SLEM”): monetizes 3rd party development activities occurring on surface and royalty acreage – Texas Pacific Water Resources (“TPWR”): supplies water for oil and gas activities and facilitates produced water disposal solutions Adjusted EBITDA ($MM) 69% 31% Land & Resource Management Water Service & Operations $632M $63 $145 $245 $302 $239 $388 $592 $541 2016 2017 2018 2019 2020 2021 2022 2023 $40 $80 $160 $234 $188 $278 $452 $415 2016 2017 2018 2019 2020 2021 2022 2023 7Note: 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 9/30/2024. Market value and average daily trading volume as of 10/28/2024. 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 tracks 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% 38% 25% Revenue Contribution1 (FY 2023) 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-cap, small-cap, and privately held companies. 9
~79,000 ~23,000 ~21,000 ~7,000 ~6,000 ~3,000 Permian Motney Eagle Ford Bakken DJ SCOOP | Stack Permian Basin is a World-Class Resource Source: US EIA, OPEC, Baker Hughes, Enverus and Company data. Production figures represent 4Q 2023 averages. Estimated Remaining Well Locations with <$55/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 1.3 2.8 3.9 5.4 1.4 2.6 2.9 3.2 4.3 6.1 7.2 9.0 9.4 Russia Permian US ex- Permian OPEC Nigeria Kuwait UAE Iran Iraq Permian US ex- Permian Saudia Arabia Russia C R U D E (M M b b l/d ) N G L (M M b b l/d ) Permian vs Major Oil Producer Nations US Rig Counts by Oil Basin Delaware Midland 10 - 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 $333 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 YTD 2024 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 $0 Debt $534MM Cash $1 9 $5 0 $6 0 $4 8 $6 1 $8 1 $9 9 2017 2018 2019 2020 2021 2022 2023 $418 MM of cumulative net income since inception Surface and easement acquisitions Capital expenditures$145 million $131 million Water Services & Operations capex and related surface investments from 2017-2023 ($ in millions) Also generates significant SLEM cash flow Water Services & Operations Net Income ($ in millions) 11Note: Financial and operating data as of 12/31/2023. Balance sheet data as of 9/30/2024.
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 14% 24% 10% 51% Other Regular Dividend Share Repurchases Investing Activities Net Cash Increase 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 2023 Allocation of Operating Cash Flow 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 $40 $80 $160 $234 $188 $278 $452 $415 2016 2017 2018 2019 2020 2021 2022 2023 TPL Free Cash Flow ($ in millions) 12Note: Free Cash Flow is a non-GAAP measure. See Appendix for reconciliation of this non-GAAP measure to net income.
48% 17% 32% (18%) (61%) SLEM Produced Water Water Sales WTI Oil Henry Hub Natural Gas TPL’s Combined Surface and Royalties Is Unique SURFACE WATER ROYALTIES FY 2023 Performance (YOY) 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
TPL Maintains Top Tier Profitability Margins 12% 13% 21% 15% 50% 64% Oilfield Services (OIH) Midstream (AMLP) 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, AMLP, XOP, and S&P 500 data reflects last-twelve-months actuals as of 3/25/2024. Figures for OIH, AMLP, 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%, 14%] (14%, 19%] (19%, 24%] (24%, 28%] (28%, 33%] (33%, 38%] (38%, 43%] (43%, 47%] (47%, 52%] (52%, 57%] (57%, 61%] (61%, 66%] (66%, 71%] 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 64% FY 2023 net income margin TPL Land & Resource Management 71% FY 2023 net income margin TPL Water Services & Operations 50% FY 2023 net income margin TPL Water Services & Operations 14
Permian Activity Overview 15 3,150 263 286 3,092 237 374 2,989 177 622 ≤ 1 year 1 year < x ≤ 2 years 2 year < x ≤ 4 years 2024 2023 2022 - 1.0 2.0 3.0 4.0 5.0 6.0 1,394 1,314 1,553 1,379 1,473 1,551 1,496 1,598 1,524 1,527 1Q 2022 2Q 2022 3Q 2022 4Q 2022 1Q 2023 2Q 2023 3Q 2023 4Q 2023 1Q 2024 2Q 2024 <1 year 1 year < x ≤ 2 years > 2 years 1,614 1,765 1,649 1,407 1,897 1,671 1,841 1,608 1,766 2,056 1Q 2022 2Q 2022 3Q 2022 4Q 2022 1Q 2023 2Q 2023 3Q 2023 4Q 2023 1Q 2024 2Q 2024 Delaware Midland Permian Other Permian Well PermitsPermian Horizontal Rig CountsPermian Oil Production Permian Completion Counts (Grouped by DUC age at completion date) (mmbbl/d) 287 321 328 332 338 338 314 301 301 302 294 1Q 2022 2Q 2022 3Q 2022 4Q 2022 1Q 2023 2Q 2023 3Q 2023 4Q 2023 1Q 2024 2Q 2024 3Q 2024 DUCs as of June 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. Permian Well Permits, DUC Counts, and Completion Counts for 3Q 2024 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 2023 EBITDA and FCF margin of 86% and 66%, 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
Jay Gould Founder - Texas and Pacific Railway 17 TPL Gryffindor source water pit
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 typically 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 2016 2017 2018 2019 2020 2021 2022 2023 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 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 2016 2017 2018 2019 2020 2021 2022 2023 SLEM Revenue $8 $26 $64 $85 $55 $68 $85 $112 2016 2017 2018 2019 2020 2021 2022 2023 Water Sales $0 $6 $17 $39 $51 $58 $72 $84 2016 2017 2018 2019 2020 2021 2022 2023 Produced Water Royalties Revenue of Consolidated Revenues (FY 2023) 57% Note: Revenue percentages do not sum to 100% due to other ancillary revenue items. of Consolidated Revenues (FY 2023) 11% of Consolidated Revenues (FY 2023) 18% of Consolidated Revenues (FY 2023) 13% 18 ($ in millions) ($ in millions) ($ in millions) ($ in millions)
Oil and Gas Royalties Overview and Management - 500 1,000 1,500 2,000 2,500 3,000 3,500 4,000 4,500 Producing Horizontal Wells (Gross) on TPL Oil and Gas Royalty Acreage Revenue 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 19 Note: Company data as of 12/31/2023.
38.2 39.2 41.6 43.7 45.0 47.1 47.8 50.1 52.4 54.5 59.3 11.6 12.0 12.5 13.0 13.4 14.5 14.0 16.2 16.8 17.7 18.8 50.7 52.1 55.0 57.7 59.4 62.6 62.8 67.2 70.2 73.3 79.2 10.00 20.00 30.00 40.00 50.00 60.00 70.00 80.00 1Q 2022 2Q 2022 3Q 2022 4Q 2022 1Q 2023 2Q 2023 3Q 2023 4Q 2023 1Q 2024 2Q 2024 3Q 2024 Delaware Midland Permian Other TPL Royalty Production and Inventory Detail 0% 20% 40% 60% 80% 100% 120% 140% 1Q 2022 2Q 2022 3Q 2022 4Q 2022 1Q 2023 2Q 2023 3Q 2023 4Q 2023 1Q 2024 2Q 2024 3Q 2024 Oil as % of WTI Gas as % of Henry Hub NGLs as % of WTI 7.4 8.7 5.6 5.0 5.0 4.9 6.7 4.5 5.1 6.3 6.9 7.7 7.5 6.9 7.4 7.8 8.2 7.9 9.7 10.3 9.5 11.8 1.8 2.9 2.9 2.3 3.3 2.3 5.2 2.8 2.2 4.0 3.4 16.9 19.1 15.4 14.7 16.1 15.4 19.8 17.0 17.6 19.8 22.1 (1.0) 4.0 9.0 14.0 19.0 24.0 1Q 2022 2Q 2022 3Q 2022 4Q 2022 1Q 2023 2Q 2023 3Q 2023 4Q 2023 1Q 2024 2Q 2024 3Q 2024 Permits DUCs Completed 1.7 2.7 3.3 5.1 8.8 13.7 16.2 18.6 21.3 23.5 2014 2015 2016 2017 2018 2019 2020 2021 2022 2023 TPL Net Royalty Production (mboe/d) Average Lateral Lengths (feet) – New Spuds 1 TPL Commodity Price Realizations vs Benchmarks 9,652 9,966 10,190 10,726 10,619 2019 2020 2021 2022 2023 20 Producing Wells (net)Line-of-Sight Well Inventory (net) (1) Enverus well data as of 9/30/2024.
21 TPL source water infrastructure
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 $267MM FY 2023 Revenue 42% 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 TPL does not own or operate produced water disposal wells 1 2 3 Aggregate Contribution From Surface Estate + Active Management 22
35% 13%16% 10% 26% $100,000 $115,000 $132,250 Year 0 Year 10 Year 20 Surface, Leases, Easements and Materials (SLEM) Overview and Management $71MM 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 2023) Illustrative Easement Renewal Payment Revenue Mechanics and Management Easement contracts generally have two 10-year renewal payments at greater of 115% or CPI-escalation amount 23 Potential for subsequent renewal payments
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 2017 2018 2019 2020 2021 2022 2023 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 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 ~$5 – $10 million How TPL is Delivering ValueTPL Water Sales Volumes1Revenue Mechanics and Management (mbbl/d) 24(1) Reflects sourced, treated, and brokered sales volumes
Water Sales Asset Map storage capacity 600+ mbbl/d 24.5 mmbbl source water pipelines335 miles 327 354 388 410 412 448 478 2017 2018 2019 2020 2021 2022 2023 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 25 Note: Enverus and Company data as of 12/31/2023. (mbbls) sourced & 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 2017 2018 2019 2020 2021 2022 2023 “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 Average royalty fee of ~$0.09 - $0.11 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 How TPL is Delivering ValueRevenue Mechanics and Management TPL Produced Water Royalty Volumes (mbbl/d) 26
~680 ~1,220 ~180 ~290 First 12 months production First 36 months production 7.2 10.4 12.9 13.5 14.5 16.1 18.8 2017 2018 2019 2020 2021 2022 2023 Produced Water Royalties Delaware Upstream Activity + High Water-Cuts to Drive Produced Water Volume Growth Water vs Oil Production – Average Well in Delaware Basin 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 27 TPL has executed numerous AMI (Area of Mutual Interest) agreements with operators – produced water volumes within the AMI are subject to a royalty fee Source: B3 Insight, Enverus and Company Data. Delaware oil and water volumes based on horizontal wells completed since 1/1/2018. TPL also generates significant revenue from water that originates from wells located off TPL acreage, including from New Mexico
TPL Captures Revenue Over the Well Lifecycle 28 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 29 ~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
30
Appendix
Summary of Highest-Visibility Inventory Notes: Per Company data. Permian Basin horizontal locations as of 9/30/24. Permitted well conversion rate based on wells permitted from 10/1/22 through 9/30/23 and then drilled through 9/30/24. DUC well conversion rate based on wells drilled from 10/1/22 through 9/30/23 and then completed through 9/30/24. Completed well conversion rates based on wells completed between 10/1/22 through 9/30/23 . DUCs considered to be all wells awaiting completion. 100% NRI Permitted Wells 100% NRI DUC Wells 100% NRI Completed Wells 13% 0% 17% 6% 6% 9%9% 8% 32% 82% 18% 0% 7% 5% 12% 3% 3% 17% 22% 8% 23% 75% 18% 6% 1% 74% 26% 13% 6% 9% 14% 8% 25% 8% 17% N R I b y R eg io n N R I b y O p er at or ~87% of Permits are drilled within 6 months ~96% of Permits are drilled within 12 months ~40% of DUCs are completed within 6 months ~91% of DUCs are completed within 12 months ~93% of Completed Wells are listed as producing within ~1 month Northern Delaware Other Midland Southeast Delaware Southwest Delaware Permitted Wells: 6.9 DUC Wells: 11.8 Completed Wells: 3.4 Permitted Wells: 6.9 Completed Wells: 3.4 DUC Wells: 11.8 Other 32
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 33 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%
Why doesn’t TPL have a non- operated Water Sales commercial model where it extracts a royalty from allowing 3rd parties access to TPL’s water aquifers? Why does TPL need to spend capital and employ personnel? Water Sales – Operated vs Royalty/Non-Operated Business Model Sustainable Extraction Economic development Control Shareholder Interests Royalty / Non-Operated Source Water Model (i.e., pre-TPWR) Professional hydrologists, advanced sensors, and active monitoring to ensure aquifers are sustainably managed History TPL formed TPWR in July 2017 Pre-TPWR development, TPL had negotiated various royalty agreements with 3rd party operators Operators often extracted water resource at unsustainably high rates; primary concern was water for their own development/commercial needs rather than TPL’s long-term interests Efficiently developed infrastructure that could serve vast upstream development areas for virtually every nearby upstream operator Operator(s) would build relatively narrow water systems to serve only their own interests, rather than for broader commercial utilization for peer operators TPL could sell water at competitive prices, have control over expansion and market capture, and leverage its SLEM and produced water offerings to expand sales and incentivize development of royalty acreage Operators could leverage TPL’s royalty rates to negotiate better pricing for water off TPL acreage, thereby undercutting TPL sales/royalties ■ TPL manages Water Sales for the benefit and in the best interests of TPL shareholders ■ Water Sales has provided TPL shareholders with significant incremental earnings and free cash flow Operators utilizing TPL source water resource have their own stakeholders, whose interests may not align with TPL shareholder interests 34 FAQ
Compensation Incentives Aligned With Shareholder Value Creation 35 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 margin (37.5% weight) Free cash flow per share (37.5% 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 16% 18% 33% 33% (1) Reflects target CEO compensation for 2023 as disclosed in the 2023 10-K.
Sustainability is Embedded in Our Strategy 36 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 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 - 41% of workforce are women and continual assessment of organizational dynamics to cultivate a more inclusive workforce
Our Environmental Management Initiatives 37 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 2020 2021 2022 2023 Emissions Scope 1 CO2 Emissions 18,987 16,159 10,590 13,819 Scope 2 CO2 Emissions 5,110 6,596 11,492 10,572 Total Scope 1 + Scope 2 24,097 22,755 22,082 24,391 Methane Emissions 0 0 0 0 $303 $451 $667 $632 24.1 22.8 22.1 24.4 0 10 20 30 40 50 60 70 80 $0 $100 $200 $300 $400 $500 $600 $700 $800 2020 2021 2022 2023 TPL Revenue ($ 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) 0 45 0 0 Please visit the TPL Website for our full ESG Disclosures Energy Management – TPWR Operations Total energy consumed (Gigajoules) 317,912 287,140 263,289 304,622 Percentage grid – electricity 12% 16% 29% 24% Percentage grid – renewables 3% 6% 13% 11% Percentage grid – fuel 85% 78% 58% 65% (1) (2) (1) These 45 bbls underwent full and successful remediation efforts (2) Calculated based on 2023 ERCOT data Safety Incidients Employee and Contractor Total Recordable Incident Rate –TRIR 0 1.59 0 0 Employee lost time incident rate 0 0.79 0 0 38
Focus Area Gross Royalty Acres Net Royalty Acres Average Royalty Gross DSU Acres Implied Avg Net Revenue Interest per well Northern Delaware 164,495 9,845 6.0% 419,450 2.3% Southeast Delaware 34,285 2,126 6.2% 101,993 2.1% Southwest Delaware 81,795 5,112 6.2% 168,459 3.0% Delaware 280,575 17,083 6.1% 689,902 2.5% Midland 218,102 3,057 1.4% 720,023 0.4% Other 110,928 4,631 4.2% 258,617 1.8% Total 609,606 24,771 4.1% 1,668,542 1.5% Royalty Key Terms 39 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 609,606 ■ 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) 198,170 = 609,606 * 4.1% / (1/8) ■ Gross Royalty Acres * Avg. royalty 24,771 = 609,606 * 4.1% ■ Total number of gross DSU acres 1,668,542 ■ Net Royalty Acres / Gross DSU Acres 1.5% = 24,771 / 1,668,542 (1) Excluding acres which are considered to be outside of the Permian Basin. Description How’s It Calculated 1
($ in millions) 2018 2019 2020 2021 2022 2023 3Q23 4Q23 1Q24 2Q24 3Q24 Net income $ 209.7 $ 318.7 $ 176.1 $ 270.0 $ 446.4 $ 405.6 $ 105.6 $ 113.1 $ 114.4 $ 114.6 $ 106.6 Income tax expense 52.0 83.6 43.6 93.0 122.5 111.9 29.4 32.0 31.6 31.9 28.8 Depreciation, depletion and amortization 2.6 8.9 14.4 16.3 15.4 14.8 3.6 3.9 3.8 4.1 5.8 EBITDA $ 264.3 $ 411.2 $ 234.1 $ 379.3 $ 584.2 $ 532.3 $ 138.5 $ 149.0 $ 149.8 $ 150.5 $ 141.2 Revenue $ 300.2 $ 490.5 $ 302.6 $ 451.0 $ 667.4 $ 631.6 $ 158.0 $ 166.7 $ 174.1 $ 172.3 $ 173.6 EBITDA Margin 88.0 % 83.8 % 77.4 % 84.1 % 87.5 % 84.3 % 87.7 % 89.4 % 86.0 % 87.4 % 81.3 % EBITDA $ 264.3 $ 411.2 $ 234.1 $ 379.3 $ 584.2 $ 532.3 $ 138.5 $ 149.0 $ 149.8 $ 150.5 $ 141.2 Adjustments: Less: land sales deemed significant — (122.0) — — — — — — — — — Less: sale of oil and gas royalty interests (18.9) — — — — — — — — — — Add: proxy contests, settlement, and corporate reorganization costs — 13.0 5.1 8.7 — — — — — — — Add: employee share-based compensation — — — — 7.6 9.1 2.5 1.9 2.2 2.7 2.9 Adjusted EBITDA $ 245.4 $ 302.2 $ 239.1 $ 388.0 $ 591.8 $ 541.4 $ 141.0 $ 150.9 $ 152.0 $ 153.2 $ 144.1 Adjusted Revenue $ 281.3 $ 368.5 $ 302.6 $ 451.0 $ 667.4 $ 631.6 $ 158.0 $ 166.7 $ 174.1 $ 172.3 $ 173.6 Adjusted EBITDA Margin 87.2 % 82.0 % 79.0 % 86.0 % 88.7 % 85.7 % 89.3 % 90.6 % 87.3 % 88.9 % 83.0 % Adjusted EBITDA $ 245.4 $ 302.2 $ 239.1 $ 388.0 $ 591.8 $ 541.4 $ 141.0 $ 150.9 $ 152.0 $ 153.2 $ 144.1 Adjustments: Less: current income tax expense (37.2) (57.5) (46.0) (93.3) (121.2) (110.5) (29.7) (29.6) (31.9) (30.8) (27.4) Less: capex (47.9) (32.7) (5.1) (16.4) (19.0) (15.4) (5.2) (5.0) (5.7) (6.5) (9.8) Add: tax impact of land sales deemed significant — 21.5 — — — — — — — — — Free cash flow $ 160.3 $ 233.5 $ 188.0 $ 278.3 $ 451.6 $ 415.5 $ 106.1 $ 116.3 $ 114.5 $ 116.0 $ 106.9 Year ended December 31, Three months ended, 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. Sale of nonparticipating perpetual oil and gas royalty interest in approximately 812 net royalty acres (1/8th interest) of ~$19 million. 3. Costs related to proxy contest to elect a new Trustee, settlement agreement and corporate reorganization. 4. Excludes land sales deemed significant and sales of oil and gas royalty interests. 40 (1) (2) (3) (4)
Non-GAAP Reconciliations - Segment Source: Company data. Note: Numbers may not foot due to immaterial rounding. 41 Land and Resource Management Water Services and Operations ($ in millions) 3Q23 4Q23 1Q24 2Q24 3Q24 2022 2023 3Q23 4Q23 1Q24 2Q24 3Q24 2022 2023 Net income $ 82.9 $ 88.8 $ 81.0 $ 80.1 $ 71.9 $ 365.0 $ 306.7 $ 22.7 $ 24.3 $ 33.4 $ 34.5 $ 34.7 $ 81.3 $ 98.9 Income tax expense 22.9 25.0 22.3 22.2 19.4 100.3 84.3 6.4 7.0 9.3 9.7 9.5 22.2 27.6 Depreciation, depletion and amortization 0.7 0.8 0.7 0.8 2.1 2.2 3.1 2.9 3.0 3.1 3.3 3.6 13.1 11.7 EBITDA $ 106.5 $ 114.7 $ 103.9 $ 103.1 $ 93.4 $ 467.6 $ 394.1 $ 32.0 $ 34.3 $ 45.9 $ 47.4 $ 47.8 $ 116.6 $ 138.2 Revenue $ 109.9 $ 116.8 $ 111.5 $ 104.0 $ 106.6 $ 507.0 $ 432.1 $ 48.0 $ 49.8 $ 62.7 $ 68.3 $ 66.9 $ 160.4 $ 199.5 EBITDA Margin 96.9 % 98.1 % 93.2 % 99.1 % 87.5 % 92.2 % 91.2 % 66.6 % 68.9 % 73.3 % 69.4 % 71.5 % 72.7 % 69.3 % EBITDA $ 106.5 $ 114.7 $ 103.9 $ 103.1 $ 93.4 $ 467.6 $ 394.1 $ 32.0 $ 34.3 $ 45.9 $ 47.4 $ 47.8 $ 116.6 $ 138.2 Adjustments: Add: employee share-based compensation 1.5 1.1 1.3 1.6 1.8 4.7 5.3 1.0 0.8 0.9 1.1 1.1 2.9 3.8 Adjusted EBITDA $ 108.0 $ 115.7 $ 105.2 $ 104.8 $ 95.2 $ 472.3 $ 399.4 $ 33.0 $ 35.2 $ 46.8 $ 48.5 $ 48.9 $ 119.6 $ 142.0 Adjusted Revenue $ 109.9 $ 116.8 $ 111.5 $ 104.0 $ 106.6 $ 507.0 $ 432.1 $ 48.0 $ 49.8 $ 62.7 $ 68.3 $ 66.9 $ 160.4 $ 199.5 Adjusted EBITDA Margin 98.3 % 99.1 % 94.4 % 100.7 % 89.2 % 93.2 % 92.4 % 68.7 % 70.6 % 74.7 % 71.0 % 73.1 % 74.5 % 71.2 % Adjusted EBITDA $ 108.0 $ 115.7 $ 105.2 $ 104.8 $ 95.2 $ 472.3 $ 399.4 $ 33.0 $ 35.2 $ 46.8 $ 48.5 $ 48.9 $ 119.6 $ 142.0 Adjustments: Less: current income tax expense (23.3) (22.6) (22.5) (21.1) (18.5) (98.7) (82.8) (6.5) (7.0) (9.4) (9.7) (9.0) (22.5) (27.7) Less: capex — (0.1) (0.1) (0.1) (0.1) (0.4) (0.2) (5.2) (5.0) (5.6) (6.4) (9.8) (18.6) (15.2) Free cash flow $ 84.7 $ 93.1 $ 82.6 $ 83.6 $ 76.6 $ 373.2 $ 316.4 $ 21.3 $ 23.2 $ 31.9 $ 32.4 $ 30.2 $ 78.5 $ 99.1 Quarterly Annual Quarterly Annual
Historical Financial Summary 42 ($ in millions) 2022 2023 September 30, 2023 September 30, 2024 Total Acres 874,366 868,446 868,446 873,115 Revenues: Oil and gas royalties $452.4 $357.4 $87.1 $94.4 Water sales 84.7 112.2 26.4 36.2 Produced water royalties 72.2 84.3 20.8 27.7 Easements and other surface-related income 48.1 70.9 18.2 14.3 Land sales and other operating revenue 10.0 6.8 5.4 0.9 Total Revenues $667.4 $631.6 $158.0 $173.6 Expenses: Salaries and related employee benefits $41.4 $43.4 $11.5 $14.0 Water service related expenses 17.5 33.6 8.6 11.7 General and administrative expenses 13.3 14.9 3.9 4.0 Legal and professional fees 8.7 31.5 1.7 8.3 Ad valorem taxes 8.9 7.4 1.8 2.2 Land Sales Expenses — — — 0.2 Depreciation, depletion and amortization 15.4 14.8 3.6 5.8 Total operating expenses $105.1 $145.5 $31.0 $46.2 Operating income (loss) $562.3 $486.1 $127.0 $127.3 Margin (%) 84.3 % 77.0 % 80.4 % 73.4 % Other income (expense) 6.5 31.5 8.0 8.1 Income before income taxes $568.9 $517.6 $135.0 $135.4 Income tax expense 122.5 111.9 29.4 28.8 Net income $446.4 $405.6 $105.6 $106.6 Margin (%) 66.9 % 64.2 % 66.8 % 61.4 % Key balance sheet items: 2022 2023 3Q23 3Q24 Cash equivalents $510.8 $725.2 $654.2 $533.9 Total debt — — — — Total capital 772.9 1,043.2 964.6 1,052.1 Total assets 877.4 1,156.4 1,079.3 1,175.6 Total liabilities 104.5 113.2 114.8 123.4 Year ended December 31, Three months ended,
1700 Pacific Avenue, Suite 2900 Dallas, Texas 75201 Texas Pacific Land Corporation
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dei_EntityCentralIndexKey |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:centralIndexKeyItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionIndicate if registrant meets the emerging growth company criteria. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityEmergingGrowthCompany |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionCommission file number. The field allows up to 17 characters. The prefix may contain 1-3 digits, the sequence number may contain 1-8 digits, the optional suffix may contain 1-4 characters, and the fields are separated with a hyphen.
| Name: |
dei_EntityFileNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:fileNumberItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTwo-character EDGAR code representing the state or country of incorporation.
| Name: |
dei_EntityIncorporationStateCountryCode |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:edgarStateCountryItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionThe exact name of the entity filing the report as specified in its charter, which is required by forms filed with the SEC. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityRegistrantName |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionThe Tax Identification Number (TIN), also known as an Employer Identification Number (EIN), is a unique 9-digit value assigned by the IRS. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b-2
| Name: |
dei_EntityTaxIdentificationNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:employerIdItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionLocal phone number for entity.
| Name: |
dei_LocalPhoneNumber |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:normalizedStringItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 13e
-Subsection 4c
| Name: |
dei_PreCommencementIssuerTenderOffer |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 14d
-Subsection 2b
| Name: |
dei_PreCommencementTenderOffer |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTitle of a 12(b) registered security. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection b
| Name: |
dei_Security12bTitle |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:securityTitleItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionName of the Exchange on which a security is registered. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Number 240
-Section 12
-Subsection d1-1
| Name: |
dei_SecurityExchangeName |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:edgarExchangeCodeItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as soliciting material pursuant to Rule 14a-12 under the Exchange Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Exchange Act
-Section 14a
-Number 240
-Subsection 12
| Name: |
dei_SolicitingMaterial |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionTrading symbol of an instrument as listed on an exchange.
| Name: |
dei_TradingSymbol |
| Namespace Prefix: |
dei_ |
| Data Type: |
dei:tradingSymbolItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
| X |
- DefinitionBoolean flag that is true when the Form 8-K filing is intended to satisfy the filing obligation of the registrant as written communications pursuant to Rule 425 under the Securities Act. Reference 1: http://www.xbrl.org/2003/role/presentationRef
-Publisher SEC
-Name Securities Act
-Number 230
-Section 425
| Name: |
dei_WrittenCommunications |
| Namespace Prefix: |
dei_ |
| Data Type: |
xbrli:booleanItemType |
| Balance Type: |
na |
| Period Type: |
duration |
|
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