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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, DC 20549

FORM 10-K

(Mark One)

☒ | ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the fiscal year ended December 31, 2025

OR

☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number: 001-42150

LandBridge Company LLC

(Exact Name of Registrant as Specified in its Charter)

Delaware | 93-3636146
(State or other jurisdiction of incorporation or organization) | (I.R.S. Employer Identification No.)
5555 San Felipe Street, Suite 1200 Houston, Texas | 77056
(Address of principal executive offices) | (Zip Code)

Registrant’s telephone number, including area code: (713) 230-8864

Securities registered pursuant to Section 12(b) of the Act:

Title of Each Class |  | Trading Symbol(s) |  | Name of Each Exchange on Which Registered
Class A shares, representing limited liability company interests |  | LB |  | New York Stock Exchange
|  |  |  | NYSE Texas, Inc.

Securities registered pursuant to Section 12(g) of the Act: None

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ☐ No ☒

Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes ☐ No ☒

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer | ☒ | Accelerated filer | ☐ | Non-accelerated filer | ☐ | Smaller reporting company | ☒ | 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. ☐

Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of internal control over financial reporting under section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☒

If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of an error to previously issued financial statements. ☒

Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s executive officers during the relevant recovery period pursuant to § 240.10D-1(b). ☒

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

The aggregate market value o f common shares held by non-affiliates of the registrant as of June 30, 2025, the last business day of the registrant’s most recently completed second fiscal quarter, was approximately $1.7 billion based on the closing price of the registrant’s Class A shares representing limited liability company interests (“Class A shares”) on that date.

As of February 23, 2026, the registrant had 27,838,199 Class A shares and 49,250,916 Class B shares representing limited liability company interests (“Class B shares”) outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the Registrant’s definitive proxy statement for the 2026 Annual Meeting of Shareholders (the “2026 Proxy Statement”), which will be filed with the U.S. Securities and Exchange Commission (the “SEC”) within 120 days after December 31, 2025, a re incorporated by reference into Part III of this Annual Report on Form 10-K.

TABL E OF CONTENTS

|  | Page
Glossary | 3
Cautionary Note Regarding Forward-Looking Statements | 6
PART I
Item 1. | Business | 10
Item 1A. | Risk Factors | 30
Item 1B. | Unresolved Staff Comments | 56
Item 1C. | Cybersecurity | 56
Item 2. | Properties | 58
Item 3. | Legal Proceedings | 58
Item 4. | Mine Safety Disclosures | 58
PART II
Item 5. | Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities | 59
Item 6. | [Reserved] | 60
Item 7. | Management’s Discussion and Analysis of Financial Condition and Results of Operations | 61
Item 7A. | Quantitative and Qualitative Disclosures About Market Risk | 76
Item 8. | Financial Statements and Supplementary Data | 81
Item 9. | Changes in and Disagreements with Accountants on Accounting and Financial Disclosure | 110
Item 9A. | Controls and Procedures | 110
Item 9B. | Other Information | 112
Item 9C. | Disclosure Regarding Foreign Jurisdictions that Prevent Inspections | 112
PART III
Item 10. | Directors, Executive Officers and Corporate Governance | 112
Item 11. | Executive Compensation | 112
Item 12. | Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters | 112
Item 13. | Certain Relationships and Related Transactions, and Director Independence | 112
Item 14. | Principal Accountant Fees and Services | 112
PART IV
Item 15. | Exhibits and Financial Statement Schedules | 112
Item 16. | Form 10-K Summary | 113
| Signatures | 116

GLOSSARY

The following are abbreviations and definitions of certain terms used in this document, many of which are commonly used in the industry:

1918 Ranch Acquisition. The acquisition of approximately 38,000 total acres across Reeves, Loving, Winkler and Ward counties, Texas, and certain related assets from 1918 Ranch & Royalty, LLC. The acreage acquired consists of approximately 22,400 fee simple acres, approximately 12,000 leasehold acres and approximately 3,600 acres subject to a long-term management agreement.

2024 Acquisitions. The Lea County Acquisition, East Stateline Acquisition, Speed Acquisition, Winkler County Acquisition, Brininstool Acquisition and Wolf Bone Acquisition, collectively.

2025 Revolving Credit Facility. The revolving credit agreement entered into between DBR Land Holdings LLC, a subsidiary of LandBridge Company LLC, and Texas Capital Bank on November 18, 2025.

BLM. Bureau of Land Management.

Boe. A barrel of oil equivalent, which is used to express crude oil, NGL and natural gas volumes on a comparable crude oil equivalent basis. Gas equivalents are determined under the relative energy content method by using the ratio of 6.0 Mcf of natural gas to 1.0 Bbl of crude oil or NGL.

Bpd. Barrels per calendar day.

Brackish water. Water with salinity levels between seawater and freshwater.

Brininstool Acquisition. The acquisition of approximately 5,820 surface acres in Lea County, New Mexico, on November 22, 2024 from a private third-party seller.

Caliche. A naturally occurring material consisting of coarse sediment or weathered soil in calcium carbonate that is commonly used for building roads and surface locations.

Completion. The process of preparing a well for the production of oil and gas by injecting high-pressure fluids mixed with proppants to create fractures in reservoir rock to enhance permeability.

Crude oil. A mixture of hydrocarbons that exists in liquid phase in natural underground reservoirs and remains liquid at atmospheric pressure after passing through surface separating facilities.

Delaware Basin. A geological depositional and structural basin in West Texas and southern New Mexico, which is a part of the Permian Basin.

Division. The division of the then-current sole member of the Company, WaterBridge NDB LLC, into two Delaware limited liability companies in accordance with a plan of division prior to the IPO and corporate reorganization.

E&P. Oil and natural gas exploration and production.

E&P companies. Companies engaged in oil and natural gas exploration and production operations.

East Stateline Acquisition. The acquisition of the East Stateline Ranch on May 10, 2024, from a private third-party seller.

East Stateline Ranch. Approximately 103,000 surface acres in Loving and Winkler counties, Texas and Lea County, New Mexico, which were acquired on May 10, 2024, from a private third-party seller.

Five Point. Five Point Infrastructure LLC, a Delaware limited liability company and our financial sponsor.

GAAP. Accounting principles generally accepted in the United States of America.

GHG. Greenhouse gas.

Gross Mineral Acre. The total gross acres in which an owner owns a Mineral Interest or a royalty. For example, an owner who owns a 25%, or 1/4th, Royalty in 100 acres has 100 Gross Mineral Acres.

3

Henry Hub. A natural gas pipeline located in Erath, Louisiana that serves as the official delivery location for futures contracts on the NYMEX. The settlement prices at the Henry Hub are used as benchmarks for the entire North American natural gas market.

Indenture. The indenture entered into between DBR Land Holdings LLC, its subsidiaries and UMB Bank, N.A., as trustee in connection with the issuance of the Notes.

LandBridge. LandBridge Company LLC, a Delaware limited liability company.

LandBridge Holdings. LandBridge Holdings LLC, a Delaware limited liability company.

LBH Incentive Units. Management incentive units consisting of time-based awards of profits interests in LandBridge Holdings.

Lea County Acquisition. The acquisition of approximately 11,000 surface acres in Lea County, New Mexico on March 18, 2024, from a private third-party seller.

Legacy Acreage. The Company’s initial approximately 72,000 owned surface acres in Loving and Reeves County, Texas and Eddy County, New Mexico.

MBbls. One thousand barrels.

MBbl/d. One MBbl per day.

Mboe. One thousand BOE.

Mboe/d. One thousand BOE per day.

Mcf. One thousand cubic feet of natural gas.

Mineral interest. Real-property interests that grant ownership of oil and natural gas under a tract of land and the rights to explore for, develop, and produce oil and natural gas on that land or to lease those exploration and development rights to a third party.

MMBtu. One million British thermal units.

MMcf. One million cubic feet of natural gas.

NDB Incentive Units. Incentive units consisting of time-based awards of profits interests in NDB LLC granted to certain individuals prior to the Division.

NDB LLC. WaterBridge NDB LLC, a Delaware limited liability company.

Net Revenue Interest. The net royalty, overriding royalty, production payment and net profits interests in a particular tract or oil and natural gas well.

Net Royalty Acre. Mineral ownership standardized to a 100% royalty based on the actual number of Gross Mineral Acres in which such owner has an interest. For example, an owner who has a 25%, or 1/4th, royalty in 100 Gross Mineral Acres would hypothetically own 25 Net Royalty Acres (100 acres multiplied by 25%).

NGL. Natural gas liquid.

Northern Delaware Basin. The northern geographic region of the Delaware Basin consisting of portions of Eddy and Lea counties, New Mexico, and Loving, Reeves and Culberson counties, Texas, collectively.

Notes. The $500.0 million aggregate principal amount of 6.25% fixed-rate senior unsecured notes due 2030 issued by DBR Land Holdings LLC on November 25, 2025.

NYMEX. The New York Mercantile Exchange.

OpCo. DBR Land Holdings LLC, a Delaware limited liability company.

Operator. The individual or company responsible for the development and/or production of an oil or natural gas well.

Permian Basin. A large sedimentary basin located in West Texas and southeastern New Mexico.

4

Produced water. Water produced from an oil and natural gas well alongside crude oil and natural gas.

Produced water handling facilities. Facilities utilized for the treatment, handling and disposal of produced water.

Rod. A unit of measure equal to 16.5 feet that is measured in linear feet.

Royalty. A real property interest that entitles the owner the right to receive a portion of the production (or the proceeds therefrom) produced from the underlying real property or a payment for the use of such underlying real property, and does not require the owner to pay any portion of the production or development costs.

Sand mine. An area of land from which sand is being mined.

Speed Acquisition. The acquisition of the Speed Ranch on May 10, 2024, from a private third-party seller.

Speed Ranch. Approximately 34,000 surface acres in Lea County, New Mexico and Andrews County, Texas, which were acquired on May 10, 2024, from a private third-party seller.

Spot Market Price. The cash market price without reduction for expected quality, transportation and demand adjustments.

SUAs. Surface use agreements.

SURAs. Surface use royalty agreements.

Unproved reserves. Reserves that are based on geoscience and/or engineering data similar to that used in estimates of proved reserves, but technical or other uncertainties preclude such reserves being classified as proved reserves.

Waha Gas market hub. A natural gas hub in the Permian Basin of West Texas.

WaterBridge. WaterBridge Infrastructure LLC, a Delaware limited liability company (NYSE: WBI), and its subsidiaries.

WaterBridge NDB. WaterBridge NDB Operating LLC, a Delaware limited liability company.

WaterBridge Operating. WaterBridge Operating LLC, a Delaware limited liability company.

Weighted average lease royalty percentage. An expression of our average lease royalty percentage weighted on an acreage basis.

Winkler County Acquisition. The acquisition of approximately 1,280 surface acres in Winkler County, Texas on November 1, 2024 from a private third-party seller.

Wolf Bone Acquisition. The acquisition of approximately 46,000 surface acres in Reeves and Pecos counties, Texas, on December 19, 2024, from a subsidiary of VTX Energy.

WTI. West Texas Intermediate, a grade of crude oil commonly used in reference to pricing for crude oil.

5

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

The information in this Annual Report on Form 10-K (this “Annual Report”) includes “forward-looking statements” within the meaning of Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements, other than statements of historical fact, included in this Annual Report regarding our strategy, future operations, estimated revenues and losses, projected costs, prospects, plans and objectives of management are forward-looking statements. When used in this Annual Report, words such as “may,” “assume,” “forecast,” “could,” “would,” “should,” “will,” “plan,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “project,” “objective,” “budget” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words. These forward-looking statements are based on our current expectations and assumptions about future events and are based on currently available information as to the outcome and timing of future events at the time such statements were made. When considering forward-looking statements, you should keep in mind the risk factors and other cautionary statements described under the section entitled “Risk Factors” included elsewhere in this Annual Report. By their nature, forward-looking statements involve known and unknown risks and uncertainties because they relate to events and depend on circumstances that may or may not occur in the future. Although we believe that the forward-looking statements contained in this Annual Report are based on reasonable assumptions, you should be aware that many factors could affect our actual results of operations, cash flows and financial position and could cause actual results to differ materially from those in such forward-looking statements. Forward-looking statements may include, but are not limited to, statements about:

•
our customers’ demand for and use of our land and resources;
•
the success of WaterBridge in executing its business strategies, including its ability to construct infrastructure, attract customers and operate successfully on our land;
•
our customers’ ability to develop our land or any potential acquired acreage to accommodate any future surface use developments;
•
our ability to continue the payment of dividends;
•
the domestic and foreign supply of, and demand for, energy sources, including the impact of actions relating to oil price and production controls by the members of the Organization of Petroleum Exporting Countries (“OPEC”), Russia and other allied producing countries (together with OPEC, “OPEC+”), such as announcements of potential changes to oil production levels;
•
our reliance on a limited number of customers and a particular region for substantially all of our revenues;
•
our ability to enter into favorable contracts regarding surface uses, access agreements and fee arrangements, including the prices we are able to charge and the margins we are able to realize;
•
our business strategies and our ability to execute thereon, including our ability to attract non-traditional energy customers to use our land and resources;
•
the risk that we may not realize the anticipated benefits and synergies from our acquisitions and our ability to successfully integrate such acquisitions;
•
the costs associated with our acquisitions;
•
our level of indebtedness and our ability to service our indebtedness;
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commodity price volatility and trends related to changes in commodity prices, and our customers’ ability to manage through such volatility;
•
the level of competition from other companies, including those offering resources that compete with the resources from our land, such as sand and brackish water;
•
changes in the price charged to our customers and availability of services necessary for our customers to conduct their businesses, as a result of oversupply, government regulations or other factors;
•
the development of advances or changes in energy technologies or practices;
•
our ability to successfully implement our growth plans, including through future acquisitions of acreage and/or introduction of new revenue streams;
•
the potential deterioration of our customers’ financial condition and their ability to access capital to fund their development programs;
•
the degree to which consolidation among our customers may affect spending on U.S. drilling and completions in the near-term, including the recent consolidation in the Permian Basin;
•
our customers’ ability to obtain necessary supplies, raw materials and other critical components on a timely basis, or at all;
•
our and our customers’ ability to obtain government approvals or acquire or maintain necessary permits, including those related to the development and operation of produced water handling facilities, sand mines and brackish water wells;
•
operational disruptions and liability related thereto associated with our customers, including those due to environmental hazards, fires, explosions, chemical mishandling or other industrial accidents;

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•
our and our customers’ liquidity and ability to access the capital markets on favorable terms, or at all, which depends on general market conditions, including the impact of inflation, tariffs, interest rates and related governmental policies and potential economic recession;
•
condemnation proceedings affecting our land or our customers’ ability to access our lands;
•
our customers’ ability to obtain rights from our neighboring landowners on economic terms, or at all, to gain access to our land or transport resources such as sand and brackish water, away from our land, to their point of end use;
•
uncertainty surrounding potential legal, regulatory and policy changes, such as proposed tariffs, as well as the potential for general market volatility and political uncertainty;
•
impacts related to changing U.S. and foreign trade policies, including increased trade restrictions or tariffs;
•
the effects of geopolitical conflicts, domestic political uncertainties or armed conflict in oil and natural gas producing regions, which may decrease demand for oil and natural gas or contribute to volatility in the prices for oil and natural gas, which could decrease demand for the use of our land and resources;
•
the demand for sand and the amount of sand that customers on our land are able to excavate and process, which could be adversely affected by, among other things, operating difficulties and unusual or unfavorable geological conditions;
•
actions taken by the federal, local or state governments in relation to surface uses;
•
title defects in the acreage that we acquire;
•
the markets for surface acreage in the areas in which we operate and own or plan to own, including pricing estimates, availability of land and our ability to acquire such land on favorable terms, or at all;
•
our ability to integrate acquired acreage, and any future acquisitions, and manage growth;
•
our ability to recruit and retain key management and other personnel and the allocation of resources between LandBridge and WaterBridge;
•
actions taken by the federal or state governments, such as executive orders or new or expanded regulations, that may impact future energy production in the U.S.;
•
changes in laws and regulations (or the interpretation thereof), such as the One Big Beautiful Bill Act (the “OBBBA”), including those related to hydraulic fracturing, accessing water, disposing of wastewater, transferring produced water, interstate brackish water transfer, carbon pricing, pipeline construction, data privacy, taxation or emissions, leasing, permitting or drilling and various other environmental matters;
•
changes in effective tax rates, or adverse outcomes resulting from other tax increases or an examination of our income or other tax returns and tax inefficiencies;
•
the severity and duration of world health events, natural disasters or inclement or hazardous weather conditions, including cold weather, hurricanes, fires, droughts, earthquakes, flooding and tornadoes;
•
evolving cybersecurity risks, such as those involving unauthorized access, third-party provider defects and service failures, denial-of-service attacks, malicious software, data privacy breaches by employees or other service providers, insider or others with authorized access, cyber or phishing-attacks, ransomware, social engineering, physical breaches or other actions; and
•
other factors discussed elsewhere in this Annual Report including in the section titled “Risk Factors.”

We caution you that these forward-looking statements are subject to all of the risks and uncertainties, most of which are difficult to predict and many of which are beyond our control, incident to the operation of business in our industry. We disclose important factors that could cause our actual results to differ materially from our expectations under “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and elsewhere in this Annual Report. Factors that could materially adversely affect our business, financial condition, operating results or liquidity and the trading price of our Class A shares are described under “Risk Factors,” included in this Annual Report. This information should be considered carefully, together with other information in this report and other reports and materials we file with the SEC. Should one or more of the risks or uncertainties described in this Annual Report occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements. Moreover, we operate in a very competitive and rapidly changing environment. New risks emerge from time to time. It is not possible for our management to predict all risks, nor can we assess the impact of all factors on our business or the extent to which any factor, or combination of factors, may cause actual results to differ materially from those contained in any forward-looking statements we may make.

All forward-looking statements, expressed or implied, included in this Annual Report are expressly qualified in their entirety by this cautionary note. This cautionary note should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue. Except as otherwise required by applicable law, we disclaim any duty to update any forward-looking statements, all of which are expressly qualified by the statements in this section, to reflect events or circumstances after the date of this Annual Report.

Summary Risk Factors

An investment in our Class A shares involves risks and uncertainties that may materially adversely affect our business, financial condition and results of operations and cash flows. Some of the more significant challenges and risks relating to an investment in the

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Company are summarized below. The following is only a summary of the principal risks that may materially adversely affect our business, financial condition, results of operations and cash flows. The following should be read in conjunction with the more complete discussion of the risk factors we face, which are set forth in “Part I, Item 1A ─ Risk Factors” in this Annual Report.

Risks Related to Our Business and Operations

•
Our revenues are substantially dependent on ongoing oil and natural gas exploration, development and production activity on or around our land. If E&P companies do not maintain drilling, completion and production activities on or around our land, the demand for the use of our land and resources, as well as the royalties we receive from the production of oil and natural gas and related activities on our land, could be reduced, which could have a material adverse effect on our results of operations, cash flows and financial position.
•
The willingness of E&P companies to engage in drilling, completion and production activities on and around our land is substantially influenced by the market prices of oil and natural gas, which are highly volatile. A substantial or extended decline in oil and natural gas prices may adversely affect our results of operations, cash flows and financial position.
•
Future land acquisitions could expose us to risks associated with acquisitions and the commercialization of additional acreage.
•
Because a significant portion of our future revenue growth is expected to be derived from WaterBridge, any development that materially and adversely affects its respective business, operations or financial condition could have a material adverse impact on us.
•
Our reliance on WaterBridge and its personnel to manage and operate our business exposes us to certain risks.
•
Our acreage is located in the Permian Basin, making us vulnerable to risks associated with geographic concentration in a single geographic area.
•
We have a limited operating history, and an investment in our Class A shares is highly speculative. Because we have a limited operating history, it may be difficult to evaluate our ability to successfully implement our business strategy.
•
We may not be successful in pursuing additional commercial opportunities on our land from non-hydrocarbon based energy production and other users.
•
The construction by our customers of new infrastructure on our land is subject to regulatory, construction, supply chain and other risks common in the development and operation of facilities and other infrastructure.

Risks Related to Environmental and Other Regulations

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Our results of operations, cash flows and financial position are subject to major trends in our industry, such as decarbonization, and may be adversely affected by future developments that are outside of our control.
•
Legislation or regulatory initiatives intended to address seismic activity, over-pressurization or subsidence could restrict drilling, completion and production activities, as well as WaterBridge’s ability to handle produced water gathered from its customers, which could have a material adverse effect on our results of operations, cash flows and financial position.

Risks Related to Our Financial Condition

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We are subject to interest rate risk, which may cause our debt service obligations to increase significantly. The weighted average interest rate on borrowings outstanding under the 2025 Revolving Credit Facility as of December 31, 2025, was 6.13%.
•
We are subject to counterparty credit risk. Nonpayment or nonperformance by our customers could have an adverse effect on our results of operations, cash flows and financial position.
•
Our obligations under the 2025 Revolving Credit Facility are secured by a first priority security interest in substantially all of our assets and various guarantees.

Risks Related to Our Class A Shares

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Maintaining the requirements of being a public company, including compliance with the reporting requirements of the Exchange Act, and the requirements of the Sarbanes-Oxley Act, will increase demands on our resources, increase our costs and divert management’s attention, and we may be unable to comply with these requirements in a timely or cost-effective manner.
•
If we do not continue paying regular cash dividends on our Class A shares, you may not receive a return on investment unless you sell your Class A shares for a price greater than that which you paid for them.

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•
LandBridge Holdings has the ability to direct the voting of a majority of our common shares and control certain decisions with respect to our management and business, including certain consent rights and the right to designate more than a majority of the members of our board of directors as long as it and its affiliates beneficially own at least 40% of our outstanding common shares, as well as lesser director designation rights as long as it and its affiliates beneficially own less than 40% but at least 10% of our outstanding common shares. LandBridge Holdings’ interests may conflict with those of our other shareholders.
•
LandBridge Holdings, Five Point and WaterBridge, as well as their affiliates, are not limited in their ability to compete with us, and may benefit from opportunities that might otherwise be available to us.
•
There are certain provisions in our Operating Agreement regarding fiduciary duties of our directors, exculpation and indemnification of our officers and directors and the approval of conflicted transactions that differ from the Delaware General Corporation Law (the “DGCL”) in a manner that may be less protective of the interests of our public shareholders and restrict the remedies available to shareholders for actions taken by our officers and directors that might otherwise constitute breaches of fiduciary duties if we were subject to the DGCL.
•
Certain of our directors and officers may have significant duties with, and spend significant time serving, other entities, including entities that may compete with us in seeking acquisitions and business opportunities, and, accordingly, may have conflicts of interest in allocating time or pursuing business opportunities.
•
The U.S. federal income tax treatment of dividends on our Class A shares to a holder will depend upon our tax attributes and the holder’s tax basis in our common shares, which are not necessarily predictable and can change over time, and could cause taxable gain or loss on the sale of our Class A shares to be more or less than expected.

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PART 1

Item 1. Business

LandBridge was formed on September 27, 2023 as a Delaware limited liability company to serve as the issuer in an initial public offering of equity, which closed on July 1, 2024 (the “IPO”). LandBridge is a holding company, the principal asset of which is membership interests in OpCo. LandBridge is also the sole managing member of OpCo. Unless otherwise indicated or the context otherwise requires, references in this Annual Report to “LandBridge”, “us,” “we,” “our” or the “Company” are to (i) OpCo and its subsidiaries before the completion of the corporate reorganization in connection with the IPO (the “Corporate Reorganization”) and (ii) LandBridge and its subsidiaries as of the completion of the Corporate Reorganization.

Company Overview

Land is a fundamental requirement for the development and production of energy and the construction and operation of critical infrastructure. As of December 31, 2025, we owned or managed more than 315,000 surface acres in and around the Delaware Basin sub-region in the prolific Permian Basin, which is the most active area for oil and natural gas exploration and development in the United States. Access to expansive surface acreage is necessary for oil and natural gas development, solar power generation, power storage, digital infrastructure and non-hazardous oilfield reclamation and solid waste facilities. Further, the significant industrial economy that exists to service and support energy and infrastructure development requires access to surface acreage to support those activities. Our strategy is to actively manage our land and resources to support and encourage energy and infrastructure development and other land uses that will generate long-term revenue and Free Cash Flow for us and returns to our shareholders. Please see “How We Evaluate Our Operations” for more information regarding Free Cash Flow.

The Delaware Basin is characterized by the abundant remaining oil and natural gas resources and low break-even cost of development. Activity in the Delaware Basin is dominated by large, generally publicly-listed, well-capitalized producers. Our land is located predominantly in the heart of the Delaware Basin, along and near the regulatory divide of the Texas-New Mexico state border. This area represents some of the most productive acreage in the Delaware Basin, with a high concentration of hydrocarbons and elevated levels of drilling and completion activity. We believe that our strategic location positions us to capture additional revenues from the growth in infrastructure required to facilitate the development of these resources.

We share a financial sponsor, Five Point, and our management team with WaterBridge. WaterBridge is one of the largest water midstream companies in the United States and operates a large-scale network of pipelines and other infrastructure in the Delaware Basin that, as of December 31, 2025, handles approximately 2.5 million bpd of water associated with oil and natural gas production, with approximately 4.2 million bpd of total handling capacity. These relationships provide our shared management team visibility into key areas of oil and natural gas production and long-term trends, which we leverage to encourage and support the development of critical infrastructure on our land and generate additional revenue for us. Since we acquired our initial acreage, WaterBridge has constructed or acquired, as of December 31, 2025, approximately 1.5 million bpd of water handling capacity on our land, with approximately 3.2 million bpd of permitted capacity available for future development on our land. We receive royalties for each barrel of produced water that WaterBridge handles on our land as well as surface use payments for infrastructure constructed on our land.

Five Point and our management team formed LandBridge to acquire, manage and expand a strategic land position in the heart of the Delaware Basin to support the development of WaterBridge’s large-scale produced water handling infrastructure and to actively manage our land and resources to support and encourage broader industrial and commercial development. Since our formation, our management and Five Point have successfully started and expanded businesses that generate new and growing sources of revenue for us by capturing and monetizing commercial activity both on and near our land. Examples of the benefits of these relationships include WaterBridge’s strategic relationship with Devon Energy, which supports the development of significant additional infrastructure on and around our land. We believe that WaterBridge’s future growth will continue to underpin increased revenues for us, into which we have significant visibility and that requires minimal investment by us. Additionally, WaterBridge operates non-hazardous oilfield reclamation and solid waste facilities that are located on our land.

In addition to our relationship with WaterBridge, we have actively grown third-party revenues. We utilize a collaborative commercial approach with a diversified customer base to provide availability, timing and consistent terms for our customers’ development activities on our land. As a landowner, we benefit from these activities by charging fees and royalties based on our customers’ usage of our land and resources. Furthermore, the cost of development on our land is primarily borne by our customers, allowing us to benefit from their growth on our land while deploying minimal capital of our own. In furtherance of our strategy, we and WaterBridge entered into agreements with Texas Pacific Land Corporation (“TPL”), one of the largest landowners in Texas, to provide reciprocal crossing rights and produced water royalty and revenue sharing across an area of mutual interest that provides our customers (including WaterBridge) with greater development efficiency and enables them to increase their operations on our land. Please see “Business—Our Assets—Our Stateline Position” for more information related to our agreements with TPL.

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We generate multiple revenue streams from the use of our surface acreage, the sale of resources from our land and oil and gas royalties.

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Surface Use Royalties and Revenues: We receive fees from our customers for the use of our surface acreage for their business operations, which currently include oil and natural gas development, produced water transportation and handling, pipeline and electrical infrastructure, digital infrastructure, a commercial fuel distribution facility and other commercial and industrial activities, including non-hazardous oilfield reclamation and solid waste facilities.
•
Resource Sales and Royalties: We receive fees from the sale of resources from our land, including sales of brackish water and caliche primarily utilized in connection with oil and natural gas well development, and royalties from sand and brackish water extracted from our land primarily utilized for oil and natural gas well completions. These resources are used by our customers in their projects on and around our land and elsewhere throughout the Delaware Basin.
•
Oil and Gas Royalties: We receive a share of recurring revenues from the production of oil and natural gas on our approximate 4,400 gross mineral acres through our ownership of mineral interests, of which approximately 96% underlie our surface acreage. Other than our gross mineral acres, we do not own the mineral interests that underlie our surface acreage.

A key attribute of our business model is entering into agreements under which our customers bear substantially all of the operating and capital expenditures related to their operations on our land, with minimal capital requirements of our own for both current and future commercial opportunities, resulting in the ability to create significant Free Cash Flow. The following table summarizes our financial performance for the periods shown:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |  |  | 2023 |
|  | (in thousands) |
Total revenues |  | $ | 199,093 |  |  | $ | 109,954 |  |  | $ | 72,865 |
Net income (loss) (1) |  | $ | 72,399 |  |  | $ | (41,479 | ) |  | $ | 63,172 |
Adjusted EBITDA (2) |  | $ | 177,171 |  |  | $ | 97,069 |  |  | $ | 62,804 |
Cash flows from operating activities |  | $ | 126,273 |  |  | $ | 67,636 |  |  | $ | 53,042 |
Capital expenditures |  | $ | (4,236 | ) |  | $ | (985 | ) |  | $ | (2,783 | )
Free Cash Flow (2) |  | $ | 122,037 |  |  | $ | 66,651 |  |  | $ | 50,259 |

(1) Net income for the year ended December 31, 2025, includes non-cash share-based compensation expense of $45.3 million, of which $8.8 million is attributable to RSUs issued by the Company and $36.5 million is attributable to LBH Incentive Units. Net loss for the year ended December 31, 2024, includes non-cash share-based compensation expense of $95.3 million, of which $4.0 million is attributable to RSUs issued by the Company, $72.6 million is attributable to NDB Incentive Units and $18.7 million is attributable to LBH Incentive Units. Net income for the year ended December 31, 2023 includes non-cash share-based compensation income of $17.2 million attributable to the NDB Incentive Units. Any actual cash expense associated with the LBH Incentive Units is borne solely by LandBridge Holdings and not the Company. Distributions attributable to LBH Incentive Units are based on returns received by investors of LandBridge Holdings once certain return thresholds have been met and are neither an obligation of the Company nor taken into consideration for distributions to investors in the Company.

(2) Adjusted EBITDA and Free Cash Flow are non-GAAP financial measures. See “Management’s Discussion and Analysis of Financial Condition and Results of Operation—Non-GAAP Financial Measures” for more information regarding these non-GAAP measures and reconciliations to the most comparable GAAP measures.

Active Land Management

We actively manage the commercial development of our land, seeking to maximize the long-term value of our surface acreage and our resources by identifying and developing, or supporting the development of, new uses and revenues from our land. Unlike landowners focused primarily on agricultural or livestock operations, we proactively promote our land as a location for commercial and industrial uses, and we offer our customers an efficient contracting process that provides a holistic solution to their operational needs.

We target opportunities that make the most efficient use of our surface acreage, allow the same surface acreage to be used for multiple activities and/or improve the value of the surrounding acreage. We have entered into, or are currently pursuing, primarily long-term commercial relationships with businesses focused on oil and gas development, solar power generation, microgrids, power storage, cryptocurrency mining and data management, as well as other renewable energy production, among other industries and applications. Similar to the other operations conducted on our land, we expect to enter into surface use or similar agreements with the owners of these projects from which we expect to receive surface use fees and other payments in connection with the utilization of our land, but we do not expect to own or operate such projects or expect to incur significant capital expenditures in connection therewith.

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We measure our revenue divided by our acreage as a performance metric, which we refer to as “surface use economic efficiency.” The surface use economic efficiency metric for the years ended December 31, 2025 and 2024 are shown in the following table:

|  | Total |  |  | Weighted average acreage (2) |  |  | Surface use economic efficiency (3) (4) |  |  | Variance |
|  | acreage (1) |  |  | 2025 |  |  | 2024 |  |  | 2025 |  |  | 2024 |  |  | Percent |
|  |  |  |  |  |  |  |  |  |  | (in thousands) |  |  |  |
Legacy acreage |  |  | 72,000 |  |  |  | 72,000 |  |  |  | 72,000 |  |  | $ | 1,159 |  |  | $ | 1,018 |  |  |  | 14 | %
2024 Acquisitions |  |  | 203,000 |  |  |  | 203,000 |  |  |  | 101,008 |  |  | $ | 499 |  |  | $ | 204 |  |  |  | 145 | %
2025 Acquisitions |  |  | 42,000 |  |  |  | 8,479 |  |  |  | - |  |  | $ | 208 |  |  | $ | - |  |  | - % |
Total |  |  | 317,000 |  |  |  | 283,479 |  |  |  | 173,008 |  |  | $ | 658 |  |  | $ | 543 |  |  |  | 21 | %

(1)
Total acreage is rounded and reflects fee surface acres, together with leasehold acres and acreage subject to a long-term management agreement.
(2)
In the year of acquisition, weighted average surface acreage is calculated for the period of ownership during the year of acquisition to align with the revenues earned during the period of ownership in that year.
(3)
Surface use economic efficiency is calculated as “Total revenues” less “Oil and gas royalties” from our consolidated statements of operations divided by the weighed average surface acres owned during the period.
(4)
May not sum or recalculate due to rounding.

The increase in our surface use economic efficiency reflects the application of our active land management strategy, including the optimization and expansion of commercial and surface use agreements.

Land and Produced Water Relationship

Produced water naturally exists in underground formations and is brought to the surface during crude oil and natural gas production throughout the entire life of an oil or natural gas well. Produced water must be reliably separated and handled in order for these wells to be brought online and remain in production. The gathering, treating, handling and recycling of produced water requires both access to significant surface acreage for operations and subsurface reservoirs that are porous, uniform and stable where produced water can be injected and sequestered.

Access to significant surface acreage and subsurface reservoirs for produced water handling is of particular importance to operators in the Delaware Basin, as the Delaware Basin has experienced significant growth in oil and natural gas production activity over the last three years with a resultant increase in produced water volumes. We believe that this growth in oil and natural gas production activity will require increased produced water handling capacity, as the amount of produced water produced from wells in the Delaware Basin significantly exceeds the amount of the related oil and natural gas production.

Produced water handling facilities and their access to specific geologic zones are regulated at the state level and are required to meet guidelines imposed by the relevant state agencies. Because the Delaware Basin straddles the Texas-New Mexico state border, the planning, permitting and building of produced water infrastructure is dependent upon the laws and regulations of either Texas or New Mexico.

In contrast to New Mexico, Texas generally provides a more favorable regulatory environment for produced water permitting. The combination of favorable geological characteristics and a comparatively less restrictive regulatory environment drives increased demand for produced water handling facilities on the Texas side of the Texas-New Mexico state border. Our Stateline and Northern Positions benefit from the demand for surface acreage and pore space in Texas that is driven by the regulatory divide between Texas and New Mexico and the level of oil and gas activity in the Northern Delaware Basin. Please see “—Our Assets—Our Stateline Position” and “— Our Assets—Our Northern Position” for more information.

New Mexico also presents a more restrictive regulatory and hydrological environment for sourcing brackish water used for oil and natural gas well completion activity. As a result, much of the brackish water supplied to the oil and natural gas industry in New Mexico is sourced from Texas. Our Stateline and Northern Positions contain significant underground brackish water resources from which brackish water can be produced for sale to companies that deliver this water to E&P companies in New Mexico for use in their drilling and completion activities.

We believe that expected future growth of produced water volumes in the Delaware Basin will require incremental pore space to ensure proper handling. We also believe that our large land position strategically located at the intersection of significant producer activity and access to largely underutilized pore space offers critical capacity for produced water disposal, along with our management team’s extensive experience in the produced water industry, uniquely positions us to provide producers and produced water companies with access to our land and pore space to establish large-scale, reliable produced water handling solutions, from which we will generate multiple revenue streams, including the sale of resources from our land and produced water handling royalties.

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Our Assets

We own or manage more than 315,000 surface acres in and around the Delaware Basin in Texas and New Mexico, the most active oil and natural gas development and production region of the United States, as of December 31, 2025. Our surface acreage is located across three separate areas, which we refer to as our Stateline, Northern and Southern Positions. Our land positions are shown below.

Overview of our Land Position

Our Stateline Position

Our Stateline Position consists of approximately 169,000 surface acres located primarily in Loving, Reeves and Winkler Counties, Texas, and Lea County, New Mexico, near and along the Texas-New Mexico state border, as of December 31, 2025. Our Stateline Position comprises a significant and large land position and geological formations that are generally characterized by high permeability and porosity, that we believe will enable reliable water handling. There are substantial hydrocarbon resources under and in close proximity to our Stateline Position, which attracts high-quality, well-capitalized producers, including Devon Energy, EOG Resources, ConocoPhillips, Continental Resources, Admiral Permian and Occidental Petroleum. We believe that our geographic proximity to the operations of large, well-capitalized producers positions us to benefit from anticipated growth in oil and natural gas development on and around our land.

The western portion of our Stateline Position is semi-contiguous, or checkerboarded, with surface acreage held by TPL, one of the largest landowners in Texas. The nature of the checkerboarded acreage results in E&P companies, midstream companies, service companies and other operators in the area generally needing to access both our and TPL’s surface acreage for rights of way. In order to unlock opportunities for the checkerboarded surface acreage, we, together with WaterBridge, entered into agreements with TPL that established an approximate 64,000 acre area of mutual interest (the “Stateline AMI”) across much of the western portion of our Stateline Position and the adjacent TPL surface acreage. These agreements provide reciprocal crossing rights as well as royalty and revenue sharing across the Stateline AMI, and provides our customers, including WaterBridge, the certainty necessary to develop

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large scale infrastructure assets on and around such land. Please see “—Our Assets—Our Stateline Position” for more information related to our agreements with TPL.

As of December 31, 2025, WaterBridge and third party operators collectively operated approximately 1.9 million bpd of existing produced water handling capacity on our Stateline Position. We believe that the pore space underlying our Stateline Position will be able to support approximately 3.2 million bpd of additional produced water handling capacity, assuming approximately 27,000 bpd produced water handling permits on average and approximately one kilometer of spacing between all future produced water handling facilities.

The eastern portion of our Stateline Position includes approximately 116,000 surface acres in Winkler and Loving counties, Texas and Lea County, New Mexico, as of December 31, 2025. WaterBridge operates produced water handling infrastructure and a brackish water supply system that serves producers active on the East Stateline Ranch, including ConocoPhillips, Continental Resources, Devon Energy and Occidental Petroleum. These producers are subject to SUAs that govern commercial activities on the East Stateline Ranch. In addition, we believe that the East Stateline Ranch contains substantial sand resources, which we expect to support additional sand mine developments over time and generate surface use revenue for us in connection with the utilization of our land.

Although oil and natural gas production and related services account for a large majority of the activity in our Stateline Position, we anticipate there will be opportunities with developers seeking to build data centers, cryptocurrency mining facilities, power generation facilities, microgrids and power storage facilities and commercial fueling stations across our Stateline Position.

Our Northern Position

Our Northern Position, which includes land positions in Eddy and Lea counties, New Mexico and Andrews County, Texas, consists of approximately 61,000 fee-owned surface acres and 33,000 additional surface acres leased from the BLM and the State of New Mexico on a year-to-year basis as of December 31, 2025.

Our Northern Position supports much needed water infrastructure development to serve oil and natural gas development in the northern part of the Delaware Basin. We believe that there is a need for produced water systems serving central and northern Lea and Eddy counties to transport produced water east out of the Delaware Basin. The Speed and Lea County Ranches within our Northern Position provide critical access to pore space that we believe will be able to handle significant produced water volumes.

As of December 31, 2025, WaterBridge and third party operators collectively operated approximately 158,000 bpd of existing produced water handling capacity on our Northern Position. We believe that the pore space underlying our Northern Position will be able to support approximately 1.4 million bpd of additional produced water handling capacity, assuming approximately 32,000 bpd produced water handling permits on average and one kilometer of spacing between all future produced water handling facilities.

Our Southern Position

Our Southern Position consists of approximately 87,000 surface acres located in Reeves, Ward and Pecos counties, Texas in the Delaware Basin as of December 31, 2025. Various producers have operations on or in the vicinity of our Southern Position, including Crescent Energy, VTX Energy, APA Corporation, Permian Resources and Diamondback Energy, and we generate revenues from their use of our Southern Position acreage and its resources.

In December 2024, we closed the Wolf Bone Acquisition, pursuant to which we acquired approximately 46,000 largely contiguous surface acres in the Southern Delaware Basin known as the Wolf Bone Ranch. Located adjacent to our existing surface acreage in Reeves County, Texas, the Wolf Bone Ranch is well-positioned at a strategic intersection of oil and natural gas exploration and transportation, with access to the Waha Gas market hub. The land also supports produced water operations, with current volumes of approximately 300,000 bpd serviced by infrastructure owned and operated by VTX Energy, as well as assets owned and managed by WaterBridge.

As of December 31, 2025, WaterBridge and third party operators collectively operated approximately 783,000 bpd of existing produced water handling capacity on our Southern Position.

In addition, we continually seek to identify and pursue opportunities with a broad array of customers, including new, distinct operations on our Southern Position. For example, in September of 2025, we sold a 3,000-acre solar energy generation project in Reeves County, Texas, to a leading, publicly-traded energy infrastructure developer. In connection with the transaction, we received an up-front cash payment and the right to receive contingent future cash payments based on the achievement of certain developmental milestones. The solar project has a proposed generation capacity of 250 MW. In addition, our Southern Position is adjacent to the I-10 interstate highway corridor, the fourth longest interstate highway system in the country, as well as I-20, which, each individually and

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collectively, serve as corridors for vehicle traffic and for pipeline and electrical infrastructure, representing additional development opportunities for this surface acreage.

Our Mineral Interests

We own approximately 4,400 gross mineral acres in the Delaware Basin with a weighted average lease royalty percentage based on acreage of 23.9% and an average proved developed producing net revenue interest per well of 4.2%, as of December 31, 2025. Our mineral interests are leased to some of the top operators in the Delaware Basin, including APA Corporation, Chevron, ConocoPhillips and Occidental Petroleum. Our leases with these and other E&P companies permit the lessee to explore for and produce oil, natural gas and NGLs from our land and entitle us to receive an upfront cash payment, or lease bonus, and a percentage of the proceeds from the sales of these commodities in the form of an oil and gas royalty interest.

Unlike businesses that focus on buying oil and gas royalty interests, which are more directly exposed to commodity prices, our focus is on surface acreage ownership and the associated fee-based revenue. As a result, we expect to acquire additional mineral interests only incidentally in connection with property acquired primarily for other purposes and, consequently, oil and natural gas is expected to become a smaller percentage of our total revenues over time.

Our Business Model

We are focused on actively growing revenue from the use of our surface acreage and the sale of resources from our land, while continuing to maximize value from our current mineral interests. We believe that our largely fee-based contracts, as well as our strong base of revenues from our customers’ oil and natural gas production, help mitigate our direct exposure to commodity price fluctuations and promote cash flow stability through commodity price cycles.

Sources of Revenue

Our sources of revenue currently include:

Surface Use Royalties and Revenues

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Surface Use Royalties: Under our SURAs, including produced water handling facility leases and certain surface use agreements that contain water handling royalties, which typically provide for five- to 10-year initial terms, we receive a royalty based on a percentage of gross revenues derived from the use of our land and/or volumetric use of infrastructure installed on our land in exchange for rights of use of our land. Royalties we receive from operations under our SURAs include produced water transportation and handling operations, skim oil recovery and produced water throughput and waste reclamation, all of which are required for oil and natural gas production throughout the lifecycle of a well.
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Easements and Surface-Related Revenues: Under our SUAs, including easements and rights-of-way, which typically provide for five- to 10-year initial terms, we typically receive a fee when the contract is executed, fixed monthly or annual payments, and often additional fees at the beginning of each renewal period. Such agreements typically include pre-defined terms for fees that we will receive for our customers’ development and use of drilling sites, new and existing roads, pipeline easements and electric transmission easements. Our SUAs generally require our customers to use the resources from our land, such as brackish water and sand, for their operations on our land, for which we receive our customary fees.

Resource Sales and Royalties

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Resource Sales: Under our water supply agreements, we sell brackish water to be used primarily in well completions in exchange for a per barrel fee. These fees are negotiated and vary depending on the destination of the brackish water, with brackish water sold for use outside the Stateline AMI typically at wholesale prices, and brackish water sold for use in the Stateline AMI sold directly to producers at retail prices. Revenue from brackish water sold for use in the Stateline AMI is shared with TPL (please see “—Our Assets—Our Stateline Position” for more information related to our agreements with TPL). We and TPL have strong relationships with, and contractual commitments from, many of the E&P companies in the Stateline AMI. Additionally, the immediate proximity of our Stateline Position to the Texas-New Mexico state border provides us the ability to deliver brackish water volumes into the otherwise constrained market in New Mexico. Through our relationships, as well as the strategic location of our brackish water resources, we believe that we will benefit from strong demand going forward in both Texas and New Mexico. Similarly, our customers buy caliche from us for the construction of access roads and well pads for which we receive a fixed-fee per cubic yard of caliche extracted from our surface acreage. Businesses operating on our land are generally required to buy all caliche they use on our land from us.
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Resource Royalties: Under our sand lease agreements, we lease our surface acreage to customers to construct and operate at their expense sand mines to provide in-basin sand for use in oil and natural gas completion operations. We receive a fixed

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royalty per ton of sand extracted, as well as a fixed-fee per barrel of brackish water used to support sand mining operations. Additionally, under certain access agreements and fee arrangements, we lease our surface acreage to customers to construct and operate (at their expense) brackish water wells to extract brackish water for use in oil and natural gas operations. We receive a fixed royalty per barrel of brackish water extracted.

Oil and Gas Royalties

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Under our oil and natural gas mineral leases, we receive a lease bonus at inception and in connection with any extensions and oil and gas royalties on a per unit produced basis at a market rate, less production taxes and, in some instances, gathering, processing and transportation costs. Our leases, which typically extend for a one- to three-year primary term, permit the lessee to explore for and produce oil, natural gas and NGLs from our land and entitle us to receive a percentage of the proceeds from the sales of these commodities in the form of a royalty. If the lessee does not meet certain requirements, such as drilling and completing wells within the leased mineral acreage by a specified date, the lessee must pay to extend the lease, or the lease will terminate. If terminated, we would seek to re-lease our mineral interests to another E&P company.

We expect our fee-based revenues to grow over time relative to our revenues generated from oil and gas royalties. As shown in the chart below, for the year ended December 31, 2025, 68% of our total revenues were surface use royalties and revenues, 24% were resources sales and royalties, 6% were oil and gas royalties and 2% were considered other. For the year ended December 31, 2024, 60% of our total revenues were surface use royalties and revenues, 26% were resource sales and royalties and 14% were oil and gas royalties.

We seek to include inflation escalators in our SURAs and SUAs, which, when combined with our relatively low operating and capital expenditures, may assist in mitigating our exposure to rising costs. Given the expected long-term nature of production in the Delaware Basin, we expect these contracts to be renewed over an extended period of time. While we expect these revenue streams to be recurring over the long-term, our contracts with our significant customers, which represent a large portion of our revenues, generally do not contain minimum commitment provisions for land use or brackish water volumes to be purchased. As a result, our revenues are dependent on ongoing demand from these customers, which may decrease due to factors beyond our control despite our current expectations regarding long-term activity by our customers on our land. Among other risks to which we are exposed, we are subject to the risk of geographic concentration in the Permian Basin where we compete with other landowners to provide an attractive development site for the limited number of potential customers that seek to develop and/or construct infrastructure or procure resources necessary for their projects and operations.

Financial Performance

Key to our business model is entering into agreements under which our customers bear substantially all of the operating and capital expenditures related to their operations, while requiring only modest capital investment by us. As a result, we are able to grow our revenues, net income and Adjusted EBITDA while maintaining relatively high Free Cash Flow.

Our success in signing new commercial agreements through the active management of our land combined with the strength of our existing contracts and our proactive land acquisition strategy has resulted in significant growth in our business.

Although we believe that we have been successful in growing our business, the 1918 Ranch Acquisition required significant capital expenditure and, as of December 31, 2025, we had $570.7 million of total debt outstanding, with working capital, defined as current

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assets less current liabilities, of $47.5 million, and cash and cash equivalents of $30.7 million. For more information, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources.”

Our Relationship with WaterBridge

We share a management team and financial sponsor with WaterBridge. WaterBridge owns and operates one of the largest integrated water midstream systems in the United States, providing water sourcing and produced water handling in key oil and natural gas producing basins in Texas, New Mexico and Oklahoma. WaterBridge’s key customers include Devon Energy, Permian Resources, BPX Energy, Chevron, EOG Resources, APA Corporation, Vital Energy, ConocoPhillips, San Mateo Midstream and Mewbourne Oil Company. As of December 31, 2025, WaterBridge handled approximately 2.5 million bpd of aggregate produced water and had approximately 4.8 million bpd of aggregate handling capacity, in each case across its aggregate areas of operation. WaterBridge has the right to construct produced water infrastructure on our Stateline and Northern Positions and is one of our largest customers, representing 25% of our revenue during the year ended December 31, 2025. These revenues consist of produced water handling fees, skim oil royalties, solid waste disposal and reclamation facility royalties and fees associated with rights of way for pipelines, equipment and roads and related surface use permits.

During the year ended December 31, 2025, we generated $50.5 million of revenues from WaterBridge. For every 100,000 bpd of incremental produced water that WaterBridge brings onto our surface, we expect to generate royalty fees of $4.0 million to $6.0 million per year, including skim oil royalties. The shared management team between LandBridge and WaterBridge facilitates our common goal of capitalizing on energy production in the Permian Basin through a mutually beneficial relationship. Additionally, our shared management team’s visibility into oil and natural gas production and long-term trends in the Permian Basin as a result of WaterBridge’s platform allows us to facilitate development of infrastructure in certain premier locations, thus capturing additional revenue streams.

In the Permian Basin, WaterBridge is primarily focused on building and operating integrated water networks to provide operational continuity for its upstream customers. WaterBridge’s integrated systems provide continuous handling capacity for water produced in connection with production operations. WaterBridge’s network provides operational redundancy, customer flow assurance and recycling and redelivery across its entire Permian Basin footprint. Within the Delaware Basin, WaterBridge has approximately 2,500 miles of pipeline with 4.2 million bpd of water handling capacity, as of December 31, 2025. In particular, as of December 31, 2025, WaterBridge operates an integrated water network on our land with approximately 1.5 million bpd of existing water handling capacity, primarily on our Stateline Position, and has approximately 3.2 million bpd of additional permitted capacity available for future development on our land. Additionally, WaterBridge operates two waste management facilities on our land for the reclamation and disposal of non-hazardous oilfield waste. We receive a percentage of gross revenue from solid waste disposal and reclamation operations, as well as revenue from providing brackish water for landfill operations.

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In addition, the Stateline AMI provides WaterBridge the certainty necessary to develop large-scale water infrastructure assets on our land, which we believe provides WaterBridge with greater water sourcing and handling opportunities and will generate additional royalty revenue for us. A map of WaterBridge’s assets in the Delaware Basin, as of December 31, 2025 is shown in the graphic below.

Our Relationship with Five Point

Five Point is a private equity and infrastructure investor focused on investments within the North American water management, surface management, powered land and sustainable infrastructure sectors. Five Point acquires and develops in-basin assets, provides growth capital and builds industry-leading companies with experienced management teams and large E&P partners. Five Point indirectly owns a majority of our common shares, a majority of WaterBridge’s common shares and 50% of Powered Land Partners, LLC (“PowLan”), a joint venture between a third-party developer and funds affiliated with Five Point for the development of a data center on our land. Please see “—Material Contracts and Marketing” below for more information on our relationship with PowLan.

Customers; Material Contracts and Marketing

Customers

We have a diverse customer base consisting primarily of businesses that develop and produce oil and natural gas or provide services in support of oil and natural gas production. Our customers are generally large, well-capitalized businesses that have strong credit ratings. For the year ended December 31, 2025:

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our five largest customers, which consisted of WaterBridge, VTX Energy, ConocoPhillips, EOG Resources and Occidental Petroleum comprised 59% of total revenue; and
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36% of total revenue was from customers with an investment grade credit rating.

Our revenue-generating agreements with WaterBridge include water facilities agreements and related SUAs, including easements and rights-of-way, pursuant to which WaterBridge has constructed and operates produced water handling facilities and fresh water facilities on our land. See “—Material Contracts and Marketing” for further information on our agreements with WaterBridge. The majority of our revenues from WaterBridge during the year ended December 31, 2025, were generated by produced water handling royalties, brackish water sales and surface use payments for infrastructure constructed on our lands, with less significant revenues generated by its other land uses. Our agreements with WaterBridge do not contain minimum volume commitments, and our revenues

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from WaterBridge can fluctuate based on the nature, timing and scope of WaterBridge’s activities on our land. Pricing for our agreements with WaterBridge is consistent with the pricing described under “Management’s Discussion and Analysis of Financial Condition and Results of Operation — How we Generate Revenue.”

Our revenue-generating agreements with VTX Energy include SUAs with VTX Energy and its water midstream affiliate, Supply Water Systems LLC (“SWS”), each with an initial term of 10 years and a perpetual term thereafter, so long as such applicable party conducts operations on Wolf Bone Ranch without cessation of use for a period of twelve consecutive months or more. Pursuant to such SUAs, VTX Energy conducts oil and natural gas development and production activities on Wolf Bone Ranch and SWS conducts produced water handling, recycling and treatment activities on Wolf Bone Ranch, as applicable, from which we receive customary royalties and fees. We also entered into a letter agreement pursuant to which VTX Energy provided a minimum annual revenue commitment of $25.0 million for each of five years beginning December 19, 2024, inclusive of revenues under the VTX Energy and SWS SUAs. The terms and conditions of, and pricing for, our agreements with VTX Energy and its affiliates are consistent with descriptions of such agreements set forth in “Management’s Discussion and Analysis of Financial Condition and Results of Operations—How We Generate Revenue.” The majority of our revenues from VTX Energy during the year ended December 31, 2025, were generated by surface use royalties, brackish water sales and the minimum annual revenue payment under the letter agreement. Our agreements with VTX Energy can fluctuate based on the nature, timing and scope of VTX Energy’s activities on our land.

Our revenue-generating agreements with ConocoPhillips include (i) a water purchase and access agreement with an initial term of 10 years and a perpetual term thereafter, subject to termination for non-use for more than six months, pursuant to which ConocoPhillips operates brackish water wells on our lands and we receive customary royalties for each barrel of brackish water produced from such wells, (ii) brackish water supply agreements, typically on a short-term basis, pursuant to which we sell brackish water to ConocoPhillips to be used primarily in well completions, (iii) SUAs with perpetual terms so long as ConocoPhillips conducts operations thereunder, subject to termination for non-use for more than six months, pursuant to which ConocoPhillips operates produced water recycling and treatment facilities on our land and from which we receive customary royalties and fees, (iv) customary term easements, typically for five- to 10-year terms, subject to early termination for non-use over a specified period of time and (v) customary oil and natural gas mineral leases with perpetual terms so long as ConocoPhillips conducts operations thereunder. The terms and conditions of, and pricing for, our agreements with ConocoPhillips are consistent with the descriptions of such agreements set forth in “Management’s Discussion and Analysis of Financial Condition and Results of Operations—How We Generate Revenue.” The majority of our revenues from ConocoPhillips during the year ended December 31, 2025, were generated by brackish water sales, produced water handling royalties and oil and gas royalties, with less significant revenues generated by its other land uses. Our agreements with ConocoPhillips do not contain minimum volume commitments, and our revenues from ConocoPhillips can fluctuate based on the nature, timing and scope of ConocoPhillips’ activities on our land.

Our revenue-generating agreements with EOG Resources include (i) a sand mine lease with an initial term of three years and a perpetual term thereafter so long as EOG Resources conducts operations thereunder, subject to early termination rights for non-use over six months, pursuant to which EOG Resources constructed and operates a sand mine on our land and from which we receive a per ton royalty for sand extracted and fees for water used in its mining operations, and (ii) an SUA with an initial term of 10 years and an option for EOG Resources to extend for two additional 10-year terms, pursuant to which we receive customary fees for EOG Resources’ development and use of drilling sites, new and existing roads, pipeline easements and surface and subsurface easements. The terms and conditions of, and pricing for, our agreements with EOG Resources are consistent with the descriptions of such agreements set forth in “Management’s Discussion and Analysis of Financial Condition and Results of Operations—How We Generate Revenue.” The majority of our revenues from EOG Resources during the year ended December 31, 2025, were generated by resource royalties and brackish water sales, with resource royalties generated during the year ended December 31, 2025, reflecting EOG Resources’ sand mining operation on our surface acreage. We generated less significant revenues from EOG Resources’ other land uses during the year ended December 31, 2025. Our agreements with EOG Resources do not contain minimum volume commitments, although our sand mine lease with EOG Resources contains a nominal minimum yearly royalty payment. Our revenues from EOG Resources can fluctuate based on the nature, timing and scope of EOG Resources’ activities on our land.

Our revenue-generating agreements with Occidental Petroleum include (i) brackish water supply agreements, typically on a short-term basis, pursuant to which we sell brackish water to Occidental Petroleum to be used primarily in well completions, (ii) SUAs with perpetual terms so long as Occidental Petroleum conducts operations thereunder, subject to termination for non-use for more than six months, pursuant to which Occidental Petroleum conducts oil and natural gas exploration, development and production activities, including produced water recycling and treatment, on our land and from which we receive customary royalties and fees, (iii) customary term easements, typically for five- to 10-year terms, subject to early termination for non-use over a specified period of time and (iv) customary oil and natural gas mineral leases with perpetual terms so long as Occidental Petroleum conducts operations thereunder. The terms and conditions of, and pricing for, our agreements with Occidental Petroleum are consistent with the descriptions of such agreements set forth in “Management’s Discussion and Analysis of Financial Condition and Results of Operations—How We Generate Revenue.” The majority of our revenues from Occidental Petroleum during the year ended December 31, 2025, were generated by damage payments under SUAs and easements, brackish water sales, produced water handling royalties and oil and gas royalties, with less significant revenues generated by its other land uses. Our agreements with Occidental

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Petroleum do not contain minimum volume commitments, and our revenues from Occidental Petroleum can fluctuate based on the nature, timing and scope of Occidental Petroleum’s activities on our land.

Please see “Management’s Discussion and Analysis of Financial Condition and Results of Operations—How We Generate Revenue” for further information regarding the ranges of our customary royalties and fees, inclusive of our royalties and fees with WaterBridge, VTX Energy, ConocoPhillips, EOG Resources and Occidental Petroleum.

While we would expect to be able to replace these customers, it is possible that the loss of any one of these customers could adversely affect our total revenues and have a material adverse effect on our results of operations, cash flows and financial position, whether in the short or long term. Furthermore, the determination by a customer to initiate or maintain activities on or around our land largely depends on the location of our surface acreage relative to the nature and locations of such customer’s operations and such customer’s need for the use of our land and resources. Our customers generally consist of a limited number of entities operating on and around our acreage in the Delaware Basin.

Material Contracts and Marketing

We enter into various agreements with our customers in the ordinary course relating to the use of our land and resources and the fees, royalty rates, payment structure and other related terms in our contracts are negotiated on a case-by-case basis, taking into account the surface use of our land, the type of resources extracted, and the amount of use expected to be made of our land and the amount of resources to be produced and/or extracted, among other things. For a discussion regarding general market rates for similar uses of land and resources in our industry and geographic area, please see “Management’s Discussion and Analysis of Financial Condition and Results of Operations—How We Generate Revenue.”

Although our agreements generally do not contain minimum commitment provisions for activities on or around our land, such as brackish water volumes to be purchased, we may include such provisions on an individual basis based on a potential customer’s proposed use of our land and resources. Under our contracts, our customers generally bear liability for environmental, health and safety risks, through indemnification of the Company, mandated insurance coverage and covenants and representations regarding environmental, health and safety compliance for all such risks, in each case, related to their operations on our land. Further, our contracts include inspection rights such that we may enter and oversee certain activities on our properties to monitor our customers’ compliance with environmental, health and safety requirements, and, following completion of the term of our agreements, our customers typically must remediate our land as close as is reasonably practicable to its state prior to such customers’ activities on the land.

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For a description of our SURAs, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Sources of Revenue—Surface Use Royalties and Revenues—Surface Use Royalties.”
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For a description of our SUAs, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Sources of Revenue—Surface Use Royalties and Revenues—Easements and Surface-Related Revenues.”
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For a description of our water supply agreements, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Sources of Revenue—Surface Use Royalties and Revenues—Resource Sales.”
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For a description of our sand lease agreements, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Sources of Revenue—Surface Use Royalties and Revenues—Resource Sales.”

In addition, we are a party to various agreements with affiliates relating to the use of our land and its resources, including:

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a produced water facilities agreement granting WaterBridge the exclusive right to construct, own and operate new produced water handling infrastructure on the western portion of our Stateline Position, with an initial term of approximately five years and automatic one-year renewals unless terminated by a party prior to renewal. We are paid a royalty for each barrel of produced water transported across our lands subject to the agreement, surface use payments in respect of its infrastructure constructed and operated on our surface acreage subject to the agreement and a percentage of the net proceeds received by WaterBridge for the sale of skim oil recovered on our land subject to the agreement. Surface use payments are based on market rates and subject to annual redetermination by us in our reasonable discretion, taking into account market rates for similar payments in the immediate vicinity of our land. The agreement provides for automatic annual increases in royalties after a specified period of time that are tied to the lesser of the CPI and a fixed percentage, and mutual termination rights in the event of a counterparty default and contains standard confidentiality, indemnification, insurance and change of control provisions;
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a produced water facilities agreement granting WaterBridge the right to construct, own and operate produced water handling infrastructure on the East Stateline Ranch, the Lea County Ranches, the Speed Ranch and all future land acquired by us in our

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Stateline and Northern Positions, with (i) a perpetual term on the East Stateline Ranch for so long as WaterBridge conducts operations thereon and (ii) an initial term of approximately ten years and automatic one-year renewals unless terminated by a party prior to renewal for all other lands. Under the agreement, WaterBridge has the exclusive right to construct and operate up to 30 produced water handling facilities at specified locations. WaterBridge also has the exclusive right to handle produced water volumes generated from oil and gas development and production on the East Stateline Ranch, subject to customary exclusions and pre-existing third-party rights. WaterBridge has the non-exclusive right to operate produced water infrastructure on all other lands subject to the agreement. We are paid a royalty for each barrel of produced water transported by WaterBridge across our land subject to the agreement, a royalty for each barrel of produced water treated and sold by WaterBridge from a recycling facility on our land subject to the agreement, surface use payments in respect of WaterBridge’s infrastructure constructed and operated on our surface acreage subject to the agreement and a percentage of the net proceeds received by WaterBridge for the sale of skim oil recovered on our land subject to the agreement. Surface use payments are based on market rates and subject to annual redetermination by us in our reasonable discretion, taking into account market rates for similar payments in the immediate vicinity of our land. The agreement provides for automatic annual increases in royalties after a specified period of time that are tied to the lesser of CPI and a fixed percentage, and mutual termination rights in the event of a counterparty default and contains standard confidentiality, indemnification, insurance and change of control provisions;
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a fresh water facilities agreement granting WaterBridge the right to construct, own and operate brackish water infrastructure on the East Stateline Ranch, the Lea County Ranches, the Speed Ranch and all future land acquired by us in our Stateline and Northern Positions, with (i) a perpetual term on the East Stateline Ranch for so long as WaterBridge conducts operations thereon and (ii) an initial term of approximately ten years and automatic one-year renewals unless terminated by a party prior to renewal for all other lands. WaterBridge has the exclusive right to market and sell brackish water produced from the East Stateline Ranch to third parties for use in oil and natural gas operations, subject to customary exclusions and pre-existing third-party rights. WaterBridge has the non-exclusive right to operate brackish water infrastructure on all other lands subject to the agreement for use in oil and natural gas operations. We may grant third parties the right to transport brackish water across the lands subject to the agreement, including the East Stateline Ranch. We are paid a royalty for each barrel of brackish water produced by WaterBridge from, or transported by WaterBridge across, our land subject to the agreement, a percentage of the net proceeds for each barrel of brackish water produced by WaterBridge from our land subject to the agreement and sold for use off of our land and surface use payments in respect of WaterBridge’s infrastructure constructed and operated on our land subject to the agreement. Surface use payments are based on market rates and subject to annual redetermination by us in our reasonable discretion, taking into account market rates for similar payments in the immediate vicinity of our land. The agreement provides for automatic annual increases in royalties after a specified period of time that are tied to the lesser of CPI and a fixed percentage, and mutual termination rights in the event of a counterparty default and contains standard confidentiality, indemnification, insurance and change of control provisions;
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a surface lease and use agreement granting WaterBridge the non-exclusive right to construct, own and operate produced water handling infrastructure on the Wolf Bone Ranch, with an initial term of 10 years and the option for WaterBridge to renew for additional 10-year terms in return for one-time renewal payments. We are paid a royalty for each barrel of produced water handled on our lands subject to the agreement and surface use payments in respect of produced water handling infrastructure constructed and operated on our surface acreage subject to the agreement. Surface use payments are based on market rates and subject to redetermination by us from time-to-time in our commercially reasonable discretion, taking into account market rates for similar payments in the immediate vicinity of our land. The agreement provides for mutual termination rights in the event of a counterparty default and contains standard confidentiality, indemnification, insurance and change of control provisions;
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a lease development agreement for the development of a data center and related facilities on approximately 2,000 acres of our land in Reeves County, Texas with PowLan. PowLan is obligated to meet certain timing milestones to maintain its lease, including the commencement of site development within a two-year period and the construction of the data center within a subsequent four-year period. To the extent PowLan does not commence site development within two years of entry into the lease development agreement or commence construction of the data center within a subsequent four-year period, the agreement will automatically terminate. The lease development agreement includes, among other things, a non-refundable deposit and a two-year site selection and pre-development period; and
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surface use agreements with WaterBridge, each with an initial term of 10 years and automatic one-year renewals unless terminated by either party prior to renewal, pursuant to which we have granted certain exclusive rights to construct, operate and maintain non-hazardous waste management facilities on our land and we receive a percentage of gross revenue from solid waste disposal and reclamation, as well as additional revenue from providing water for landfill operations and fees for surface damages, which surface damage payments are based on market rates and subject to annual redetermination by us in our reasonable discretion, taking into account market rates for similar payments in the immediate vicinity of our land. Each party is required to purchase all dirt, gravel and similar materials utilized in connection with such facilities on our land, as well as for all brackish water, from us. These agreements contain standard confidentiality, indemnification, insurance and change of control provisions.

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We are also party to lease arrangements with respect to a portion of our oil and natural gas mineral interests. See “—Our Assets—Mineral Interests” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Oil and Gas Royalties.”

In addition to continuing to capitalize on existing agreements and relationships, we intend to pursue and acquire new commercial arrangements in an effort to develop and diversify our revenue streams. As such, we are currently pursuing arrangements, or have agreed to certain arrangements, relating to solar power generation, power storage, microgrids, cryptocurrency mining and data centers, non-hazardous oilfield reclamation and solid waste facilities and commercial fueling stations, among other revenue streams. Similar to the other operations conducted on our land, we expect to enter into surface use or similar agreements with the owners of these projects from which we expect to receive surface use fees and other payments in connection with the utilization of our land, but we would not own or operate such projects or expect to incur significant capital expenditures in connection therewith.

Infrastructure

In order to use our surface acreage to, among other things, support all stages of energy development and production to supply growing global demand, we have entered into various SUAs through which our customers have built and own or are developing infrastructure on our land, including oil, natural gas and produced water gathering pipelines, recycled water pipelines, produced water handling facilities, water recycling ponds, sand mines, non-hazardous oilfield reclamation and solid waste facilities, a data center and a cryptocurrency facility, as of December 31, 2025. We also own brackish water wells and ponds on our land.

In addition to the above infrastructure, improvements with respect to permanent electrical infrastructure, including telecommunication lines, drilling pad sites, roads and landfills, among other things, have been made on our land that improve reliability and lower operating costs for our customers. Although infrastructure with the ability to increase revenue-generating activities is already present on our surface acreage, we believe that our land presents a multitude of additional opportunities for further commercialization and optimization, including coordinating with potential customers to construct infrastructure relating to power storage, water treatment facilities, hydrogen production and carbon capture and sequestration.

Cyclical Nature of Oil and Natural Gas Industry

The oil and natural gas industry is a highly cyclical industry. Demand for the use of our land and its resources depends substantially on activity levels by producers on and around our land. Prevailing commodity prices and future demand for, and price of, oil and natural gas and volatility in oil or natural gas prices (or the perception that oil or natural gas prices will decrease) affects such producers’ capital expenditures and willingness to pursue development activities. As such, the willingness of our producers to engage in drilling activities on and around our land is substantially influenced by the market prices of oil and natural gas. Producers tend to increase capital expenditures in response to increases in oil and natural gas prices, which would generally be expected to result in greater revenues for us. Increased capital expenditures can also lead to greater production, which historically has resulted in increased supplies of oil and natural gas that can, in turn, reduce prices thereby leading to a reduction in activity levels. For these reasons, the results of our operations may be cyclical and may fluctuate from quarter to quarter and from year to year, and these fluctuations may distort comparisons of results across periods.

Seasonality

While our business is not necessarily seasonal in nature, revenue from the use of our land and its resources may fluctuate over certain reporting periods due to fluctuations in the prices of oil and natural gas. Generally, but not always, the demand for natural gas, as well as associated production, decreases during the summer months and increases during the winter months, thereby affecting the amount we receive in association with natural gas production and related activities on our land.

Seasonal anomalies, such as mild winters or hotter than normal summers, may lessen this fluctuation. Demand for oil has generally not been seasonal. Our other revenue streams, including sales of brackish water, payments from SUAs and other surface related revenue and sales of resources, may also vary from period to period due to seasonal changes in supply and demand, and a variety of additional seasonal factors that are beyond our control and the control of producers on or around our land.

Our results and business are significantly dependent on our customers and their activities on our land, which are beyond our control. Weather conditions in the Permian Basin generally result in higher drilling activity in the spring, summer and fall months, although summer and fall drilling activity can be restricted due to severe weather conditions. In the fourth quarter, due to inclement weather and the exhaustion of annual drilling and completion capital expenditure budgets, drilling activity typically declines in the Permian Basin. As a result, our results of operations, cash flows and financial position may vary year over year, with particular periods of results not necessarily indicative of our future results.

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Human Capital Resources

We manage our operations through a shared services agreement (the “Shared Services Agreement”) with certain affiliates of WaterBridge (the “Manager”). Pursuant to the Shared Services Agreement, the Manager provides us with the services of our senior executive management team and certain management services, as well as general, administrative, overhead and operating services to support our business and development activities, including by making available five full-time personnel exclusively providing field services on our surface acreage and five full-time corporate services personnel exclusively providing corporate services to us.

Pursuant to the Shared Services Agreement, the Manager also provides operational and maintenance services, such as project and construction management, and provides operating materials and equipment. Because our customers construct and operate almost all of the infrastructure installed on our acreage, we expect to maintain a minimal number of dedicated personnel. As of December 31, 2025, we did not directly employ any employees.

Due to our Shared Services Agreement, our business and the success thereof is dependent, in part, on the Manager’s ability to attract and retain qualified personnel. As part of the Manager’s efforts to hire and retain highly qualified employees, the Manager has structured competitive compensation and benefits programs that reward outstanding performance. In addition to the incentive programs in place for our named executive officers, the Manager has structured an incentive bonus program for employees that is dependent on an employee’s individual performance.

Certain employees of the Manager who make material contributions to our success may also receive restricted share units and/or other equity-based incentive awards to encourage retention and align compensation with our performance. The Manager provides a comprehensive benefits package, including 401(k) contributions, medical insurance options and programs to encourage and support employee development. We are not a party to any collective bargaining agreements and have not experienced any strikes or work stoppages. In general, we believe that our personnel relations are positive.

Personnel Health and Safety

Safety is important to us and begins with the protection and safety of the personnel who provide services with respect to our business and the communities in which we operate. We value people above all else and remain committed to making safety and health a top priority. We strive to comply with all applicable health and safety laws and regulations and continually seek to maintain and deepen our safety culture by providing a safe working environment that encourages active personnel engagement, including implementing safety programs and continuing education policies to achieve improvements in our safety culture. We intend to continue to develop and administer policies to promote our organizational goals and improve and maintain the safety of our workspace.

Competition

The market in which we operate is competitive due to the location of our land in the Permian Basin in Texas and New Mexico and to the services in which we offer our customers. Given our geographic concentration in the Permian Basin, we compete with existing landowners in the area to provide an attractive development site for the limited number of potential customers that seek to develop and/or construct infrastructure in Texas and New Mexico to support their various business activities. We also compete with such landowners over the limited supply of, and demand for, resources, including brackish water, in the area. Furthermore, to the extent any new property owner purchases land located in areas comparable to our surface acreage, such property owner could be a potential competitor. As we continue to grow our business and enter into new business lines, including with respect to renewable energy, non-hazardous oilfield reclamation and solid waste facilities and other revenue streams, we will experience increasing levels of competition. Competition in our current market is based primarily on the geographic location of land, business reputation, pricing arrangements for the use of the land and its resources and legal and regulatory restrictions, among other factors. Although some of our competitors may have a broader geographic scope, longer operating history and greater financial and other resources than we have, we believe that we are competitively well-positioned due to the premier location of our land, which also provides a multitude of resources and uses, the reliability of our assets and our customer relationships, such as our symbiotic relationship with WaterBridge.

Insurance

We maintain insurance coverage at levels that we believe are reasonable and prudent; however, as is customary in our industry, we do not insure fully against all risks associated with our business, either because such insurance is not available or because premium costs are considered prohibitive. We may not be able to maintain adequate insurance in the future at rates or on other terms we consider commercially reasonable and our actual coverage may not insure against many types of interruptions or events that might occur. In addition, the proceeds of any such insurance may not be paid in a timely manner and may be insufficient if a loss event were to occur. The occurrence of such an event, the consequences of which are either not covered by insurance or not fully insured, or a significant delay in, or denial of, the payment of a major insurance claim, could have a materially and adverse effect on our results of operations, cash flows and financial position. Our arrangements with our customers operating on our land require the maintenance of certain levels of insurance and such customers’ indemnification of us to protect for such events occurring with respect to their operations.

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Regulation of Environmental and Occupational Safety and Health Matters

Our customers’ business operations are subject to numerous environmental and occupational health and safety laws and regulations that may be imposed at the federal, regional, state and local levels. The activities that our customers conduct in the course of oil and natural gas exploration and production, produced water handling, sand mining, and other activities are subject to or may become subject to stringent environmental regulation. Our customers are responsible for compliance with various environmental laws and regulations in the course of their operations. Although we generally have the right to inspect our properties and the activities thereon, we typically do not have any control with respect to such activities. For properties in which we hold mineral or royalty interests, we generally are not subject to direct environmental liability because we do not own, operate, or otherwise have control over any of the equipment, facilities, or operations occurring on such properties. However, with respect to land owned by us and leased to a customer, we may be subject to strict, joint and several liability for any spills or contamination on those properties, even though we generally have no control over operations on properties. For further information, see “Risk Factors—Risks Related to Environmental and Other Regulations—Our customers” operations on our land may be exposed to significant delays, costs and liabilities as a result of environmental, health and safety requirements, and we may be subject to strict, as well as joint and several liability, for contamination resulting from such operations pursuant to such requirements, even if we do not have control over such operations. The occurrence of any such delays, costs and liabilities may materially and adversely affect our customers’ business, operations or financial condition, which could reduce the demand for the use of our land and its resources, as well as the royalties and other payments we receive therefrom, and thereby materially affect our results of operations, cash flows and financial position. To mitigate the risk of potential environmental liabilities that may arise in the course of operations on our properties that we do not control, we generally seek to partner with reputable customers and seek indemnification from our customers for liabilities arising from their operations on our land, and we maintain what we believe is customary and reasonable insurance to protect our business against these potential losses. We also typically include covenants relating to compliance with environmental, health and safety regulations and remediation provisions in our contracts. Additionally, we may be able to rely on state funded programs (such as the Texas Railroad Commission’s (“TRRC”) Orphan Well Program) for coverage of certain plugging and abandonment liabilities upon declaration of bankruptcy by any of our customers. However, such actions may not be adequate to cover our liabilities, and we are not fully protected or insured against all risks. We do not expect environmental compliance costs to have a material adverse effect on our results of operations, cash flows and financial position; however, there can be no assurance that such costs will not be material in the future or that such future compliance will not have a material adverse effect on our results of operations, cash flows and financial position, or on those of our customers.

The more significant of these existing environmental and occupational health and safety laws and regulations include the following U.S. legal standards, as amended from time to time:

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the Clean Air Act (“CAA”), which restricts the emission of air pollutants from many sources and imposes various pre-construction, operational, monitoring and reporting requirements, and which the U.S. Environmental Protection Agency (“EPA”) has historically relied upon as authority for adopting climate change regulatory initiatives relating to GHG emissions;
•
the Federal Water Pollution Control Act, also known as the Clean Water Act (“CWA”), which regulates discharges of pollutants into state and federal waters and establishes the extent to which waterways are subject to federal jurisdiction and rulemaking as protected waters of the United States;
•
the Comprehensive Environmental Response, Compensation and Liability Act of 1980 (“CERCLA”), which imposes liability on generators, transporters, and arrangers of hazardous substances at sites where hazardous substance releases have occurred or are threatening to occur;
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the Resource Conservation and Recovery Act (“RCRA”), which governs the generation, treatment, storage, transport, and disposal of solid wastes, including hazardous wastes;
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the Oil Pollution Act of 1990, which subjects owners and operators of onshore facilities, pipelines and other facilities, as well as lessees or permittees of areas in which offshore facilities are located, that are the site of an oil spill in waters of the United States, to liability for removal costs and damages;
•
the Safe Drinking Water Act (the “SDWA”), which ensures the quality of the United States’ public drinking water through the adoption of drinking water standards and control of the injection of waste fluids into below-ground formations that may adversely affect drinking water sources;
•
the Endangered Species Act (the “ESA”), which restricts activities that may affect federally identified endangered and threatened species or their habitats through the implementation of operating restrictions or a temporary, seasonal, or permanent ban in affected areas;

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•
the National Environmental Policy Act, which requires federal agencies to evaluate major agency actions having the potential to impact the environment and that may require the preparation of environmental assessments and more detailed environmental impact statements that may be made available for public review and comment; and
•
the Occupational Safety and Health Act (“OSHA”), which establishes workplace standards for the protection of the health and safety of employees, including the implementation of hazard communications programs designed to inform employees about hazardous substances in the workplace, potential harmful effects of these substances, and appropriate control measures.

Texas and New Mexico have similar laws and regulations in many respects. These environmental and occupational health and safety laws and regulations generally restrict the level of substances generated as a result of operations that may be emitted to ambient air, discharged to surface water, and disposed or released to surface and below-ground soils and ground water. Additionally, there exist state and local jurisdictions in the United States where we operate that also have, or are developing or considering developing, similar environmental and occupational health and safety laws and regulations governing many of these same types of activities. Any failure by us, or our customers, to comply with these laws and regulations may result in the assessment of sanctions, including administrative, civil, and criminal fines or penalties; the imposition of investigatory, remedial, and corrective action obligations or the incurrence of capital expenditures; the occurrence of restrictions, delays or cancellations in the permitting, development or expansion of projects; and the issuance of injunctions restricting or prohibiting some or all activities in a particular area. Certain environmental laws also provide for citizen suits, which allow environmental organizations to act in place of the government and sue those subject to the laws, in many cases, our customers, for alleged violations of environmental law. The ultimate financial impact arising from environmental laws and regulations is neither clearly known nor determinable as existing standards are subject to change and new standards continue to evolve.

Some of our land has been or is now operated by third parties or by previous owners or operators whose treatment and disposal of hazardous substances, wastes, or petroleum hydrocarbons is not under our control. Under environmental laws such as CERCLA and RCRA, we could incur strict, joint and several liability for remediating hydrocarbons, hazardous substances or wastes disposed of or released by us or prior owners or operators. We also could incur costs related to the clean-up of third-party sites to which we sent regulated substances for disposal or to which we sent equipment for cleaning, and for damages to natural resources or other claims related to releases of regulated substances at or from such third-party sites.

Waste Disposal. RCRA and comparable state statutes regulate the generation, transportation, treatment, storage, disposal and cleanup of hazardous and nonhazardous wastes. Pursuant to rules issued by the EPA, the individual states administer some or all of the provisions of RCRA, sometimes in conjunction with their own, more stringent requirements. Drilling fluids, produced water, and most of the other wastes associated with the exploration, development, and production of oil or gas, if properly handled, are currently exempt from regulation as hazardous waste under RCRA, and instead are regulated under RCRA’s less stringent nonhazardous waste provisions, state laws or other federal laws. However, it is possible that certain oil and natural gas drilling and production wastes now classified as nonhazardous could be classified as hazardous wastes in the future. Any loss of the RCRA exclusion for drilling fluids, produced water and related wastes could result in an increase in our and our oil and natural gas producing operators’ costs to manage and dispose of generated wastes, which could have a material adverse effect on our and our customers’ results of operations, cash flows and financial position. Texas and New Mexico have received authority from the EPA to administer the RCRA program in their respective jurisdictions, in addition to their own state regulations.

Wastes containing naturally occurring radioactive materials (“NORM”) may also be generated in connection with our customers’ operations. Certain processes used to produce oil and natural gas may enhance the radioactivity of NORM, which may be present in oilfield wastes. NORM is subject primarily to individual state radiation control regulations. For example, the TRRC and New Mexico Oil Conservation Division (“NMOCD”) generally regulate the management and disposal of NORM from oil and natural gas operations in their own respective jurisdictions. In addition, NORM handling and management activities are governed by regulations promulgated by OSHA. These state and OSHA regulations impose certain requirements concerning worker protection, the treatment, storage and disposal of NORM waste and the management of waste piles, containers and tanks containing NORM, as well as restrictions on the uses of land with NORM contamination.

The CWA and analogous state laws impose restrictions and strict controls with respect to the discharge of pollutants, including spills and leaks of oil and hazardous substances, into state waters and waters of the U.S. The discharge of pollutants into regulated waters is prohibited, except in accordance with the terms of a permit issued by the EPA or an analogous state agency. The CWA and analogous state laws also require individual permits or coverage under general permits for discharges of stormwater runoff from certain types of facilities.

Water Regulation. The CWA also prohibits the discharge of dredge and fill material in regulated waters, including wetlands, unless authorized by permit. There continues to be uncertainty regarding the federal government’s applicable jurisdictional reach under the CWA over waters of the U.S., including wetlands, as the EPA and the U.S. Army Corps of Engineers (“Corps”) have pursued multiple rulemakings since 2015 in an attempt to determine the scope of such reach. In January 2023, the EPA and the Corps issued a final rule

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founded upon the pre-2015 regulations and incorporated updates based on existing Supreme Court decisions, including considerations based on regional and geographic differences. Additionally, in May 2023, the Supreme Court decided Sackett v. EPA, a case relating to the legal tests used to determine whether wetlands should be considered waters of the United States. A revised waters of the United States rule was issued in September 2023, to amend the January 2023 rule based on the Sackett decision, but it is currently being challenged in multiple courts. Due to the rule’s injunction in certain states, the implementation of the September 2023 final rule varies by state and the operative definition is different in the two states in which we currently operate. However, in November 2025, the EPA and the Corps proposed a rule to further update and narrow the September 2023 definition. To the extent any judicial ruling or administrative rulemaking or other action changes the scope of the CWA’s jurisdiction, we, WaterBridge and our producers and other customers could face increased costs and delays with respect to obtaining permits for dredge and fill activities in wetland areas. These laws and any implementing regulations provide for administrative, civil and criminal penalties for any unauthorized discharges of crude oil and other substances in reportable quantities and may impose substantial potential liability for the costs of removal, remediation and damages. To the extent that any new final rule or rules issued by the EPA and Corps expands the scope of the CWA’s jurisdiction in areas where we or our customers conduct operations, such developments could increase compliance expenditures or mitigation costs, contribute to delays, restrictions, or cessation of the development of projects, and also reduce the rate of production of oil and natural gas from producers with whom we have a business relationship and, in turn, have a material adverse effect on our results of operations, cash flows and financial position. Federal and state regulatory agencies can impose administrative, civil and criminal penalties for noncompliance with discharge permits or other requirements of the CWA and analogous state laws and regulations.

Air Emissions. The CAA and comparable state laws restrict the emission of air pollutants from many sources through air emissions standards, construction and operating permit programs and the imposition of other compliance standards. These laws and regulations may require us, or our customers, to obtain preapproval for the construction or modification of certain projects or facilities expected to produce or significantly increase air emissions, obtain and strictly comply with stringent air permit requirements or utilize specific equipment or technologies to control emissions of certain pollutants. The need to obtain permits has the potential to delay our projects as well as our customers’ development of various types of projects. Over the next several years, our customers may incur certain capital expenditures for air pollution control equipment or other air emissions related issues, which could lead to an increase in our customers’ operating costs or a decrease in our or our customers’ revenues and limit future development activity by our customers, including WaterBridge, thereby reducing their demand for the use of our land and resources. For example, in 2015, the EPA issued a final rule under the CAA, making the National Ambient Air Quality Standard (“NAAQS”) for ground level ozone more stringent. In December 2020, the EPA under the Trump Administration published a final action that elected to retain the 2015 ozone NAAQS without revision on a going-forward basis. However, several groups filed litigation over the December 2020 decision, and the Biden Administration subsequently announced plans to reconsider the December 2020 final action in favor of a more stringent ground-level ozone NAAQS. On August 21, 2023, the EPA announced a new review of the ozone NAAQS to reflect updated ozone science in combination with the reconsideration of the December 2020 decision. In June 2025, the EPA announced its plans to reconsider its finalized revisions to the regulatory deadlines for submitting state implementation plan (SIP) revisions and implementation requirements for nonattainment areas under the 2015 ozone NAAQS.

State implementation of the revised NAAQS could also result in the imposition of more stringent requirements through permits issued by the New Mexico Environmental Department or the Texas Commission on Environmental Quality if projects on our land have air emissions above certain thresholds set under applicable laws and regulations. Compliance with the NAAQS requirements or other air pollution control and permitting requirements has the potential to delay the development of oil and natural gas and other projects and increase our or our customers’ costs of development and production, which costs could reduce demand for our services and have a material adverse impact on our results of operations, cash flows and financial position.

Notwithstanding the EPA’s recent proposal to revoke the “endangerment finding,” which supports the majority of the EPA’s GHG-related regulations, in recent years, the agency has made considerable efforts to regulate GHG emissions from oil and natural gas operations. These include regulations that establish construction and operating permit reviews for GHG emissions from certain large stationary sources, require the monitoring and annual reporting of GHG emissions from certain petroleum and natural gas system sources, implement New Source Performance Standards directing the reduction of methane from certain new, modified, or reconstructed facilities in the oil and natural gas sector. In addition, the Inflation Reduction Act of 2022 (the “IRA”) amended the CAA to impose a fee on the emission of excess methane from sources required to report their GHG emissions to the EPA, including those sources in the onshore petroleum and natural gas production and gathering and boosting source categories. In May 2024, the EPA issued a final rule to implement the IRA’s methane fee, although in February 2025, Congress repealed the rule under the Congressional Review Act. Additionally, in the One Big Beautiful Bill Act (“OBBBA”), Congress delayed the implementation of the methane emission fee until 2034. We cannot predict if the Trump Administration and / or Congress may take further actions with respect to the IRA or the methane emissions fee. However, compliance with this and other air pollution control and permitting requirements has the potential to increase costs for our customers and, indirectly, adversely affect our results of operations, cash flows and financial position.

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Produced Water Handling Facilities. Water handling via underground injection is regulated pursuant to the Underground Injection Control (“UIC”) program established under the SDWA and analogous state and local laws and regulations. The UIC program includes requirements for permitting, testing, monitoring, recordkeeping and reporting of produced water handling activities, as well as a prohibition against the migration of fluid containing any contaminant into underground sources of drinking water. State regulations require a permit from the applicable regulatory agencies to operate produced water handling facilities. Authority over underground injection and disposal wells has been delegated by the EPA to the TRRC and the NMOCD, respectively. Although our customers monitor the injection process of their facilities, any leakage from the subsurface portions of the produced water handling facilities could cause degradation of groundwater resources, potentially resulting in suspension of our customers UIC permits, issuance of fines and penalties from governmental agencies, incurrence of expenditures for remediation of the affected resource and imposition of liability by third parties claiming damages for alternative water supplies, property and personal injuries. A change in water handling regulations or the inability to obtain permits for new produced water handling permits in the future may affect our customers’ ability to handle produced water and other substances on our land, which could adversely affect our business, results of operations, cash flows and financial position.

Furthermore, in response to seismic events in the past several years near produced water handling facilities used for disposal by injection of produced water resulting from oil and natural gas activities, federal and some state agencies are investigating whether such facilities have caused increased seismic activity, and some states have restricted, suspended or shut down the use of such produced water handling facilities in certain areas prone to increased seismic activity. Developing research suggests that the link between seismic activity and wastewater disposal may vary by region and that only a very small fraction of the tens of thousands of produced water handling facilities have been suspected to be, or have been, the likely cause of induced seismicity. In 2016, the U.S. Geological Survey identified six states with the most significant hazards from induced seismicity, including Oklahoma, Kansas, Texas, Colorado, New Mexico and Arkansas. As a result of these concerns, regulators in some states have imposed, or are considering imposing, additional requirements in the permitting of produced water handling facilities or otherwise to assess any relationship between seismicity and the use of such wells. For example, the TRRC has issued rules for water handling facilities that imposed certain permitting and operating restrictions and reporting requirements on produced water handling facilities in proximity to faults. New Mexico has, in some parts of the state, issued monitoring and reporting guidelines with respect to seismic activity and requires significant spacing between produced water handling facilities.

States also may issue orders to temporarily shut down or to curtail the injection depth of existing facilities in the vicinity of seismic events. In Texas, the TRRC has pursued several regulatory initiatives since the latter half of 2021 as a result of recent seismic activity in an area of the Midland Basin including: (i) directing operators to pursue voluntary reductions in produced water handling from scores of produced water handling facilities in response to earthquakes; (ii) suspending certain deep produced water handling permits within seismic response areas: and (iii) suspending all produced water handling permits to inject oil and natural gas waste into deep strata within the boundaries of seismic response areas. In November 2021, New Mexico implemented protocols requiring operators to take various actions within a specified proximity of certain seismic activity, including a requirement to limit injection rates if a seismic event is of a certain magnitude. Further, on July 11, 2024, New Mexico announced the administrative cancellation of 75 pending permit applications for UIC Class II wells within the 10-mile County Line Seismic Response Area, due to the potential for increased seismicity within the area. An additional consequence of this seismic activity is lawsuits alleging that produced water handling operations have caused damage to neighboring properties or otherwise violated state and federal rules regulating waste disposal. The adoption and implementation of any new laws, regulations or directives that restrict our customers’, including WaterBridge’s, ability to dispose of wastewater on our land by limiting volumes, disposal rates, produced water handling facility locations or otherwise, or requiring our customers to shut down produced water handling facilities, could reduce the demand for use of our land and resources and limit the fees and royalties we receive from the transportation and the handling of produced water on our land, which would have a material adverse effect on our results of operations, cash flows and financial position.

Hydraulic Fracturing. Hydraulic fracturing involves the injection of water, sand or other proppants and chemical additives under pressure into targeted geological formations to fracture the surrounding rock and stimulate production. Hydraulic fracturing is an important and common practice that is typically regulated by state oil and natural gas commissions or similar agencies. However, the practice continues to be controversial in certain parts of the country, resulting in increased scrutiny and regulation of the hydraulic fracturing process, including by federal agencies that have asserted regulatory authority or pursued investigations over certain aspects of the hydraulic fracturing process.

Moreover, some state and local governments, including states where our customers operate, have adopted, and other governmental entities are considering adopting, regulations that could impose more stringent permitting, disclosure and well construction requirements on hydraulic fracturing operations, including bans on hydraulic fracturing. For example, Texas, New Mexico and other states have adopted regulations that impose stringent permitting, disclosure, disposal and well construction requirements on hydraulic fracturing operations, such as the TRRC’s 2014 “well integrity rule.” States could also elect to place certain prohibitions on hydraulic fracturing. For example, in multiple annual New Mexico legislative sessions, there have been continued efforts to pause hydraulic fracturing and cease state issuance of permits for a four year time period, although none of the bills introduced on this topic have yet passed the New Mexico Legislature.

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In the event that new federal, state or local restrictions or bans on the hydraulic fracturing process are adopted in areas where our land is located, our customers may incur additional costs or permitting requirements to comply with such requirements that may be significant in nature and our customers could experience added restrictions, delays or cancellations in their exploration, development, or production activities, which would in turn reduce the demand for use of our land and resources and have a material adverse effect on our results of operations, cash flows and financial position.

Climate Change. The threat of climate change continues to attract considerable attention from the public and policymakers in the U.S. and around the world. As a result, numerous proposals have been made, and more are likely forthcoming at the international, national, regional and state levels of government to monitor and limit existing emissions of GHGs as well as to restrict or eliminate such future emissions. As a result, our operations as well as the operations of our customers are subject to a series of regulatory, political, litigation, and financial risks associated with our and their operations, including those related to the production and processing of fossil fuels and emission of GHGs.

Endangered Species. The ESA restricts activities that may affect endangered or threatened species or their habitats. Similar protections are afforded under the Migratory Bird Treaty Act (the “MBTA”), which prohibits the taking of protected migratory bird species without prior authorization by the U.S. Fish and Wildlife Service (“FWS”). To the degree that species listed under the ESA or similar state laws, or are protected under the MBTA, live in the areas where we or our customers operate, our and our customers’ abilities to conduct or expand operations and construct facilities could be limited or we and our customers could be forced to incur material additional costs. Moreover, our customers’ drilling activities may be delayed, restricted, or cancelled in protected habitat areas or during certain seasons, such as breeding and nesting seasons. Some of our land and the operations of our customers are located in areas that are designated as habitats for protected species. In addition, the FWS may make determinations on the listing of unlisted species as endangered or threatened under the ESA For example, in November 2022, the FWS listed the northern district population segment of the lesser prairie chicken (encompassing southwest Colorado, south central to western Kansas western Oklahoma and the northeast Texas Panhandle) as threatened under the ESA, and the southern district population segment (covering eastern New Mexico and the southwest Texas panhandle) as endangered. The listing decision for the lesser prairie chicken was challenged by the states of Texas, Kansas, and Oklahoma, and various industry groups, with the U.S. District Court for the Western District of Texas vacating the rule for the northern district population segment in March 2025. Further, the FWS listed the dunes sagebrush lizard as an endangered species under the ESA in a final rule that became effective in June 2024. In September 2024, however, that listing decision was also challenged by the state of Texas in the U.S. District Court for the Western District of Texas. The results of that challenge remain uncertain. Critical habitat for the species has not yet been designated but is expected to occur after a separate rulemaking in the future. The designation of previously unidentified endangered or threatened species could indirectly cause us or our customers to incur additional costs, cause our or our customers’ operations to become subject to operating restrictions or bans and limit future development activity in affected areas. The FWS and similar state agencies may designate critical or suitable habitat areas that they believe are necessary for the survival of threatened or endangered species. Such a designation could materially restrict use of, or access to, federal, state, and private lands, including our land.

Over time, the trend in environmental and occupational health and safety regulation is to typically place more restrictions and limitations on activities that may adversely affect the environment or expose workers to injury and thus, any changes in environmental or occupational health and safety laws and regulations or reinterpretation of enforcement policies that may arise in the future and result in more stringent or costly waste management or disposal, pollution control, remediation or occupational health and safety-related requirements could have a material adverse effect on our business, results of operations, cash flows and financial position. We may not have insurance or be fully covered by insurance against all environmental and occupational health and safety risks, and we may be unable to pass on increased compliance costs arising out of such risks to our customers. We review regulatory and environmental issues as they pertain to us and we consider regulatory and environmental issues as part of our general risk management approach. For more information on environmental and occupational health and safety matters, see “Risk Factors—Risks Related to Environmental and Other Regulations—Legislation or regulatory initiatives intended to address seismic activity, over-pressurization or subsidence could restrict drilling, completion and production activities, as well as WaterBridge’s ability to handle produced water gathered from its customers, which could have a material adverse effect on our results of operations, cash flows and financial position,” “Risk Factors—Risks Related to Environmental and Other Regulations—The results of operations of our customers, as well as producers on or around our land, may be materially impacted by efforts to transition to a lower-carbon economy,” “Risk Factors—Risks Related to Our Business and Operations—We may be subject to claims for personal injury and property damage, or for catastrophic events, which could materially and adversely affect our results of operations, cash flows and financial position,” “Risk Factors—Risks Related to Our Business and Operations—We or our customers may be unable to obtain and renew permits necessary for operations, which could materially and adversely affect our results of operations, cash flows, and financial position” and “Risks Related to Our Business and Operations.”

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Organizational Structure; Availability of Information

LandBridge was formed on September 27, 2023 as a Delaware limited liability company. We are a holding company whose principal asset is membership interests in OpCo. We are also the sole managing member of OpCo. Our principal executive office is located at 5555 San Felipe Street, Suite 1200, Houston, Texas 77056, and we have an additional office in Midland, Texas.

The following diagram reflects our current simplified organizational structure as of December 31, 2025.

1 In connection with the 1918 Ranch Acquisition, we issued 657,411 OpCo Units and a corresponding number of Class B shares to sellers. For more information, see “—Recent Developments—1918 Ranch Acquisition.”

* This diagram is provided for illustrative purposes only and has been simplified by not depicting each individual operating subsidiary.

Our website is located at www.landbridgeco.com. Our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and other reports and filings and amendments thereto filed or furnished with the SEC are available, free of charge, through our website, as soon as reasonably practicable after those reports and other information are filed with or furnished to the SEC. Information contained on our website is not incorporated into this Annual Report or on our other filings with the SEC. Our filings are available in hard copy, free of charge, by contacting us at 5555 San Felipe Street, Suite 1200, Houston, Texas 77056, Attention: Investor Relations, telephone: (432) 445-3929. The SEC also maintains a website (www.sec.gov) that contains reports, proxy and information statements and other information regarding issuers that file electronically with the SEC.

Also posted on our website under “Investor Relations—Governance—Governance Documents,” and available in print upon request made by any shareholder to the Investor Relations Department, are our Code of Business Conduct and Ethics and Whistleblower Policy and Corporate Governance Guidelines, as well as our charter for our Audit Committee. Within the time period required by the SEC, the New York Stock Exchange (the “NYSE”) and NYSE Texas, Inc. (“NYSE Texas”), as applicable, we will post on our website any modifications to the foregoing governance documents and any waivers applicable to senior officers as defined in the applicable governance document, as required by the Sarbanes-Oxley Act.

We webcast our earnings calls and certain events we participate in or host with members of the investment community on our investor relations website. Additionally, we provide notifications of news or announcements regarding our financial performance, including SEC filings, investor events and presentations and press and earnings releases, as part of our investor relations website. We intend for our website to be a forum of public dissemination for purposes of Regulation FD.

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Item 1A. Risk Factors

Described below are certain risks that we believe are applicable to our business. The risks described below are not the only ones that we face. Additional risks not presently known to us or that we currently deem immaterial individually or in the aggregate may also impair our business operations. This information should be considered carefully, together with other information in this Annual Report and other reports and materials we file with the SEC. If any of these risks were to occur, our business, financial condition, results of operations or liquidity and the trading price of our Class A shares could be materially adversely affected.

Risks Related to Our Business and Operations

Our revenues are substantially dependent on ongoing oil and natural gas exploration, development and production activity on or around our land. If E&P companies do not maintain drilling, completion and production activities on or around our land, the demand for the use of our land and resources, as well as the royalties we receive from the production of oil and natural gas and related activities on our land, could be reduced, which could have a material adverse effect on our results of operations, cash flows and financial position.

We are not an E&P company, and we have no control over the oil and natural gas development activity on or around our land. The willingness and ability of E&P companies to continue development activities on and around our land is dependent on a variety of factors that are outside of their and our control, including:

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the demand for and supply of oil and natural gas;
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the capital costs required for drilling, completion and production activities, which could be significantly more than anticipated;
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the ability to access, and cost of, capital;
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prevailing oil and natural gas prices;
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the availability of suitable drilling equipment, production and transportation infrastructure and qualified operating personnel;
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the producers’ expected return on investment in wells drilled on or around our land as compared to opportunities in other areas; and
•
regulatory developments.

The SUAs we enter into and the sand, brackish water and other resources that we or our customers sell are substantially dependent on drilling, completion and production activities by E&P companies on or around our acreage. Similarly, the services WaterBridge provides, from which we earn royalties and fees, are substantially dependent on these same activities. If E&P companies do not maintain such activities on or around our land, their demand for the use of our land and resources and WaterBridge’s services will decline, negatively impacting our results of operations, cash flows and financial position.

Demand for the use of our land and resources, as well as the services provided by WaterBridge, depends substantially on capital spending by producers to construct and maintain infrastructure on and around our acreage and explore for, develop and produce oil and natural gas in the area. These expenditures are generally dependent on such producers’ overall financial position, capital allocation priorities and ability to access capital, and their views of future demand for, and prices of, oil and natural gas. Volatility in oil or natural gas prices (or the perception that oil or natural gas prices will decrease) affects such producers’ capital expenditures and willingness to pursue development activities. This, in turn, could lead to lower demand for the use of our land and resources or WaterBridge’s services, delays in payment of, or nonpayment of, amounts that are owed to us and cause lower rates and lower utilization of our land. In addition, we own oil and gas royalty interests that generate revenue based on oil and natural gas prices and production. As a result, a significant decrease in the price of oil and natural gas or decrease in levels of production of oil and natural gas on and around our land could adversely affect our results of operations, cash flows and financial position. For additional information, please see “—The willingness of E&P companies to engage in drilling, completion and production activities on and around our land is substantially influenced by the market prices of oil and natural gas, which are highly volatile. A substantial or extended decline in oil and natural gas prices may adversely affect our results of operations, cash flows and financial position.”

For the year ended December 31, 2025, we received revenue from approximately 208 customers, and our top ten customers represented 73% of our total revenues. While we expect these revenue streams to be recurring, our contracts with our significant customers, which represent a large portion of our revenues, typically do not contain minimum volume commitment provisions for land use or brackish water volumes to be purchased. As a result, our revenues are dependent on ongoing demand from these customers, which may decrease due to factors beyond our control. Our producers make all decisions as to investments in, and production from, their wells, and our revenues are dependent upon decisions made by such producers, among other factors. For example, we cannot

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control whether a producer chooses to develop a property or the success of drilling and development activities, which depend on a number of factors under the control of such producer. There can be no assurance that such producers will take actions or make decisions that will be beneficial to us, which could result in adverse effects on our results of operations, cash flows and financial position.

The willingness of E&P companies to engage in drilling, completion and production activities on and around our land is substantially influenced by the market prices of oil and natural gas, which are highly volatile. A substantial or extended decline in oil and natural gas prices may adversely affect our results of operations, cash flows and financial position.

Market prices for oil and natural gas are volatile and a decrease in prices could reduce drilling, completion and production activities by producers on or around our land, resulting in a reduction in the use of our land and resources and WaterBridge’s services, as well as the amount of revenues we receive from the production of oil and natural gas. The market prices for oil and natural gas are subject to U.S. and global macroeconomic and geopolitical conditions, among other things, and, historically, have been subject to significant price fluctuations and may continue to change in the future. Prices for oil and natural gas may fluctuate widely in response to relatively minor changes in supply and demand, market uncertainty and a variety of additional factors that are beyond our control and the control of producers on or around our land, such as:

•
general market conditions, including macroeconomic trends, inflation, interest rates and associated policies of the Federal Reserve;
•
the domestic and foreign supply of and demand for oil and natural gas;
•
the price and quantity of foreign imports and U.S. exports of oil and natural gas;
•
market expectations about future prices of oil and natural gas;
•
oil and natural gas drilling, completion and production activities and the cost of such activities;
•
political and economic conditions and events domestically and in foreign oil and natural gas producing countries, including embargoes, increased hostilities in the Middle East, and other sustained military campaigns, the Russia-Ukraine war, as well as the Israel-Hamas conflict, conditions in South America, Central America, China and Russia, and acts of terrorism or sabotage;
•
the ability of and actions taken by members of OPEC+ and other oil-producing nations in connection with their arrangements to maintain oil prices and production controls;
•
the impact on worldwide economic activity of an epidemic, outbreak or other public health event;
•
the level of consumer product demand and any efforts that may negatively impact the future production of oil and natural gas;
•
weather conditions, such as winter storms, fires, earthquakes and flooding, and other natural disasters;
•
the level of U.S. domestic oil and natural gas production;
•
U.S. and non-U.S. governmental regulations and energy policy, including environmental initiatives and taxation;
•
changes in global and domestic political and economic conditions, both generally and in the specific markets in which we operate, including the impact related to changing U.S. and foreign trade policies, such as increased trade restrictions or tariffs;
•
the effects of litigation;
•
physical, electronic and cybersecurity breaches;
•
the proximity, cost, availability and capacity of oil and natural gas pipelines and other transportation infrastructure;
•
technological advances affecting energy consumption, energy storage and energy supply;
•
the price and availability of alternative fuels and any efforts to transition to a low-carbon economy; and
•
the impact of energy conservation efforts.

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These factors have at times resulted in, and may in the future result in, a reduction in global economic activity and volatility in the global financial markets and make it extremely difficult to predict future oil and natural gas price movements with certainty. A sustained decline in oil and natural gas prices may reduce the amount of oil and natural gas that can be produced economically by producers on or around our land, which may reduce such producers’ willingness to develop such land and use our land and resources and WaterBridge’s services. Producers on or around our land could also determine during periods of low oil and natural gas prices to shut-in or curtail production from wells on such land, or plug and abandon marginal wells that otherwise may have been allowed to continue to produce for a longer period under conditions of higher prices. The scale and duration of the impact of these factors cannot be predicted but could lead to an increase in our customers’ operating costs or a decrease in our or our customers’ revenues, and any substantial decline in the price of oil and natural gas or prolonged period of low oil and natural gas prices may materially and adversely affect our results of operations, cash flows and financial position.

Future land acquisitions would expose us to risks associated with acquisitions and the commercialization of additional acreage.

We may pursue opportunistic future land acquisitions that we expect to complement or expand our current land position. We may not be able to identify attractive acquisition opportunities, and even if we do so, we may not be able to complete the acquisition on commercially acceptable terms, or at all. No assurance can be given that we will be able to identify additional suitable acquisition opportunities, negotiate acceptable terms, obtain financing for acquisitions on acceptable terms, or at all, or successfully acquire such identified acreage.

The process of integrating acquired acreage may involve unforeseen difficulties and may require a disproportionate amount of our managerial and financial resources. Our failure to realize the anticipated benefits of our acquisitions could have a material and adverse effect on our results of operations, cash flows and financial position. The successful acquisition and integration of acreage requires an assessment of several factors, including:

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the availability of brackish water and the suitability of the land for produced water handling;
•
proximity to recoverable oil and natural gas reserves and the level of drilling, completion and production operations of the target acreage;
•
presence of minable sand;
•
future oil and natural gas prices and their applicable differentials;
•
potential environmental and other liabilities;
•
any restrictive covenants or other use restrictions that would prohibit or restrict the ability to engage in certain activities on the target land; and
•
regulatory, permitting and other similar matters, including condemnation proceedings.

The accuracy of these assessments is inherently uncertain. Although we will perform a review of the subject acreage that we believe to be generally consistent with industry practices, the accuracy of these assessments is inherently uncertain and may not reveal all existing or potential problems or fully assess their deficiencies and capabilities. Inspections may not always be performed on the totality of such acreage, and environmental problems are not necessarily observable even when an inspection is undertaken. Even when problems are identified, the seller may be unwilling or unable to provide effective contractual protection against all or part of the problems.

Because a significant portion of our future revenue growth is expected to be derived from WaterBridge, any development that materially and adversely affects either of their businesses, operations or financial condition could have a material adverse impact on us.

WaterBridge is among our most significant customers and is expected to play an increasingly important role in our financial performance over the long term. Accordingly, we are indirectly subject to the business risks faced by WaterBridge. Because a significant portion of our revenues is derived from WaterBridge, any development that materially and adversely affects WaterBridge’s businesses, operations or financial condition could have a material adverse impact on us.

In addition, WaterBridge does not own all of the land on which its infrastructure is located and certain portions of such infrastructure located outside of our land are subject to leases, rights-of-way and easements with third parties. Such infrastructure is necessary to deliver produced water volumes to facilities on our land and if WaterBridge were to lose these rights or be required to relocate its infrastructure, our business could be materially and adversely affected as a result of produced water delivery interruptions. If WaterBridge is unable to enter into favorable contracts or to obtain the necessary regulatory and land use approvals on favorable

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terms, it may not be able to construct and operate its assets as anticipated, or at all, which could negatively affect our results of operations, cash flows and financial position.

Our reliance on WaterBridge and its personnel to manage and operate our business exposes us to certain risks.

Pursuant to the Shared Services Agreement, WaterBridge provides general and administrative services, as well as limited operational and maintenance services to us, together with five dedicated employees providing field services and five dedicated employees providing corporate services. Our success depends on the efforts, experience, diligence, skill and network of business contacts of such personnel and the quality of services that WaterBridge offers. However, the allocation of such resources is generally within WaterBridge’s discretion. We can offer no assurance that WaterBridge will continue to provide services to us or that we will continue to have access to WaterBridge’s personnel or that the Manager will be able to recruit and retain personnel necessary to provide us with key services. If the Shared Services Agreement is terminated and no suitable replacement is found to provide management and operating services for our land, or if the Manager is unable to recruit and retain those personnel necessary to perform services under the Shared Services Agreement, we may not be able to execute our business plan, and our results of operations, cash flows and financial position may be materially and adversely affected.

We rely on a small number of key individuals, certain of whom have responsibilities with affiliated entities, whose absence or loss could adversely affect our business, and difficulty attracting and retaining experienced personnel could reduce our competitiveness and prospects for future success.

The successful operation and growth of our business depends to a large extent on a small number of individuals to whom many key responsibilities within our business have been assigned. Such individuals hold positions with our affiliates, including Five Point and WaterBridge, and dedicate a portion of their time and resources to the activities of such affiliates, and there can be no assurance as to the future allocation of time and resources between our business, on the one hand, and our affiliates in which our personnel, other service providers, and management team hold an interest, on the other hand. We rely on our key personnel for their knowledge of the energy industry, relationships within the industry and experience in operating a business in the Permian Basin. The loss of the services of one or more of these key personnel, and the inability to recruit or retain additional key personnel, could have an adverse effect on our business. Further, we do not have currently a succession plan for the replacement of, and do not maintain “key-person” life insurance policies on, such key personnel.

In addition, our business and the success thereof is also dependent, in part, on our ability and the ability of the Manager to attract and retain qualified personnel. Acquiring and keeping these personnel could prove more difficult or cost substantially more than estimated due to competition within the broader energy industry. Other companies may be able to offer better compensation and benefits packages to attract and retain such personnel. If we or the Manager cannot retain experienced personnel or attract additional experienced personnel, our ability to compete in our industry could be harmed, which could materially and adversely affect our results of operations, cash flows and financial position.

Our acreage is located in the Permian Basin, making us vulnerable to risks associated with geographic concentration in a single geographic area.

Our acreage is located in the Permian Basin in Texas and New Mexico making us vulnerable to risks associated with geographic concentration in that basin. In particular, we and our customers may be disproportionately exposed to the impact of regional supply and demand factors, delays or interruptions of production from oil and natural gas wells in this area, availability of equipment, facilities, personnel or services, market limitations, governmental regulation and political activities, processing or transportation capacity constraints, natural disasters, adverse weather conditions, water shortages or other drought related conditions or interruption of the processing or transportation of oil and natural gas. In addition, the effect of fluctuations on supply and demand may become more pronounced within specific geographic oil and natural gas producing areas such as the Delaware Basin, which may cause these conditions to occur with greater frequency or magnify the effects of these conditions.

Additionally, our brackish water sales and sand royalties may be adversely affected by risks associated with our geographic concentration, including the presence of a limited number of potential customers on or near our land, competition with adjacent landowners to provide an attractive development site for such resources, particularly if such landowners are closer to the location of oil and natural gas development activity, and legislation or regulatory initiatives limiting the utilization of brackish water and sand in the Permian Basin.

We have a limited operating history, and an investment in our Class A shares is highly speculative. Because we have a limited operating history, it may be difficult to evaluate our ability to successfully implement our business strategy.

Our predecessor for accounting purposes, OpCo, was formed in September 2021, and, accordingly, we have a limited operating history and track record. As a result, our prior operating history and historical financial statements may not be a reliable basis for evaluating our business prospects or the future value of our Class A shares and may make it difficult to assess our ability to operate

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profitably. Our future results will be dependent on, among other things, a number of factors and trends discussed in the “Business” section and the risks discussed elsewhere in this “Risk Factors” section, as well as our ability to execute our business model. Our business model may not be successful, and if unsuccessful, we may be unable to modify it in a timely and successful manner.

Because of our limited operating history, our business model and the attractiveness of our acreage to our customers, as well as the performance of any other future assets, are not yet proven. As a result, it may be difficult to evaluate our business and results of operations to date and to assess our future prospects.

In addition, we may encounter risks and difficulties experienced by companies whose performance is dependent upon newly acquired assets, such as failing to integrate, or realizing the expected benefits of, such assets. As a result of the foregoing, we may be less successful in achieving a consistent revenue base capable of generating cash flows from operations compared with a company that has a longer operating history. In addition, we may be less equipped to identify and address risks and hazards in the conduct of our business than those companies that have longer operating histories.

We may experience difficulty in achieving and managing future growth.

Future growth may place strains on our resources, possibly negatively affecting our results of operations, cash flows and financial position. Our ability to grow will depend on a number of factors, including:

•
investment by our customers in infrastructure on or around our land;
•
the amount of brackish water use and associated prices for such brackish water;
•
the results of drilling operations on and in proximity to our land;
•
future and existing limitations imposed by law or environmental regulations;
•
oil and natural gas prices;
•
our ability to develop existing and future projects, including sand mines, solar projects and data centers;
•
our ability to identify and acquire additional acreage;
•
our or the Manager’s ability to continue to retain and attract skilled personnel, and our ability to contract for the services of key personnel who are sufficiently dedicated to performing services with respect to our business;
•
our ability to maintain or enter into new relationships with customers;
•
our or our customers’ ability to obtain rights from our neighboring landowners on economic terms, or at all, to gain access to our land or transport resources, such as sand and brackish water, away from our land, to their point of end use; and
•
our access to, and cost of, capital in the event we pursue future acquisitions.

We may also be unable to make attractive acquisitions, which could inhibit our ability to grow, or we could experience difficulty commercializing any acquired acreage. It may be difficult to identify attractive acquisition opportunities and, even if such opportunities are identified, our existing and/or future debt agreements contain, or may contain, limitations on our ability to enter into certain transactions, which could limit our future growth.

We may not be successful in pursuing additional commercial opportunities on our land from non-hydrocarbon based energy production and other users.

One of our strategies is to expand the use of our land by customers not engaged in hydrocarbon-based energy development. We may not be able to correctly identify such commercial opportunities or may be unsuccessful in attracting industry participants to develop projects on our land. For example, we are party to a lease development agreement pursuant to which the counterparty holds an option to develop a data center and related facilities on our land; however, we can offer no assurance that the counterparty will lease the site, nor can there be any assurance that such counterparty will be successful in its efforts to develop the data center or any power generation facilities.

The rapidly evolving and competitive nature of many of the industries we are targeting for such development makes it difficult to evaluate the future prospects of these projects. In addition, we have limited insight into emerging trends that may adversely affect the development of such projects on our land or otherwise, and the developers of these projects, if they were to materialize, would

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encounter the risks and difficulties frequently experienced by growing companies and project developers in rapidly changing industries, including, unpredictable and volatile revenues, increased expenses, an uncertain regulatory environment, novel litigation and corresponding outcomes and changes in business conditions. The viability of this business strategy and the resulting demand for the use of our land and its resources by such project developers will be affected by many factors outside of our control and may not be successful.

The construction by our customers of new infrastructure on our land is subject to regulatory, construction, supply chain and other risks common in the development and operation of facilities and other infrastructure.

We intend to grow our business through revenues from SUAs or other contracts pursuant to which our customers develop infrastructure on our land. These infrastructure projects involve numerous regulatory, environmental, political and legal uncertainties, including political opposition by environmental groups, local groups and other advocates. Such opposition can take many forms, including the delay or denial of required governmental permits, organized protests, attempts to block or sabotage our customers’ operations, intervention in regulatory or administrative proceedings related to our customers’ permitting efforts or otherwise involving their assets, or lawsuits or other actions designed to prevent, disrupt or delay the operation of our customers’ assets or their business. There can be no assurance that such infrastructure will be developed at all or that our customers will complete these projects on schedule or at an economical cost, and we may not realize the anticipated benefits of such projects.

Our customers may also encounter technical difficulties during the construction of such infrastructure leading to a reduction in capacity or a shorter useful life. Moreover, our customers may undertake expansion projects to capture anticipated future growth that does not materialize or for which they are unable to acquire new customers. As a result, the new facilities and infrastructure developed by our customers on our acreage may not be able to attract enough demand to achieve their expected investment return, which could materially and adversely affect our results of operations, cash flows and financial position.

In addition, acts of sabotage or eco-terrorism could cause significant damage or injury to people, property or the environment or lead to extended interruptions of operations. Moreover, governmental authorities exercise considerable discretion in the timing and scope of permit issuance and the public may engage in the permitting process, including through intervention in the courts. Negative public perception could cause the permits our customers require to conduct their operations to be withheld, delayed or burdened by requirements that restrict our customers’ ability to profitably conduct their business. Any such event that delays or otherwise interrupts the revenues generated by our customers’ operations, or which causes them to make significant expenditures not covered by insurance, could adversely affect their payments to us in respect of use of existing infrastructure as well as future development of infrastructure on our land.

Technological advancements in connection with alternatives to hydraulic fracturing could decrease the demand for our brackish water sales and WaterBridge’s produced water transportation and handling operations on our land.

Wide-scale development of techniques to recycle produced water for use in completion activities or otherwise could adversely affect the amount of produced water transported to and handled on our land, which could materially and adversely affect our results of operations, cash flows and financial position. Some E&P companies are focusing on developing and utilizing non-water fracturing techniques, including those utilizing propane, carbon dioxide or nitrogen instead of water. If producers in the Permian Basin begin to shift their fracturing techniques to waterless fracturing in the development of their wells, our brackish water sales could be materially and negatively impacted.

Inadequate brackish water supplies could have a material adverse effect on our revenues.

One of our significant sources of revenue is the sale of brackish water for use in oil and natural gas drilling and completion operations. Our ability to meet the existing and future demand for brackish water depends on an adequate supply of such brackish water from our acreage. Additionally, regulatory restrictions on the use of brackish water and the development of brackish water wells, lack of available water rights, drought, overuse of sources of water, protection of threatened species or habitats or other factors may limit the availability of brackish water. No assurance can be given that we will be able to produce enough brackish water to fully satisfy future customer demand.

If we are unable to produce adequate brackish water supplies, our results of operations, cash flows, and financial position may be adversely affected by, among other things, the following:

•
a reduction in the amount of brackish water we sell and reduced revenues therefrom;
•
an increase in operating costs; and

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•
an increase in capital expenditures associated with building pipelines to connect to alternative sources of brackish water supply, new wells to replace those that are no longer in service or are otherwise inadequate to meet the needs of customers, and reservoirs and other facilities to conserve or reclaim water.

We may or may not be able to recover increased operating and capital costs as a result of water shortages on a timely basis, or at all.

Sand operations are subject to operating risks that are often beyond the control of the mine operator. These risks can adversely affect production levels and costs, which could adversely affect sand production from our acreage.

We do not operate the sand mines on our land, but our customers who conduct such operations are subject to risks normally encountered in the mining industry generally and the sand mining industry in particular. These risks include:

•
changes in the price and availability of transportation, natural gas or electricity;
•
unanticipated ground, grade or water conditions;
•
unusual or unexpected geological formations or pressures;
•
pit wall failures or surface rock falls;
•
inclement or hazardous weather conditions;
•
environmental hazards and industrial accidents;
•
changes in applicable laws and regulations (or the interpretation thereof);
•
inability to maintain necessary permits or mining or water rights;
•
restrictions on blasting operations;
•
inability to obtain necessary mining or production equipment or replacement parts;
•
fires, explosions or industrial accidents or other accidents;
•
technical difficulties or key equipment failures;
•
labor disputes;
•
late delivery of supplies; and
•
facility shutdowns in response to environmental regulatory actions.

Any of these risks could result in damage to current and future mining properties or production facilities on our land, personal injury, environmental damage, delays in mining or processing, losses or possible legal liability. Any prolonged downtime or shutdowns at any of the mining properties or production facilities on our acreage could have a material adverse effect on our results of operations, cash flows and financial position.

In addition, transportation and related logistics costs are a significant component of the total delivered cost of sand for oil and natural gas operations. As a result, the cost of transporting sand to the well site is a key factor in our customers’ purchasing decisions. The development of additional in-basin sand mines that are closer to areas of drilling activity could reduce demand for sand produced from our acreage. For example, a number of companies have announced plans to develop or acquire, are currently developing or expanding, or have recently acquired or completed sand mine projects in the Delaware Basin that may be closer to ongoing development activity. Any such reduction in demand for sand from our land could materially affect our results of operations, cash flows and financial position.

Interruption of our customers’ supply chains could negatively impact our business and operations as well as reduce our revenues.

Any material interruption in our customers’ supply chains, such as a material interruption of the resources required to drill and complete oil and natural gas wells, to construct produced water pipelines on our land and otherwise construct infrastructure and extract resources from our land, such as those resulting from interruptions in service by the third-party providers or common carriers that ship goods within our customers’ distribution channels, trade restrictions, such as changing U.S. and foreign trade policies relating to

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increased trade restrictions or tariffs, embargoes or customs restrictions, social or labor unrest, natural disasters, epidemics or pandemics or political disputes and military conflicts that cause a material disruption in our customers’ supply chains, could have a negative impact on our business and our profitability. In the event of disruptions in our customers’ supply chains, the labor and materials they rely on in the ordinary course of business may not be available at reasonable rates or at all.

Any such supply disruption could adversely affect activity levels on or around our land or significantly delay construction and development on our land, which could materially and adversely affect our results of operations, cash flows and financial position.

Operational disruptions on or around our land from weather, natural disasters, terrorism or other similar causes could impact our results of operations, cash flows and financial position.

A natural disaster (such as an earthquake, tornado, fire or flood) or an act of terrorism could damage or destroy our customers’ infrastructure on or around our land or result in a disruption of operations on or around our land.

Additionally, our land is located in the Permian Basin, which may be adversely affected by earthquakes and adverse weather conditions. During periods of heavy rain or extreme weather conditions such as tornados or after other disruptive events such as earthquakes or wildfires, we or our customers may be unable to access our land and our customers’ infrastructure may be damaged. Such disruptions could materially and adversely affect our results of operations, cash flows and financial position.

Global incidents, such as world health events, could have a similar effect of disrupting our or our customers’ businesses to the extent they reach and impact the service areas on or around our land, the availability of supplies our customers need, the customers we or our customers serve, or the employees or other personnel who operate our or our customers’ businesses.

Any such destruction of or damage to infrastructure or interruptions of operations could materially and adversely affect our results of operations, cash flows and financial position.

We or our customers may be unable to obtain and renew permits necessary for operations, which could materially and adversely affect our results of operations, cash flows and financial position.

Our or our customers’ ability to conduct operations is subject to a variety of required permits from various governmental authorities, which may limit such operations, including those associated with oil and natural gas drilling, completion and production activities, disposal or transport of produced water and other hazardous materials or wastes or oilfield wastes, construction, stormwater, water use, air emissions, mining, and other activities that may be conducted in association with operations on our acreage. The public often has the right to comment on permit applications and otherwise participate in the permitting process, including through court intervention. Accordingly, permits required to conduct our or our customers’ operations may not be issued, maintained, or renewed, may not be issued or renewed in a timely fashion, or may involve requirements that restrict our or our customers’ ability to economically conduct operations. Limitations on our or our customers’ ability to conduct operations due to the inability to obtain or renew necessary permits or similar approvals could materially and adversely affect our results of operations, cash flows and financial position.

The deterioration of the financial condition of our customers could adversely affect our business, and the termination of activities on or around our land by one or more significant customers could materially and adversely affect our results of operations, cash flows and financial position.

For the year ended December 31, 2025, revenues from WaterBridge, VTX Energy and ConocoPhillips each individually comprised more than 10% of our total revenues and collectively represented 47% of our total revenues. WaterBridge, VTX Energy, TPL and EOG Resources each individually comprised 21%, 19%, 14% and 11%, respectively, of our total accounts receivable for the year ended December 31, 2025 and collectively represented 65% of our total accounts receivable at such date.

We expect to continue to depend on key customers to support our revenues for the foreseeable future, and although each of WaterBridge, VTX Energy and ConocoPhillips operates on our land under long-term contracts, each of these customers has the right to reduce or cease operations on our acreage at their sole discretion under certain circumstances, as our contracts with such customers generally do not contain minimum commitment provisions for land use or brackish water volumes to be purchased. See “Business—Customers; Material Contracts and Marketing” for further information on our agreements with our significant customers. The loss of revenue derived from any of these customers’ operations on our land could adversely affect our results of operations, cash flows and financial position. During times when the oil and natural gas markets weaken, our customers are more likely to experience financial difficulties, including generating less cash flow due to lower oil and natural gas prices and being unable to access or receive favorable terms in connection with debt or equity financing, which could result in a reduction in our customers’ activities on or around our land. Furthermore, the determination by a customer to initiate or maintain activities on or around our land largely depends on the location of our surface acreage relative to the nature and location of such customer’s operations and such customer’s need for the use of our land and resources. Our customers are limited to entities operating on and around our acreage in the Delaware Basin.

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We cannot assure you that any of our customers will continue to do business with us. If these customers do not maintain their activities on or around our land, their demand for use of our land and resources will be reduced. The loss of revenue from key customers, failure to renew contracts upon expiration, or a sustained decrease in demand by key customers could result in a substantial loss of revenues and could materially and adversely affect our results of operations, cash flows and financial position.

We may experience delays in the payment of royalties and fees and be unable to replace customers or producers that do not make required payments to us, and we may not be able to terminate our agreements with defaulting customers that declare bankruptcy.

We may experience delays in receiving royalty, fee and other payments from our customers or producers. A failure on the part of a producer to make royalty payments typically gives us the right to terminate the lease agreement, repossess the property and enforce payment obligations under the agreement. If we repossessed any of our mineral interests, we would seek a replacement producer. However, we might not be able to find a replacement producer and, if we did, we might not be able to enter into a new lease on favorable terms within a reasonable period of time. In addition, with respect to a customer or producer that is subject to a proceeding under Title 11 of the United States Code (the “Bankruptcy Code”), our right to enforce or terminate the agreement for any defaults, including nonpayment, may be substantially delayed or otherwise impaired. In general, in a proceeding under the Bankruptcy Code, the bankrupt customer or producer would have a substantial period of time to decide whether to ultimately reject or assume our agreement, which could prevent the execution of a new agreement or the assignment of the existing agreement to another customer or producer. In the event that the customer or producer rejected the agreement, our ability to collect amounts owed would be substantially delayed, and our ultimate recovery may be only a fraction of the amount owed or nothing. In addition, if we are able to enter into a new agreement with a new customer or producer, the replacement customer or producer may not achieve the same levels of activity on or around our land at the same price as the customer or producer it replaced.

Additionally, we are subject to the risk of loss resulting from nonpayment or nonperformance by our customers of their respective obligations. Although we maintain policies and procedures to limit such risks, our credit procedures and policies may not be adequate to fully eliminate customer credit risk. If we fail to adequately assess the creditworthiness of existing or future customers or unanticipated deterioration in their creditworthiness, any resulting increase in nonpayment or nonperformance by them of their respective obligations and our inability to collect on outstanding payables or find substitute customers could have an adverse effect on our results of operations, cash flows and financial position. A decline in oil and natural gas prices could negatively impact the financial condition of our customers and sustained lower prices could impact their ability to meet their obligations to us. Further, our contract counterparties may not perform or adhere to our existing or future contractual arrangements. To the extent one or more of our contract counterparties is in financial distress or commences bankruptcy proceedings, contracts with these counterparties may be subject to renegotiation or rejection under applicable provisions of the Bankruptcy Code. Any material nonpayment or nonperformance by our contract counterparties due to inability or unwillingness to perform or adhere to contractual arrangements could adversely affect our results of operations, cash flows and financial position.

Declining general economic, business or industry conditions may have a material adverse effect on our results of operations, cash flows and financial position.

Concerns over global economic conditions, global health threats, trade policies, increased trade restrictions and tariffs, supply chain disruptions, increased demand, labor shortages associated with a fully employed U.S. labor force, geopolitical issues, inflation, interest rates, the availability and cost of credit and the United States financial markets and other factors have contributed to increased economic uncertainty. Although inflation in the United States had been relatively low for many years, there was a significant increase in inflation beginning in the second half of 2021, with a general decline beginning in the second half of 2022 and a relative settling in in 2023 and 2024. In addition, the current presidential administration has stated an intention to continue imposing tariffs on international goods, such as those produced in both China and Europe. To the extent that any U.S. trade policy results in retaliatory tariffs against the U.S., such developments could result in inflationary pressures and have an adverse effect on our customers’ business, and reduce demand for use of our land and services, which could have a material adverse effect on our business, results of operations and financial condition. Though we incorporate inflation escalators in most of our long-term customer contracts, contractual provisions providing for inflation escalators in certain contracts are subject to caps, which may limit the amount of any single pricing increase, and may also vary as to the commencement date of such increases and the timing and calculation of the applicable adjustment. As a result, inflation may outpace the revenue adjustments provided by those provisions. Our customers may also experience supply chain constraints, due to international trade policies or otherwise, and inflationary pressure on their cost structures, which could impact the revenues we receive from them. Our customers also may face shortages of equipment, raw materials, supplies, commodities, labor and services, which may prevent them from executing their development plans on or around our land. These supply chain constraints, trade policies and inflationary pressures may continue to adversely impact our customers’ operating costs and, if they are unable to manage their supply chain, it may impact their ability to procure materials and equipment in a timely and cost-effective manner, if at all, which could materially and adversely affect the revenues received in respect of our customers’ operations on or around our land.

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In addition, hostilities related to the Russia-Ukraine war, as well as the Israel-Hamas conflict and heightened tensions in the Middle East, and the occurrence or threat of terrorist attacks in the United States or other countries could adversely affect the global economy. These and other factors, such as declining business and consumer confidence, may contribute to an economic slowdown and a recession. Concerns about global economic health also have a significant adverse impact on global financial markets and commodity prices. If the economic climate in the United States or abroad deteriorates, worldwide demand for oil and natural gas products could diminish, which could impact operations on or around our land, affect the ability of our customers to continue operations and ultimately adversely impact our results of operations, cash flows and financial position.

We may be subject to claims for personal injury and property damage, catastrophic events, and those related to contamination resulting from our customers’ operations, which could materially and adversely affect our results of operations, cash flows and financial position.

Our customers will be subject to all of the hazards and operating risks associated with their operations, which include oil and natural gas drilling, completion and production activities, sand mining, production and distribution of brackish water, water handling, waste disposal, construction and operation of non-hazardous oilfield reclamation and solid waste facilities, power storage, microgrids, cryptocurrency mining, fuel stations, battery and/or solar facilities, and any other operations that may occur on our acreage. These hazards may include the risk of fire, explosions, blowouts, seismic events, surface cratering, uncontrollable flows of crude oil, natural gas, NGLs and produced water, pipe or pipeline failures, abnormally pressured formations, casing collapses and environmental hazards such as crude oil and NGL spills, natural gas leaks and ruptures or discharges of toxic gases, release of hazardous materials into the environment, and worker health and safety issues. The occurrence of any of these events could result in substantial losses to our customers due to injury or loss of life, severe damage to or destruction of property, natural resources and equipment, pollution or other environmental damage, clean-up responsibilities, regulatory investigations and penalties, suspension of operations and repairs required to resume operations.

In addition, litigation arising from operations on our acreage may cause us to be named as a defendant in lawsuits asserting potentially large claims, including claims for defense, indemnity, and exemplary damages. We generally seek indemnity from our customers for liabilities arising from their operations on our land, and we maintain what we believe is customary and reasonable insurance to protect our business against these potential losses, but such indemnity and insurance may not be adequate to cover our liabilities, and we are not fully protected or insured against all risks.

Subject to certain exceptions, our customers assume responsibility for, including control and removal of, all other pollution or contamination that may result from their operations on our acreage, such as WaterBridge’s oil reclamation, solid waste and landfill operations. We may have liability in such cases if we are grossly negligent or commit willful acts, or as owners of the land under laws that impose strict, joint and several liability for pollution clean-up, such as CERCLA (as defined herein). Our customers generally agree to indemnify and defend us against claims relating to contamination resulting from their operations and related closure and remedial obligations, damage or loss of a well, reservoir, geological formation, underground strata, or water resources, or the loss of oil, natural gas, mineral, or water, but sometimes such indemnity and defense is subject to exceptions for claims for gross negligence or willful misconduct, and we may not be able to collect under these indemnities if the applicable customer is in financial distress. Our customers also generally assume responsibility for claims arising from their employees’ personal injury or death, or the damage or loss of their property, to the extent that their employees are injured or their properties are damaged by operations on our acreage, but sometimes such indemnity and defense is subject to exceptions for claims resulting from our gross negligence or willful misconduct, and we may not be able to collect under these indemnities if the applicable customer is in financial distress. However, we might not succeed in enforcing such contractual risk allocation or might incur an unforeseen liability falling outside the scope of such risk allocation.

The occurrence of any of these events could result in interruption of our customers’ operations or substantial losses to us or our customers, which could materially and adversely affect our results of operations, cash flows and financial position.

Our insurance coverage may not fully cover our losses, and we may in the future encounter increased costs related to, and lack of availability of, insurance.

While we maintain insurance coverage at levels that we believe to be reasonable and prudent, we can provide no assurance that our current levels of insurance will be sufficient to cover any losses that we have incurred or may incur in the future, whether due to deductibles, coverage challenges or other limitations. Additionally, we may not be able to maintain adequate insurance in the future at rates or on other terms we consider commercially reasonable. Additionally, insurance will not cover many types of interruptions or events that might occur and will not cover all risks associated with our business and may not be available in certain areas in which we operate. In addition, the proceeds of any such insurance may not be paid in a timely manner and may be insufficient if such an event were to occur. The occurrence of a significant event, the consequences of which are either not covered by insurance or not fully insured, or a significant delay in, or denial of, the payment of a major insurance claim, could materially and adversely affect our results of operations, cash flows and financial position.

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Cyber incidents or attacks targeting systems and infrastructure used by the oil and natural gas industry may adversely impact our operations, and a cyber incident or systems failure could result in information theft, data corruption or operational disruption and our results of operations, cash flows or financial position may be adversely impacted.

We and our customers, and the energy industry generally, increasingly rely on uninterrupted information technology systems and digital technologies to operate our respective businesses. This reliance extends to the majority of our and our customers’ operations, from monitoring and managing critical infrastructure to processing and storing proprietary and sensitive information. Our information technology systems and networks, and those of our customers, vendors, and other business partners, are subject to damage or interruption from cyberattacks, power outages, computer and telecommunications failures, catastrophic events, such as natural disasters or acts of war or terrorism, usage errors by our employees or other personnel, and other events unforeseen or generally beyond our control. Damage or interruption to information technology systems could result in significant costs and may lead to significant liability, loss of critical data, reputational damage, and disruptions to services or operations.

Threats to information technology systems associated with cybersecurity risks and cyber incidents or attacks continue to grow. Cyber incidents, including deliberate attacks, have increased in frequency globally, with energy-related assets particularly at risk. Due to the critical nature of these assets, any such attack on energy infrastructure could result in widespread service disruptions and challenges in maintaining public trust. The U.S. government has issued public warnings that specifically indicate energy assets could be targets of cybersecurity threats. Our technologies and systems, networks, and those of our customers, affiliates, vendors and other business partners, may become the target of cyberattacks or information security breaches that could result in the unauthorized access, release, gathering, monitoring, corruption, misuse, or destruction of proprietary, personal and other information, or other disruption of business operations. Any such event could lead to significant liability, loss of critical data, reputational damage and disruptions to our services or operations.

While we have implemented and maintain commercially reasonable security measures and safeguards, such security measures and safeguards may not be sufficient to protect against or effectively mitigate an attack. Attackers are increasingly using advances in technologies, such as artificial intelligence and encryption bypasses that may evade our efforts. Emerging artificial intelligence technologies may improve or expand the capabilities of malicious third parties in a way we cannot predict, including being used to develop new hacking tools, exploit vulnerabilities, obscure malicious activities and increase the difficulty detecting threats. Moreover, some of our networks and systems are managed by third-party service providers and are not under our direct control. We regularly enter into transactions with third parties, some of whom may have less sophisticated electronic systems or networks and may be more vulnerable to cyberattacks. Our reliance on these third parties means that any vulnerability in their systems could propagate to our own systems or affect our data, increasing our risk exposure despite our internal controls.

In addition, certain cyber incidents, such as surveillance, ransomware, deepfake-based social engineering attacks, and credential stuffing, may remain undetected for some period of time, and cyber incidents and attacks are continually evolving and unpredictable. As cyber incidents and attacks continue to evolve, we may be required to expend additional resources to continue to modify or enhance our protective measures or to investigate and remediate any vulnerability to cybersecurity incidents. While we utilize various procedures and controls to reduce the risk of the occurrence of cyber incidents, there can be no assurance that our business, finances, systems and assets will not be compromised in a cyber incident. Any failure or perceived failure to detect or respond effectively to a cybersecurity incident could lead to significant liability, undermine shareholder and stakeholder trust, and negatively impact business continuity. Furthermore, we are subject to an evolving regulatory landscape, including state, federal, and international data privacy laws that require rigorous cybersecurity standards and standards relating to artificial intelligence. Compliance with various data privacy and cybersecurity regulations may impose significant costs, and any perceived or actual failure to comply could result in regulatory penalties, litigation, and reputational harm.

Our future results following our acquisitions will suffer if we do not effectively manage our expanded operations.

Since our formation, the size of our asset base has increased significantly. Our future success will depend, in part, upon our ability to manage this expanded business, which poses substantial challenges for management, including challenges related to the management and monitoring of expanded acreage, new operations and associated increased costs and complexity. We may also face increased scrutiny from governmental authorities as a result of the significant increase in the size of our business. There can be no assurances that we will be successful or that we will realize the expected operating efficiencies, cost savings, revenue enhancements or other benefits currently anticipated from our acquisitions.

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Risks Related to Environmental and Other Regulations

Our results of operations, cash flows and financial position are subject to major trends in our industry, such as decarbonization, and may be adversely affected by future developments that are outside of our control.

The value of the revenues we receive from the use of our land and resources by our customers is substantially based on the level of oil and natural gas drilling and production activities. Our revenues may be negatively affected by changes driven by trends such as decarbonization efforts. Such changes may relate to the types or sources of energy in demand, such as a shift to renewable sources of power generation (for example, wind and solar), along with ongoing changes in regulatory, investor, customer and consumer policies and preferences. While we intend to pursue these additional opportunities, we may ultimately be unsuccessful. The evolution of global energy sources is affected by factors out of our control, such as the pace of technological developments and related cost considerations, the levels of economic growth in different markets around the world and the adoption of climate change-related policies. In addition, the possibility of taxes on carbon emissions can affect the demand for crude oil and natural gas and the operating costs for producers on or around our land.

Legislation or regulatory initiatives intended to address seismic activity, over-pressurization or subsidence could restrict drilling, completion and production activities, as well as WaterBridge’s ability to handle produced water gathered from its customers, which could have a material adverse effect on our results of operations, cash flows and financial position.

WaterBridge handles large volumes of produced water in connection with its customers’ drilling and production operations pursuant to permits issued by governmental authorities overseeing such produced water handling activities. While these permits are issued pursuant to existing laws and regulations, these legal requirements are subject to change, which could result in the imposition of more stringent operating constraints or new monitoring and reporting requirements, owing to, among other things, concerns of the public or governmental authorities regarding such produced water handling activities. For example, there exists a growing concern that the injection of produced water into certain produced water handling facilities triggers seismic activity in certain areas, including Texas, where a majority of our acreage is located. This has led to the creation of operator-led response plans in certain areas in New Mexico or Texas by the NMOCD and the TRRC, respectively, which can include the TRRC suspending or declining to issue produced water handling permits, restrictions on the amount of material that can be handled, or requiring producers to cease disposal in certain produced water handling facilities.

State and federal regulatory agencies have recently focused on a possible connection between hydraulic fracturing related activities, particularly the underground injection of produced water into produced water handling facilities, and the increased occurrence of seismic activity, and regulatory agencies at all levels are continuing to study the possible linkage between oil and natural gas activity and induced seismicity. The U.S. Geological Survey has recently identified Texas and New Mexico as two of six states with the most significant hazards from induced seismicity. In addition, a number of lawsuits have been filed in some states alleging that produced water handling operations have caused seismic events, caused damage to neighboring properties or otherwise violated state and federal rules regulating waste disposal. In response to these concerns, regulators in some states are seeking to impose additional requirements, including requirements regarding produced water handling permits, to assess the relationship between seismicity and the use of such produced water handling facilities. For example, the TRRC has previously published a rule governing permitting or re-permitting of produced water handling facilities that would require, among other things, the submission of information on seismic events occurring within a specified radius of the produced water handling facility location, as well as logs, geologic cross sections and structure maps relating to the water handling area in question. The TRRC has also suspended produced water handling permits and introduced injection volume curtailments within the boundaries of certain Seismic Response Areas (“SRAs”). A significant portion of our acreage in our Northern Position within New Mexico is currently located within SRAs that limit produced water injection into deep formations, which currently only affects one produced water handling facility on our land. There can be no assurance that additional portions of our acreage will not be included in an SRA in the future. Separately, in November 2021, the NMOCD implemented protocols requiring producers to take various actions within a specified proximity of certain seismic activity, including a requirement to limit injection rates if a seismic event of a certain magnitude occurs within a specified radius of a produced water handling facility. Further, on July 11, 2024, the NMOCD announced the administrative cancellation of 75 pending permit applications for UIC Class II wells within the 10-mile County Line SRA, due to the potential for increased seismicity within the area. The adoption and implementation of any new laws or regulations that restrict our customers’ ability to handle produced water gathered from E&P companies, by limiting volumes, disposal rates, produced water handling facility locations or otherwise, or requiring our customers to shut down produced water handling facilities, could limit existing operations and future development activity in affected areas by our customers, including WaterBridge, and reduce their demand for the use of our land and resources, which could have a material adverse effect on our results of operations, cash flows and financial position.

Additionally, hydraulic fracturing related activities have been linked to subsidence and expansion. Both the injection of produced water into produced water facilities and the extraction of water, oil, natural gas, or mineral resources from the ground can result in surface subsidence and uplifts caused by changes underground (such as, but not limited to, loss of volume and pressure depletion). This has been linked to various geo-and environmental hazards, such as alteration of local ecosystems and impacts upon local

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communities, to include increased seismic activity and the formation of sinkholes. Any new laws or regulations that may be adopted and implemented with respect to addressing subsidence and expansion risks may lead to restrictions upon our customers’ operations, which could materially and adversely affect our results of operations, cash flows and financial position.

Our reliance on revenue generated from produced water handling activities exposes us to potential regulatory risks.

There are unique risks associated with handling produced water, and the legal requirements related to handling produced water into a non-producing geologic formation by means of produced water handling facilities are subject to change based on concerns of the public or governmental authorities. There remains substantial uncertainty regarding the handling of produced water by means of produced water handling facilities, the regulation of which could materially and adversely affect our customers in a manner that cannot be predicted. These include liabilities related to the handling, treatment, storage, disposal, transport, release and use of radioactive materials, which could be in produced water, and uncertainties regarding the ultimate, and potential exposure to, technical and financial risks associated with modifying or decommissioning produced water handling facilities. Federal or state regulatory agencies could require the shutdown of produced water handling facilities for safety reasons or refuse to permit the restart of any facility after unplanned or planned outages. New or amended safety and regulatory requirements may give rise to additional operation and maintenance costs and capital expenditures. Additionally, aging equipment may require more capital expenditures to keep produced water infrastructure operating efficiently or in compliance with applicable laws and regulations. Such equipment is also likely to require periodic upgrading and improvement in order to maintain compliance. Although the safety record of produced water handling generally has been very good, accidents and other unforeseen problems have occurred. The consequences of a major incident could be severe and include loss of life and property damage. Any resulting liability from a major environmental or catastrophic incident could materially and adversely affect our customers and limit their operations on our land.

The Endangered Species Act (“ESA”) and Migratory Bird Treaty Act (“MBTA”) govern our and our customers’ operations and additional restrictions may be imposed in the future, which constraints could have an adverse impact on our ability to expand some of our existing operations or limit our customers’ ability to develop new infrastructure on our land.

The ESA and comparable state laws restrict activities that may affect endangered or threatened species or their habitats. Similar protections are offered to migratory birds under the MBTA. To the degree that species listed under the ESA or similar state laws, or are protected under the MBTA, live in the areas where we and our customers operate, both our and our customers’ abilities to conduct or expand operations and construct facilities could be limited, or both we and our customers could be forced to incur additional material costs. Additionally, the FWS may make determinations on the listing of unlisted species as endangered or threatened under the ESA. For example, in November 2022, the FWS designated two distinct population segments of the lesser prairie chicken under the ESA, which live in certain areas in southeastern New Mexico and western Texas. The listing decision was challenged by the states of Texas, Kansas and Oklahoma, and various industry groups, with the U.S. District Court for the Western District of Texas vacating the rule for the northern district population segment in March 2025. In May 2024, the FWS designated the dunes sagebrush lizard under the ESA, which also lives in certain areas in southeastern New Mexico and western Texas. This listing decision is subject to ongoing litigation. The designation of previously unidentified endangered or threatened species could indirectly cause us or our customers to incur additional costs, cause our or our customers’ operations to become subject to operating restrictions or bans and limit future development activity in affected areas, which developments could have a material adverse effect on our results of operations, cash flows and financial position.

The results of operations of our customers, as well as producers on or around our land, may be materially impacted by efforts to transition to a lower-carbon economy.

Concerns over the risk of climate change have increased the focus by global, regional, national, state and local regulators on GHG emissions, including carbon dioxide emissions, and on transitioning to a lower-carbon future. A number of countries and states have adopted, or are considering the adoption of, regulatory frameworks to reduce GHG emissions. These regulatory measures may include, among others, adoption of cap and trade regimes, carbon taxes, increased efficiency standards, prohibitions on the sales of new automobiles with internal combustion engines, and incentives or mandates for battery-powered automobiles and/or wind, solar or other forms of alternative energy. These include laws such as the IRA, which appropriated significant federal funding for renewable energy initiatives and amended the CAA to impose a first-time fee on the emission of methane from sources required to report their GHG emissions to the EPA. In May 2024, the EPA issued a final rule to implement the IRA’s methane fee, although in February 2025, Congress repealed the rule under the Congressional Review Act. Additionally, in the OBBBA, Congress delayed the implementation of the methane emission fee until 2034. We cannot predict if the Trump Administration and / or Congress may take further actions with respect to the IRA or the methane emissions fee. Compliance with changes in laws, regulations and obligations relating to climate change could result in increased costs of compliance for our customers on or around our land or costs of consuming oil and natural gas for such products, and thereby reduce demand for the use of our land and resources, which could reduce our profitability. Changes in laws and regulations may also result in delays or increased costs associated with obtaining permits needed for oil and natural gas operations. Additionally, our customers on or around our land could incur reputational risk tied to changing customer or community perceptions of our customers or their customers’ contribution to, or detraction from, the transition to a

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lower-carbon economy. These changing perceptions could lower demand for oil and natural gas products, resulting in lower prices and lower revenues as consumers avoid carbon-intensive industries, and could also pressure banks and investment managers to shift investments and reduce lending.

Separately, banks and other financial institutions, including investors, may decide to adopt policies that restrict or prohibit investment in, or otherwise funding, us or our customers on or around our land based on climate change-related concerns, which could affect our and our customers on or around our land’s access to and cost of capital for potential growth projects. However, this trend has been declining recently. Additionally, insurers may decide to raise rates and/or cease insuring us or our customers on or around our land based on climate change-related concerns.

Approaches to climate change and transition to a lower-carbon economy, including government regulation, company policies, and consumer behavior, are continuously evolving. While we intend to pursue opportunities related to the transition to a lower-carbon economy, there can be no assurance that our efforts will be successful. At this time, we cannot predict how such approaches may develop or otherwise reasonably or reliably estimate their impact on us or our customers’ financial condition, results of operations and ability to compete. However, any long-term material adverse effect on the oil and natural gas industry may affect our results of operations, cash flows and financial position.

Climate variability may cause increased volatility in weather and may impact water usage and related revenue.

The issue of climate variability is receiving increasing attention nationally and worldwide. There is consensus among climate scientists that there will be worsening of weather volatility in the future associated with climate variability. Many climate variability predictions present several potential challenges to the energy industry, including brackish water sales and water services related to oil and natural gas production, such as:

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increased frequency and duration of droughts;
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challenges associated with changes in temperature;
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potential degradation of water quality;
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decreases in available water supply and changes in water usage patterns;
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increased frequency and severity of storms and other weather events;
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increases in disruptions in service; or
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increased costs to reduce risks associated with the increasing frequency and severity of natural events, including to improve the resiliency and reliability of the infrastructure and systems necessary for customers’ water services.

Because of the uncertainty of weather volatility related to climate variability, we cannot predict its potential impact on our or our customers’ business, financial condition, results of operations, cash flows and liquidity. This, in turn, could lead to lower demand, rates and utilization for the use of our land and resources, and delays in payment of, or nonpayment of, amounts that are owed to us. Furthermore, laws and regulations have been enacted that seek to reduce or limit GHG emissions and require additional reporting and monitoring, and these regulations may become more pervasive or stringent in light of changing governmental agendas and priorities, although the exact nature and timing of these changes is uncertain. There can be no assurance that we or our customers would be able to recover any expenditures or costs associated with the impact of climate variability and related laws and regulations on a timely basis, or at all.

Increased investor attention to sustainability-related matters may impact our or our customers’ business.

Companies across all industries are facing increasing scrutiny from stakeholders related to their sustainability practices. Companies that do not adapt to or comply with investor or stakeholder expectations and standards, which are evolving, or which are perceived to have not responded appropriately to sustainability issues, regardless of whether there is a legal requirement to do so, may suffer from reputational damage and the business, financial condition, and/or stock price of such a company could be materially and adversely affected. Increased attention to climate change, increasing and sometimes conflicting societal expectations on companies to address climate change, and potential consumer use of substitutes to energy commodities may result in increased costs, reduced demand for our customers’ products and services, lower demand for the use of our land and resources, reduced profits, increased governmental investigations and litigation against us.

Moreover, certain institutional investors have announced plans to transition their portfolios to net-zero GHG emissions over the next two to three decades as part of a commitment to combat climate change. This has, and will likely continue to result in some (and

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perhaps a growing number of) institutions removing from their portfolios the shares of companies that do not meet their minimum investment standards. Further, in some cases, banks and other capital providers are reassessing their capital allocation to our or our customers’ industries or making their participation uncertain. Any divestment or limitation of future investment in companies involved in the development, production, transportation and utilization of fossil fuels may adversely affect the price of our shares and limit our access to the debt and equity markets for capital to fund our growth.

Moreover, while we may create and publish voluntary disclosures regarding sustainability matters from time to time, many of the statements in those voluntary disclosures are based on expectations and assumptions or hypothetical scenarios that may be incorrect or may change with the passage of time. Such expectations and assumptions or hypothetical scenarios are necessarily uncertain and may be prone to error or subject to misinterpretation given the long timelines involved and the lack of an established approach to identifying, measuring and reporting on many sustainability matters. Additionally, voluntary disclosures regarding sustainability matters, as well as any sustainability disclosures mandated by law, could result in litigation or government investigations or enforcement action regarding the sufficiency or validity of such disclosures. In addition, failure or a perception (whether or not valid) of failure to adequately pursue or implement sustainability strategies or achieve sustainability goals or commitments, which are often aspirational, including any GHG reduction or neutralization goals or commitments, could result in litigation and damage our reputation, cause our investors or consumers to lose confidence in us, or otherwise negatively impact our operations. Moreover, even if we voluntarily elect to pursue climate or sustainability goals, we cannot guarantee that we will be able to pursue or implement such goals because of potential costs, technical or operational obstacles, uncertainty in long-term assumptions and expectations or other market or technological developments beyond our control. Similarly, we cannot guarantee that participation in any sustainability or, climate-related certification program or framework will have the intended results on our sustainability profile.

In addition, certain organizations that provide proxy advisory services to investors on corporate governance and related matters have developed rating and proxy voting recommendation processes for evaluating companies on their approach to sustainability matters. Such ratings and proxy advisory services are used by some investors to inform their investment and voting decisions. Additionally, certain investors use these scores to benchmark companies against their peers and if a company is perceived as lagging, these investors may engage with companies to require improved sustainability disclosure or performance. While such ratings do not impact all investors’ investment or voting decisions, unfavorable sustainability ratings may lead to increased negative investor sentiment toward us or our customers and to the diversion of investment to other industries, which could have a negative impact on our share price and/or our access to and costs of capital.

Furthermore, certain public statements with respect to sustainability matters, such as emissions reduction goals, other environmental targets, or other commitments addressing certain social issues, are becoming increasingly subject to heightened scrutiny from public and governmental authorities related to the risk of potential “greenwashing” (i.e., misleading information or false claims overstating potential sustainability benefits). For example, the SEC has taken enforcement action against companies for sustainability-related misconduct, including alleged greenwashing. Certain regulators, such as the SEC and various state agencies, as well as non-governmental organizations and other private actors have also filed lawsuits under various securities and consumer protection laws alleging that certain sustainability-statements, goals, or standards were misleading, false, or otherwise deceptive. Any alleged claims of greenwashing against us or others in our industry may lead to further negative sentiment and diversion of investments. We could also face increasing costs as we attempt to comply with and navigate further regulatory sustainability-related focus and scrutiny.

Additionally, certain employment practices and social initiatives are the subject of scrutiny by both those calling for the continued advancement of such policies, as well as those who believe they should be curbed, including government actors, and the complex regulatory and legal frameworks applicable to such initiatives continue to evolve. We cannot be certain of the impact of such regulatory, legal and other developments on our business. More recent political developments could mean that the Company faces increasing criticism or litigation risks from certain “anti-sustainability” parties, including various governmental agencies.

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Our customers’ operations on our land may be exposed to significant delays, costs and liabilities as a result of environmental, health and safety requirements, and we may be subject to strict, as well as joint and several liability, for contamination resulting from such operations pursuant to such requirements, even if we do not have control over such operations. The occurrence of any such delays, costs and liabilities may materially and adversely affect our customers’ business, operations or financial condition, which could reduce the demand for the use of our land and its resources, as well as the royalties and other payments we receive therefrom, and thereby materially affect our results of operations, cash flows and financial position.

E&P activities, sand mining, produced water handling, oilfield reclamation, solid waste facilities, landfills and other operations on our land are subject to numerous environmental, health and safety requirements. Our customers may incur significant delays, costs and liabilities as a result of federal, state and local environmental, health and safety requirements applicable to their activities on our land. These laws and regulations may require our customers to obtain and maintain a variety of permits, approvals, certificates or other authorizations that govern air emissions, water discharges, waste disposal or other environmental impacts associated with drilling, production and transporting oil and natural gas or other operations; regulate the sourcing and disposal of water used in the drilling, fracturing and completion processes; limit or prohibit drilling activities in certain areas and on certain lands lying within wilderness, wetlands, frontier, seismically active areas and other protected areas; require remedial action to prevent or mitigate pollution from former operations such as plugging abandoned wells or closing earthen pits; and/or impose substantial liabilities for spills, pollution or failure to comply with regulatory filings. In addition, these laws and regulations may restrict the rate of oil or natural gas production. These laws and regulations are complex, change frequently and have tended to become increasingly stringent over time. Failure to comply with these laws and regulations may result in the assessment of administrative, civil and criminal penalties, imposition of cleanup and site restoration costs and liens, the suspension or revocation of necessary permits, licenses and authorizations, the requirement that additional pollution controls be installed, and, in some instances, the issuance of orders or injunctions limiting or requiring discontinuation of certain operations, in each case, which could materially and adversely affect our customers’ operations on our land. Additionally, any failure to comply could result in negative sentiment toward our customers’ business and others in the industry.

Moreover, under certain environmental laws that impose strict as well as joint and several liability, we may be required to remediate contaminated properties owned by us even if a customer’s operations caused the contamination. In addition, our customers may be liable for the remediation of contamination at currently or formerly operated facilities and facilities of third parties that received waste generated by our customers’ operations, regardless of whether such contamination resulted from the conduct of others or from consequences of actions that were in compliance with all applicable environmental laws at the time those actions were taken. In addition, claims for damages to persons or property, including natural resources, may result from the environmental, health and safety impacts of the operations of our customers. While we seek to mitigate any potential liability we may have through indemnification, customary insurance policies and remediation activities, in each case, required under our contracts, as well as reliance on state funded programs (such as the TRRC’s Orphan Well Program) for coverage of plugging and abandonment liabilities if any of our customers declared bankruptcy or if our insurance policies did not fully cover such liabilities, we may not be fully protected. Additionally, although we generally have rights to inspect our property and the operations thereon, we may not become aware of all environmental, health and safety matters. Moreover, public interest in the protection of the environment has tended to increase over time. The trend of more expansive and stringent environmental legislation and regulations applied to extractive industries such as those our customers engage in could continue resulting in increased costs of doing business and consequently affecting profitability. To the extent laws are enacted or other governmental actions are taken that restrict drilling or impose more stringent and costly operating, waste handling, disposal and cleanup requirements, our customers’ operations could face increased costs and potential curtailment of operations, which consequently could indirectly materially and adversely affect our business, cash flows, prospects, financial condition or results of operations.

Risks Related to Our Financial Condition

We may be unable to generate sufficient cash to service all of our indebtedness and financial commitments and any future indebtedness could adversely affect our financial condition.

As of December 31, 2025, we had $570.7 million of total debt outstanding. Our ability to make scheduled payments on, or to refinance, our indebtedness and financial commitments depends on our financial condition and operating performance, which are subject to prevailing economic and competitive conditions including financial, business and other factors beyond our control, and may vary significantly from year to year. As a result, the amount of debt that we can manage in some periods may not be appropriate for us in other periods and we may be unable to generate sufficient cash flow to permit us to pay the principal, premium, if any, and interest on our indebtedness. Any insufficiency may impact our business.

If our cash flows and capital resources are insufficient to fund debt and other obligations, we may be forced to reduce or delay capital expenditures, sell assets, seek to raise additional capital or refinance or restructure our indebtedness. Our ability to restructure or refinance indebtedness will depend on the condition of the capital markets and our financial condition at such time. Any refinancing of indebtedness could be on unfavorable terms, including at higher interest rates, and may require us to comply with more restrictive

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covenants. The terms of our existing or future debt instruments may restrict us from adopting some of these alternatives. We cannot assure you that any refinancing or restructuring would be possible, that any assets, including land, could be sold or that, if sold, the timing of the sales and the amount of proceeds realized from those sales would be favorable to us or that additional financing could be obtained on favorable terms, if at all. In addition, any failure to service our debt, including paying interest or principal on a timely basis, would likely result in a reduction of our credit rating, if any, which could harm our ability to incur additional indebtedness. In addition, if we fail to comply with the covenants or other terms of any agreements governing our debt, our lenders will have the right to accelerate the maturity of that debt and foreclose upon the collateral, if any, securing that debt.

Our indebtedness could have important consequences for you and significant effects on our business, including:

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increasing our vulnerability to adverse changes in general economic, industry and competitive conditions and limiting our ability to address such changes;
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requiring us to dedicate a substantial portion of our cash flow from operations to make payments on our indebtedness, thereby reducing the availability of our cash flow to fund general company and other purposes, including dividend payments;
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restricting us from exploiting business opportunities and making strategic land acquisitions;
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making it more difficult to satisfy our financial obligations, including payments on our indebtedness, and contractual and commercial commitments;
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disadvantaging us when compared to our competitors that have less debt;
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complying with covenants contained in the documents governing such indebtedness may require us to meet or maintain certain financial tests, which may affect our flexibility in planning for, and reacting to, changes in our industry, such as being able to take advantage of acquisition opportunities when they arise; and
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increasing our borrowing costs or otherwise limiting our ability to borrow additional funds for the execution of our business strategy.

Finally, the agreements governing our outstanding indebtedness limit our ability to incur additional debt, but such agreements do not prohibit us from doing so. As a result, we could incur more indebtedness in the future, which would exacerbate the foregoing risks.

We are subject to interest rate risk, which may cause our debt service obligations to increase significantly. The weighted average interest rate on borrowings outstanding under the 2025 Revolving Credit Facility as of December 31, 2025 was 6.13%.

Borrowings under the 2025 Revolving Credit Facility bear interest at variable rates and expose us to interest rate risk. The weighted average interest rate on our borrowings outstanding under the 2025 Revolving Credit Facility as of December 31, 2025 was 6.13%. If interest rates increase, our debt service obligations on the variable rate indebtedness would increase even if the amount borrowed remained the same, and we would be required to devote more of our cash flow to servicing our indebtedness.

In March 2022, the Federal Reserve began, and continued through 2023, to raise interest rates in an effort to curb inflation. Although the Federal Reserve made cuts to benchmark interest rates, to the extent such rates remain elevated or are increased as a result of inflationary pressures or otherwise, we may continue to experience further financing cost increases if interest rates on borrowings, credit facilities and debt offerings increase, as compared to previous levels. Changes in interest rates, either positive or negative, may also affect the yield requirements of investors who invest in our Class A shares, and the elevated interest rate environment could have an adverse impact on the price of our Class A shares, or our ability to issue equity or incur debt for acquisitions or other purposes.

Changes to applicable tax laws and regulations, exposure to additional income tax liabilities, changes in our effective tax rates or an assessment of taxes resulting from an examination of our income or other tax returns could adversely affect our results of operations, cash flows and financial position, including our ability to repay our debt.

We are subject to various complex and evolving U.S. federal, state and local taxes. U.S. federal, state and local tax laws, policies, statutes, rules, regulations or ordinances could be interpreted, changed, modified or applied adversely to us, in each case, possibly with retroactive effect, and may have an adverse effect on our results of operations, cash flows and financial position, including our ability to repay our debt. The passage of any tax legislation or similar changes in U.S. federal income tax laws could adversely affect our results of operations, cash flows and financial position.

Changes in our effective tax rates or tax liabilities could also adversely affect our results of operations, cash flows and financial position. Our future effective tax rates could be subject to volatility or adversely affected by a number of factors, including:

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changes in the valuation of our deferred tax assets and liabilities;
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expected timing and amount of the release of any tax valuation allowances;
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expansion into future activities in new jurisdictions;
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the availability of tax deductions, credits, exemptions, refunds and other benefits to reduce tax liabilities; and
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tax effects of share-based compensation.

In addition, an adverse outcome arising from an examination of our income or other tax returns could result in higher tax exposure, penalties, interest or other liabilities that could have an adverse effect on our results of operations, cash flows and financial position.

If we fail to comply with the restrictions and covenants in the 2025 Revolving Credit Facility, the Indenture or our future debt agreements, there could be an event of default under the terms of such agreements, which could result in an acceleration of payment.

A breach of compliance with any restriction or covenant in the 2025 Revolving Credit Facility, the Indenture or any of our future debt agreements could result in a default under the terms of the applicable agreement, and our ability to comply with such restrictions and covenants may be affected by events beyond our control. As a result, we cannot assure you that we will be able to comply with these restrictions and covenants. A default could result in acceleration of the indebtedness and a declaration of all amounts borrowed due and payable, which could have an adverse effect on us and negatively impact our ability to borrow. If an acceleration occurs, we may be unable to make all of the required payments and may be unable to find alternative financing. Even if alternative financing were available at that time, it may not be on terms that are favorable or acceptable to us. Additionally, we may not be able to amend the 2025 Revolving Credit Facility or such future agreements governing our indebtedness or obtain necessary waivers on satisfactory terms.

Our obligations under the 2025 Revolving Credit Facility are secured by a first priority security interest in substantially all of our assets and various guarantees.

The amounts borrowed pursuant to the terms of the 2025 Revolving Credit Facility are secured by substantially all of our and our subsidiaries’ present and after-acquired assets. Additionally, our obligations under the 2025 Revolving Credit Facility are jointly and severally guaranteed by us and our material subsidiaries.

As a result of the above, in the event of the occurrence of a default under the 2025 Revolving Credit Facility, the administrative agent may enforce its security interests (for the ratable benefit of the lenders under the 2025 Revolving Credit Facility and the other secured parties) over our and/or our subsidiaries’ assets that secure the obligations under the 2025 Revolving Credit Facility, take control of our assets and business, force us to seek bankruptcy protection, or force us to curtail or abandon our current business plans. If that were to happen, you may lose all, or a part of, your investment in our Class A shares.

We do not currently have in place hedging agreements with respect to oil and natural gas production from our acreage, and we will be exposed to the impact of decreases in the price of oil and natural gas.

We do not currently have in place hedging arrangements to establish, in advance, a price for the sale of the oil and natural gas produced from our acreage. As a result, although we may realize the benefit of any short-term increase in the price of oil and natural gas, we will not be protected against decreases in the price or prolonged periods of low oil and natural prices, which, in combination with all of our acreage being located solely in the Permian Basin, could materially and adversely affect our results of operations, cash flows and financial position. Any future price hedging strategy and future hedging transactions will be determined at our discretion. If we enter into hedging arrangements in the future, it may limit our ability to realize the benefit of rising prices and may result in hedging losses.

Risks Related to Our Corporate Structure and Our Class A Shares

Maintaining the requirements of being a public company, including compliance with the reporting requirements of the Exchange Act, and the requirements of the Sarbanes-Oxley Act, will increase demands on our resources, increase our costs and divert management’s attention, and we may be unable to comply with these requirements in a timely or cost-effective manner.

As a public company, we must comply with new laws, regulations and requirements, certain corporate governance provisions of the Sarbanes-Oxley Act, related regulations of the SEC and the NYSE and NYSE Texas rules. Complying with these statutes, regulations and requirements occupy a significant amount of time of our board of directors and management and significantly increase our costs and expenses. We are continuing our efforts to:

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institute a more comprehensive compliance function;
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comply with rules promulgated by the NYSE and NYSE Texas;
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continue to prepare and distribute periodic public reports in compliance with our obligations under the federal securities laws;
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institute and enforce new internal policies, such as those relating to insider trading; and
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involve and retain to a greater degree outside counsel and accountants in the above activities.

We are required to comply with the SEC’s rules implementing Sections 302 and 404 of the Sarbanes-Oxley Act, which require management to certify financial and other information in our quarterly and annual reports and provide an annual management report on the effectiveness of internal controls over financial reporting. As of December 31, 2025, we are no longer an “emerging growth company,” as defined in the JOBS Act. As such, our independent registered public accounting firm is required to attest to the effectiveness of our internal control over financial reporting and we are required to disclose, to the extent material, changes made in our internal control over financial reporting on a quarterly basis. Our independent registered public accounting firm may issue a report that is adverse in the event it is not satisfied with the level at which our controls are documented, designed, operated or reviewed. Compliance with these requirements will increase demands on our resources, increase our costs and distract management, and we may be unable to comply with these requirements in a timely or cost-effective manner.

In addition, being a public company subject to these rules and regulations has increased our director and officer liability insurance expenses and we may be required to accept reduced policy limits and coverage or incur substantially higher costs to obtain the same or similar coverage in the future. As a result, it may be more difficult for us to attract and retain qualified individuals to serve on our board of directors or as executive officers. We cannot predict or estimate the amount of additional costs we may incur or the timing of such costs.

If we experience any material weaknesses in the future or otherwise fail to develop or maintain an effective system of internal controls in the future, we may not be able to accurately report our financial condition or results of operations, which may adversely affect investor confidence in us and, as a result, the value of our Class A shares.

Effective internal controls are necessary for us to provide reliable financial reports, prevent fraud and operate successfully as a public company. If we cannot provide reliable financial reports or prevent fraud, our reputation and operating results will be harmed. We are required, under Section 404 of the Sarbanes-Oxley Act, to furnish a report by management on, among other things, the effectiveness of our internal control over financial reporting. This assessment will need to include disclosure of any material weaknesses identified by our management in our internal control over financial reporting. We will take steps to improve control processes as appropriate, validate through testing that controls are functioning as documented, and implement a continuous reporting and improvement process for our internal control over financial reporting. If we identify one or more material weaknesses in our internal control over financial reporting during the evaluation and testing process, we may be unable to conclude that our internal controls are effective.

If we are unable to confirm that our internal control over financial reporting is effective, or if our independent registered public accounting firm is unable to express an unqualified opinion on the effectiveness of our internal controls, we could lose investor confidence in the accuracy and completeness of our financial reports, which could cause the price of our Class A shares to decline.

Our ability to continue to pay dividends to our shareholders may be limited by our holding company structure, contractual restrictions and regulatory requirements.

We are a holding company and will have no material assets other than our equity interest in OpCo, and we do not have any independent means of generating revenue. To the extent OpCo has available cash we intend to cause OpCo to make (i) generally pro rata distributions to all holders (“OpCo Unitholders”) of limited liability interests in OpCo (“OpCo Units”), including us, in an amount at least sufficient to allow us to pay taxes, (ii) additional distributions in an amount generally intended to allow the OpCo Unitholders (other than us) to satisfy their respective income tax liabilities with respect to their allocable share of the income of OpCo (based on certain assumptions and conventions), which additional distributions may be made on a pro rata basis to all OpCo Unitholders (including us) or a non-pro rata basis to OpCo Unitholders (other than us) in redemption of OpCo Units from such holders and (iii) non-pro rata distributions to us in an amount sufficient to cover our public company and other overhead expenses. In addition, as the sole managing member of OpCo, we intend to cause OpCo to make pro rata distributions to all of its unitholders, including to us, in an amount sufficient to allow us to fund dividends to our shareholders in accordance with our dividend policy, to the extent our board of directors declares such dividends. OpCo is a distinct legal entity and may be subject to legal or contractual restrictions that, under certain circumstances, may limit our ability to obtain cash from it. If OpCo is unable to make distributions, we may not receive adequate distributions, which could materially and adversely affect our results of operations, cash flows, financial position and ability to fund any dividends.

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Although we intend to continue to pay dividends on our Class A shares, we are not obligated to do so. We have not adopted a formal written dividend policy nor have we adopted a dividend policy to pay a fixed amount of cash each quarter in respect of each Class A share or to pay an amount based on the achievement of, or derivable based on, any specific financial metrics such as Free Cash Flow. Dividend payments are not guaranteed and are within the absolute discretion of our board of directors. Our board of directors will take into account general economic and business conditions, our financial condition and results of operations, our cash flows from operations and current and anticipated cash needs, our capital requirements, legal, tax, regulatory and contractual restrictions, and implications of such other factors as our board of directors may deem relevant in determining whether, and in what amounts, to pay such dividends. In addition, our debt agreements may limit the amount of distributions that OpCo’s subsidiaries can make to OpCo and OpCo can make to us and the purposes for which distributions could be made. Any return on investment in our Class A shares may be solely dependent upon the appreciation of the price of our Class A shares on the open market, which may not continue to occur. Please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Debt Instruments” for further discussion of our debt agreements. Accordingly, we may not be able to pay dividends even if our board of directors would otherwise deem it appropriate. Please see “Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities—Dividends” and “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources.”

LandBridge Holdings has the ability to direct the voting of a majority of our common shares and control certain decisions with respect to our management and business, including certain consent rights and the right to designate more than a majority of the members of our board of directors as long as it and its affiliates beneficially own at least 40% of our outstanding common shares, as well as lesser director designation rights as long as it and its affiliates beneficially own less than 40% but at least 10% of our outstanding common shares. LandBridge Holdings’ interests may conflict with those of our other shareholders.

As of December 31, 2025, LandBridge Holdings owned an aggregate of 48,593,505 Class B shares representing approximately 63.04% of our voting power. LandBridge Holdings’ beneficial ownership of greater than 50% of our common shares means LandBridge Holdings is able to control matters requiring shareholder approval, including the election of directors, changes to our organizational documents, approval of acquisition offers and other significant corporate transactions. This concentration of ownership makes it unlikely that any other holder or group of holders of our Class A shares will be able to affect the way we are managed or the direction of our business. The interests of LandBridge Holdings with respect to matters potentially or actually involving or affecting us, such as future acquisitions, financings and other corporate opportunities and attempts to acquire us, may conflict with the interests of our other shareholders.

Furthermore, in connection with the consummation of the IPO, we entered into a shareholder’s agreement, dated July 1, 2024 (the “Shareholder’s Agreement”), with LandBridge Holdings, providing that, for so long as LandBridge Holdings and certain affiliates beneficially own at least 40% of our outstanding common shares, LandBridge Holdings shall be entitled to designate a number of directors equal to a majority of the board of directors, plus one director; and for so long as LandBridge Holdings and such affiliates beneficially own at least 30%, 20% and 10% of our outstanding common shares, LandBridge Holdings shall be entitled to designate at least three directors, two directors and one director, respectively. So long as LandBridge Holdings is entitled to designate one or more directors and notifies the board of directors of its desire to remove, with or without cause, any director previously designated by it to the board of directors, we are required to take all necessary action to cause such removal. So long as LandBridge Holdings has the right to designate at least one director to our board of directors, it will also have the right to appoint a number of board observers, who will be entitled to attend all meetings of the board of directors in a non-voting, observer capacity, equal to the number of directors LandBridge Holdings is entitled to appoint.

In addition, under our First Amended and Restated Limited Liability Company Agreement (the “Operating Agreement”), for so long as LandBridge Holdings and certain affiliates beneficially own at least 40% of our outstanding common shares, we have agreed not to take, and will take all necessary action to cause our subsidiaries not to take, the following direct or indirect actions (or enter into an agreement to take such actions) without the prior consent of LandBridge Holdings:

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increasing or decreasing the size of our board of directors, committees of our board of directors or boards and committees of our subsidiaries;
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terminating our chief executive officer or removing the Chairman of our board of directors and/or hiring or appointing either of their successors;
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agreeing to or entering into any transaction that would result in a change of control of the Company or enter into definitive agreements with respect to a change of control transaction;
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incurring debt for borrowed money (or liens securing such debt) in an amount that would result in outstanding debt that exceeds our Adjusted EBITDA for the four quarter period immediately prior to the proposed date of the incurrence of such debt by 4.00 to 1.00;

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authorizing, creating (by way of reclassification, merger, consolidation or otherwise) or issuing any equity securities of any kind (other than pursuant to any equity compensation plan approved by our board of directors or a committee of our board of directors or intra-company issuances among the Company and our subsidiaries);
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making any voluntary election to liquidate or dissolve or commence bankruptcy or insolvency proceedings or the adoption of a plan with respect to any of the foregoing or any determination not to oppose such an action or proceeding commenced by a third party; and
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selling, transferring or disposing of assets outside the ordinary course of business in a transaction or series of transactions with a fair market value in excess of 2% of our Consolidated Net Tangible Assets (as defined in the Operating Agreement) determined as of the end of the most recently completed fiscal quarter or year, as applicable, immediately prior to the proposed date of the consummation of such transaction or such series of transactions.

Additionally, for so long as LandBridge Holdings and certain affiliates beneficially own at least 10% of our outstanding common shares, we and our subsidiaries may not, without the approval of LandBridge Holdings, make any amendment, modification or waiver of our Operating Agreement or any other of our governing documents that materially and adversely affects LandBridge Holdings.

The existence of LandBridge Holdings as a significant shareholder may have the effect of deterring hostile takeovers, delaying or preventing changes in control or changes in management, or limiting the ability of our other shareholders to approve transactions that they may deem to be in the best interests of our company. Moreover, LandBridge Holdings’ concentration of share ownership may adversely affect the trading price of our Class A shares to the extent investors perceive a disadvantage in owning shares of a company with a significant shareholder.

In addition, LandBridge Holdings may have different tax positions from us that could influence its decisions regarding whether and when to support the disposition of assets and the incurrence or refinancing of new or existing indebtedness. In addition, the determination of future tax reporting positions, the structuring of future transactions and the handling of any challenge by any taxing authority to our tax reporting positions may take into consideration LandBridge Holdings’ tax or other considerations, which may differ from the considerations of our other shareholders.

LandBridge Holdings, Five Point and WaterBridge, as well as their affiliates, are not limited in their ability to compete with us, and may benefit from opportunities that might otherwise be available to us.

Our Operating Agreement provides that our officers and directors and their respective affiliates and LandBridge Holdings, Five Point and WaterBridge, as well as their officers, directors and affiliates (each an “Unrestricted Party”), are not restricted from owning assets or prohibited from engaging in other businesses or activities, including those that might be in direct competition with us, and that we renounce any interest or expectancy in any business opportunity that may from time to time be presented to them that would otherwise be subject to a corporate opportunity or other analogous doctrine under Delaware General Corporation Law (the “DGCL”). In addition, the Unrestricted Parties may compete with us for investment opportunities and may own an interest in entities that compete with us. In particular, our Operating Agreement, subject to the limitations of applicable law, provides, among other things, that (i) the Unrestricted Parties may conduct business that competes with us and may make investments in any kind of property in which we may make investments, and (ii) if any of the Unrestricted Parties acquire knowledge of a potential business opportunity, transaction or other matter, they have no duty, to the fullest extent permitted by law, to communicate such offer to us, our shareholders or our affiliates.

We may refer any conflicts of interest or potential conflicts of interest involving any of the Unrestricted Parties to a conflicts committee, which must consist entirely of independent directors, for resolution. Additionally, our board of directors adopted a written related party transactions policy relating to the approval of related party transactions, pursuant to which any such transactions, including transactions with the Unrestricted Parties, will be reviewed and approved or ratified by our Audit Committee or such conflicts committee or pursuant to the procedures outlined in such policy.

LandBridge Holdings may become aware, from time to time, of certain business opportunities (such as acquisition opportunities) and may direct such opportunities to other businesses in which they have invested, in which case we may not become aware of or otherwise have the ability to pursue such opportunities. Furthermore, such businesses may choose to compete with us for these opportunities, possibly causing these opportunities to not be available to us or causing them to be more expensive for us to pursue. Furthermore, LandBridge Holdings, Five Point and WaterBridge, are not required to utilize facilities located on our land in connection with any business opportunities, whether currently existing or arising in the future, and may pursue development opportunities with competing landowners, or pursue an alternative land position without informing us of such opportunity or offering such opportunity to us. This renouncing of our interest and expectancy in any business opportunity may create actual and potential conflicts of interest between us and LandBridge Holdings, Five Point and WaterBridge, and result in less than favorable treatment of us and our

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shareholders if attractive business opportunities are pursued by LandBridge Holdings, Five Point and WaterBridge, for their own benefit rather than for ours.

Certain of our directors and officers may have significant duties with, and spend significant time serving, other entities, including entities that may compete with us in seeking acquisitions and business opportunities, and, accordingly, may have conflicts of interest in allocating time or pursuing business opportunities.

Certain of our directors and officers, who are responsible for managing our business may hold positions of responsibility with other entities, including those that are in the energy industry. The existing and potential positions held by these directors and officers may give rise to fiduciary or other duties that are in conflict with the duties they owe to us and may also otherwise require attention and time that could otherwise be devoted to our business. These directors and officers may become aware of business opportunities that may be appropriate for presentation to us as well as to the other entities with which they are or may become affiliated. Due to these existing and potential future affiliations, such directors and officers may present potential business opportunities to other entities prior to presenting them to us, which could cause additional conflicts of interest. They may also decide that certain opportunities are more appropriate for other entities with which they are affiliated, and, as a result, they may elect not to present those opportunities to us. These conflicts may not be resolved in our or your best interests.

A significant reduction by LandBridge Holdings of its ownership interests in us could adversely affect us.

We believe that LandBridge Holdings’ ownership interest in us provides it with an economic incentive to assist us to be successful. LandBridge Holdings is not subject to any obligation to maintain its ownership interest in us and may elect at any time to sell all or a substantial portion of or otherwise reduce its ownership interest in us. If LandBridge Holdings sells all or a substantial portion of its ownership interests in us, it may have less incentive to assist in our success and its affiliate(s) that are expected to serve as members of our board of directors may resign. Such actions could adversely affect our ability to successfully implement our business strategies, which could adversely affect our results of operations, cash flows and financial position.

The U.S. federal income tax treatment of dividends on our Class A shares to a holder will depend upon our tax attributes and the holder’s tax basis in our common shares, which are not necessarily predictable and can change over time, and could cause taxable gain or loss on the sale of our Class A shares to be more or less than expected.

Amounts we distribute to our shareholders with respect to our Class A shares, which we refer to as “dividends,” will constitute “dividends” for U.S. federal income tax purposes to the extent paid from our current or accumulated earnings and profits, as determined under U.S. federal income tax principles. To the extent such distribution amounts exceed our current and accumulated earnings and profits, such distributed amount will be treated as a non-taxable return of capital to the extent of a holder’s tax basis in our Class A shares and thereafter as capital gain from the sale or exchange of such shares.

If a holder sells its Class A shares, the holder will recognize a gain or loss equal to the difference between the amount realized and the holder’s tax basis in such Class A shares. To the extent that the amount of our dividends is treated as a non-taxable return of capital as described above, such dividends will reduce a holder’s tax basis in the Class A shares. Consequently, such excess dividends will result in a corresponding increase in the amount of gain, or a corresponding decrease in the amount of loss, recognized by the holder upon the sale of the Class A shares or subsequent dividends with respect to such shares. Additionally, with regard to U.S. corporate holders of our Class A shares, to the extent that a dividend on our Class A shares exceeds both our current and accumulated earnings and profits and such holder’s tax basis in such shares, such holders would be unable to utilize the corporate dividends-received deduction (to the extent it would otherwise be applicable to such holder) with respect to the gain resulting from such excess dividend.

Prospective investors in our Class A shares are encouraged to consult their tax advisors regarding the tax consequences of receiving dividends on our Class A shares that are not treated as dividends for U.S. federal income tax purposes.

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The Internal Revenue Service (“IRS”) Forms 1099-DIV that our shareholders receive from their brokers may over-report dividend income with respect to our Class A shares for U.S. federal income tax purposes, and failure to report dividend income in a manner consistent with the IRS Forms 1099-DIV may cause the IRS to assert audit adjustments to a shareholder’s U.S. federal income tax return. For non-U.S. holders of our Class A shares, brokers or other withholding agents may overwithhold taxes from dividends paid, in which case a shareholder generally would have to timely file a U.S. tax return or an appropriate claim for refund in order to claim a refund of the overwithheld taxes.

Dividends we pay with respect to our Class A shares will constitute “dividends” for U.S. federal income tax purposes only to the extent of our current and accumulated earnings and profits. Dividends we pay in excess of our earnings and profits will not be treated as “dividends” for U.S. federal income tax purposes; instead, they will be treated first as a tax-free return of capital to the extent of a shareholder’s tax basis in their Class A shares and then as capital gain realized on the sale or exchange of such shares. We may be unable to timely determine the portion of our dividends that is a “dividend” for U.S. federal income tax purposes.

For a U.S. holder of our Class A shares, the IRS Forms 1099-DIV may not be consistent with our determination of the amount that constitutes a “dividend” for U.S. federal income tax purposes or a shareholder may receive a corrected IRS Form 1099-DIV (and may therefore need to file an amended federal, state or local income tax return). We will attempt to timely notify our shareholders of available information to assist with income tax reporting (such as posting the correct information on our website). However, the information that we provide to our shareholders may be inconsistent with the amounts reported by a broker on IRS Form 1099-DIV, and the IRS may disagree with any such information and may make audit adjustments to a shareholder’s tax return.

For a non-U.S. holder of our Class A shares, “dividends” for U.S. federal income tax purposes will be subject to withholding of U.S. federal income tax at a 30% rate unless an applicable income tax treaty provides for a lower rate or the dividends are effectively connected with conduct of a U.S. trade or business. In the event that we are unable to timely determine the portion of our dividends that is a “dividend” for U.S. federal income tax purposes, or a shareholder’s broker or withholding agent chooses to withhold taxes from dividends in a manner inconsistent with our determination of the amount that constitutes a “dividend” for such purposes, a shareholder’s broker or other withholding agent may overwithhold taxes from dividends paid. In such a case, a shareholder generally would have to timely file a U.S. tax return or an appropriate claim for refund in order to obtain a refund of the overwithheld tax.

If securities or industry analysts do not publish research or reports about our business, if they adversely change their recommendations regarding our Class A shares or if our operating results do not meet their expectations, our share price could decline.

The trading market for our Class A shares is influenced by the research and reports that industry or securities analysts publish about us or our business. If one or more of these analysts cease coverage of us or fail to publish reports on us regularly, we could lose visibility in the financial markets, which in turn could cause our share price or trading volume to decline. Moreover, if one or more of the analysts who cover us downgrades our Class A shares or if our operating results do not meet their expectations, our Class A share price could decline.

The market price of our Class A shares could be adversely affected by sales of substantial amounts of our Class A shares in the public or private markets or the perception in the public markets that these sales may occur, including sales by LandBridge Holdings after the exercise of the Redemption Right.

As of December 31, 2025, we had 27,838,199 Class A shares and 49,250,916 Class B shares outstanding. Future sales by LandBridge Holdings after the exercise of the Redemption Right (as described in the OpCo LLC Agreement) or sales by other large holders of our Class A shares in the public markets, or the perception that such sales might occur, could have a material adverse effect on the price of our Class A shares or could impair our ability to obtain capital through an offering of equity securities. In addition, we have agreed to provide registration rights to LandBridge Holdings and certain other shareholders. In July 2025, we registered the resale of 53,915,691 Class A shares (including Class A shares to be issued upon redemption of a corresponding number of Class B shares) by certain selling shareholders, including LandBridge Holdings, pursuant to certain registration rights agreements. Furthermore, we filed a registration statement with the SEC on Form S-8 providing for the registration of 3,960,000 Class A shares issued or reserved for issuance under the LandBridge Company LLC Long Term Incentive Plan. Subject to the satisfaction of vesting conditions, the expiration of lock-up agreements and the requirements of Rule 144 under the Securities Act, shares registered under the registration statement on Form S-8 have been made available for resale immediately in the public market without restriction. Alternatively, we may be required to undertake a future public or private offering of Class A shares and use the net proceeds from such offering to purchase an equal number of OpCo Units, with the cancellation of a corresponding number of Class B shares, from LandBridge Holdings.

We may sell additional Class A shares in future offerings. Sales of substantial amounts of our Class A shares (including shares issued in connection with an acquisition), or the perception that such sales could occur, may adversely affect prevailing market prices of our Class A shares.

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We cannot predict the size of future issuances of our Class A shares or securities convertible into Class A shares or the effect, if any, that future issuances and sales of our Class A shares will have on the market price of our Class A shares. Sales of substantial amounts of our Class A shares (including shares issued in connection with an acquisition), or the perception that such sales could occur, may adversely affect prevailing market prices of our Class A shares.

LandBridge Holdings has in the past sold substantial amounts of Class A shares into the market, including in connection with underwritten offerings, and may continue to do so in the future. Any such sales could adversely affect the price of our Class A shares.

We are a “controlled company” within the meaning of the NYSE and NYSE Texas rules and, as a result, qualify for and intend to rely on exemptions from certain corporate governance requirements.

LandBridge Holdings holds a majority of the voting power of our common shares. As a result, we are a controlled company within the meaning of the NYSE and NYSE Texas rules. Under the NYSE rules, a company of which more than 50% of the voting power for the election of directors is held by an individual, a group or another company is a controlled company, and under NYSE Texas rules, a company of which more than 50% of the voting power is held by an individual, a group or another company is a controlled company. Under NYSE and NYSE Texas rules, controlled companies may elect not to comply with certain NYSE corporate governance requirements, including the requirements that:

•
a majority of the board of directors consists of independent directors as defined under the rules of the NYSE and NYSE Texas;
•
the nominating and governance committee be composed entirely of independent directors with a written charter addressing the committee’s purpose and responsibilities; and
•
the compensation committee be composed entirely of independent directors with a written charter addressing the committee’s purpose and responsibilities.

These requirements will not apply to us as long as we remain a controlled company. A controlled company does not need its board of directors to have a majority of independent directors or to form independent compensation and nominating and governance committees. We currently utilize all of these exemptions. Accordingly, you may not have the same protections afforded to shareholders of companies that are subject to all of the rules of the NYSE and NYSE Texas.

Our Operating Agreement, as well as Delaware law, contains provisions that could discourage acquisition bids or merger proposals, which may adversely affect the market price of our Class A shares and deprive our investors of the opportunity to receive a premium for their shares.

Our Operating Agreement authorizes our board of directors to issue preferred shares without shareholder approval in one or more series, designate the number of shares constituting any series, and fix the rights, preferences, privileges and restrictions thereof, including dividend rights, voting rights, rights and terms of redemption, redemption prices and liquidation preferences of such series. If our board of directors elects to issue preferred shares, it could be more difficult for a third party to acquire us.

In addition, certain provisions of our Operating Agreement could make it more difficult for a third party to acquire control of us, even if the change of control would be beneficial to our shareholders. Among other things, such provisions of our Operating Agreement include:

•
providing that after LandBridge Holdings and certain of its affiliates no longer beneficially own or control the voting of more than 40% of our outstanding common shares (the “Trigger Event”), our board of directors will be divided into three classes that are as nearly equal in number as is reasonably possible and each director will be assigned to one of three classes, with each class of directors elected for a three-year term to succeed the directors of the same class whose terms are then expiring; provided that LandBridge Holdings shall have the right to designate the initial class assigned to each director immediately following the occurrence of the Trigger Event;
•
prohibiting cumulative voting in the election of directors;
•
providing that after the Trigger Event, the affirmative vote of the holders of not less than 66 2/3% in voting power of all then-outstanding common shares entitled to vote generally in the election of our board of directors, voting together as a single class, will be required to remove any director from office, and such removal may only be for “cause”;
•
providing that after the Trigger Event, all vacancies, including newly created directorships, may, except as otherwise required by the terms of the Shareholder’s Agreement, law or, if applicable, the rights of holders of a series of preferred shares, only be

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filled by the affirmative vote of a majority of directors then in office, even if less than a quorum, or by a sole remaining director;
•
providing that after the Trigger Event, shareholders will not be permitted to call special meetings of shareholders;
•
providing that after the Trigger Event, our shareholders may not act by written consent and may only act at a duly called annual or special meeting;
•
establish advance notice procedures with respect to shareholder proposals and nominations of persons for election to our board of directors, other than nominations made by or at the direction of our board of directors or any committee thereof; and
•
providing that a majority of our board of directors is expressly authorized to adopt, or to alter or repeal our Operating Agreement.

Pursuant to our Operating Agreement, for so long as LandBridge Holdings beneficially owns at least 40% of our outstanding common shares, we have agreed not to take, and will take all necessary action to cause our subsidiaries not to take, certain direct or indirect actions (or enter into an agreement to take such actions) without the prior consent of LandBridge Holdings.

Our Operating Agreement designates the Court of Chancery of the State of Delaware as the sole and exclusive forum for certain types of actions and proceedings that may be initiated by our shareholders, which could limit our shareholders’ ability to obtain a favorable judicial forum for disputes with us or our directors, officers, employees, other personnel or agents.

Our Operating Agreement provides that, unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware (or, if the Court of Chancery of the State of Delaware does not have jurisdiction, the Superior Court of the State of Delaware, or, if the Superior Court of the State of Delaware does not have jurisdiction, the United States District Court for the District of Delaware, in each case, subject to that court having personal jurisdiction over the indispensable parties named defendants therein) will, to the fullest extent permitted by applicable law, be the sole and exclusive forum for (i) any derivative action or proceeding brought on our behalf, (ii) any action asserting a claim of breach of a fiduciary duty owed by any of our directors, officers, employees, other personnel, or agents to us or our shareholders, (iii) any action asserting a claim against us or any director or officer or employee or other personnel of ours arising pursuant to any provision of the Delaware Limited Liability Company Act (the “Delaware LLC Act”) or our Operating Agreement or (iv) any action asserting a claim against us or any director, officer, employee or other personnel of ours that is governed by the internal affairs doctrine. Our Operating Agreement also provides that, to the fullest extent permitted by applicable law, the United States District Court for the District of Delaware will be the sole and exclusive forum for resolving any complaint asserting a cause of action under the Securities Act. This provision would not apply to claims brought to enforce a duty or liability created by the Exchange Act, the Securities Act or any other claim for which the federal courts have exclusive jurisdiction. Any person or entity purchasing or otherwise acquiring any interest in our common shares will be deemed to have notice of, and consented to, the provisions of our Operating Agreement described in the preceding sentence. This choice of forum provision may limit a shareholder’s ability to bring a claim in a judicial forum that it finds favorable for disputes with us or our directors, officers, employees, other personnel or agents, which may discourage such lawsuits against us and such persons. Alternatively, if a court were to find these provisions of our Operating Agreement inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, we may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect our results of operations, cash flows and financial position.

There are certain provisions in our Operating Agreement regarding fiduciary duties of our directors, exculpation and indemnification of our officers and directors and the approval of conflicted transactions that differ from the DGCL in a manner that may be less protective of the interests of our public shareholders and restricts the remedies available to shareholders for actions taken by our officers and directors that might otherwise constitute breaches of fiduciary duties if we were subject to the DGCL.

Our Operating Agreement contains certain provisions regarding exculpation and indemnification of our officers and directors and the approval of conflicted transactions that differ from the DGCL in a manner that may be less protective of the interests of our public shareholders. For example, our Operating Agreement provides that to the fullest extent permitted by applicable law our directors or officers will not be liable to us. In contrast, under the DGCL, a director or officer would be liable to us for (i) breach of duty of loyalty to us or our shareholders, (ii) intentional misconduct or knowing violations of the law that are not done in good faith, (iii) improper redemption of shares or declaration of dividends or (iv) a transaction from which the director derived an improper personal benefit.

Pursuant to our Operating Agreement and indemnification agreements, we must indemnify our directors and officers for acts or omissions to the fullest extent permitted by law. In contrast, under the DGCL, a corporation can only indemnify directors and officers for acts and omissions if the director or officer acted in good faith, in a manner he or she reasonably believed to be in or not opposed

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to the best interest of the corporation, and, in a criminal action, if the officer or director had no reasonable cause to believe his or her conduct was unlawful.

Additionally, our Operating Agreement provides that in the event a potential conflict of interest exists or arises between any of our directors, officers, equity owners or their respective affiliates, including LandBridge Holdings, on the one hand, and us, any of our subsidiaries or any of our public shareholders, on the other hand, a resolution or course of action by our board of directors shall be deemed approved by all of our shareholders, and shall not constitute a breach of the fiduciary duties of members of our board of directors to us or our shareholders, if such resolution or course of action (i) is approved by a conflicts committee, which is composed entirely of independent directors, (ii) is approved by shareholders holding a majority of our common shares that are disinterested parties, (iii) is determined by our board of directors to be on terms that, when taken together in their entirety, are no less favorable than those generally provided to or available from unrelated third parties or (iv) is determined by our board of directors to be fair and reasonable to us, taking into account the totality of the relationships between the parties involved (including other transactions that may be particularly favorable or advantageous to us). In contrast, under the DGCL, a corporation is not permitted to exempt board members from claims of breach of fiduciary duty under such circumstances.

Accordingly, our Operating Agreement may be less protective of the interests of our public shareholders, when compared to the DGCL, insofar as it relates to the exculpation and indemnification of our officers and directors.

We are a holding company. Our principal asset is our equity interest in OpCo, and accordingly, we will be dependent upon distributions from OpCo to pay taxes and cover our corporate and other overhead expenses.

We are a holding company and have no material assets other than our equity interest in OpCo. We have no independent means of generating revenue. To the extent OpCo has available cash and subject to the terms of any debt instruments or other applicable agreements, we intend to cause OpCo to make (i) generally pro rata distributions to OpCo Unitholders, including us, in an amount at least sufficient to allow us to pay our taxes, (ii) at the election of certain holders of OpCo Units, additional distributions in an amount generally intended to allow such OpCo Unitholders to satisfy their respective income tax liabilities with respect to their allocable share of the income of OpCo (based on certain assumptions and conventions), which additional distributions may be made on a pro rata basis to all OpCo Unitholders (including us) or a non-pro rata basis to OpCo Unitholders (other than us) in redemption of OpCo Units from such holders and (iii) non pro rata distributions to us in an amount at least sufficient to reimburse us for our corporate and other overhead expenses. In addition, as the sole managing member of OpCo, we intend to cause OpCo to make pro rata distributions to all of its unitholders, including us, in an amount sufficient to allow us to fund dividends to our shareholders in accordance with our dividend policy, to the extent our board of directors declares such dividends. Therefore, although we expect to pay dividends on our Class A shares in amounts determined by our board of directors, from time to time, our ability to do so may be limited to the extent OpCo and its subsidiaries are limited in their ability to make these and other distributions to us. To the extent that we need funds and OpCo or its subsidiaries are restricted from making distributions under applicable law or under the terms of any current or future financing or other arrangements or are otherwise unable to provide such funds, our results of operations, cash flows and financial position could be materially and adversely affected.

In certain circumstances, OpCo will be required to make tax distributions to OpCo Unitholders, and such tax distribution may be substantial. To the extent we receive tax distributions in excess of our actual tax liabilities and retain such excess cash, the OpCo Unitholders would benefit from such accumulated cash balances if they exercise their Redemption Right.

Pursuant to the OpCo LLC Agreement, OpCo will make generally pro rata distributions to the OpCo Unitholders, including us, in an amount sufficient to allow us to satisfy our actual tax liabilities. In addition, to the extent OpCo has available cash, OpCo will be required to make additional pro rata tax distributions to all OpCo Unitholders in an amount generally intended to allow the OpCo Unitholders (other than us) to satisfy their assumed tax liabilities with respect to their allocable share of the income of OpCo (based on certain assumptions and conventions and as determined by OpCo). For this purpose, the determination of available cash will take into account, among other factors, (i) the existing indebtedness and other obligations of OpCo and its subsidiaries and their anticipated borrowing needs, (ii) the ability of OpCo and its subsidiaries to take on additional indebtedness on commercially reasonable terms and (iii) any necessary or appropriate reserves.

The amount of such additional tax distributions will be determined based on certain assumptions, including assumed income tax rates, and will be calculated after taking into account other distributions (including other tax distributions) made by OpCo. Additional tax distributions may significantly exceed the actual tax liability for many of the OpCo Unitholders, including us. If we retain the excess cash we receive from such distributions, the OpCo Unitholders would benefit from any value attributable to such accumulated cash balances as a result of their exercise of the Redemption Right. However, we intend to take steps to eliminate any material excess cash balances, which could include, but are not necessarily limited to, a distribution of the excess cash to holders of our Class A shares or the reinvestment of such cash in OpCo for additional OpCo Units.

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In addition, the tax distributions that OpCo may be required to make may be substantial, and the amount of any additional tax distributions OpCo is required to make likely will exceed the tax liabilities that would be owed by a corporate taxpayer similarly situated to OpCo. Funds used by OpCo to satisfy its obligation to make tax distributions will not be available for reinvestment in our business, except to the extent we or certain other OpCo Unitholders use any excess cash received to reinvest in OpCo for additional OpCo Units. In addition, because cash available for additional tax distributions will be determined taking into account the ability of OpCo and its subsidiaries to take on additional borrowing, OpCo may be required to increase its indebtedness in order to fund additional tax distributions. Such additional borrowing may adversely affect our results of operations, cash flows and financial position by, without limitation, limiting our ability to borrow in the future for other purposes, such as capital expenditures, and increasing our interest expense and leverage ratios.

If OpCo were to become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes, significant tax inefficiencies might result.

We intend to operate such that OpCo does not become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes. A “publicly traded partnership” is a partnership the interests of which are traded on an established securities market or are readily tradable on a secondary market or the substantial equivalent thereof. Under certain circumstances, redemptions of OpCo Units pursuant to the Redemption Right (or our Call Right (as described in the OpCo LLC Agreement)) or other transfers of OpCo Units could cause OpCo to be treated as a publicly traded partnership. Applicable U.S. Treasury regulations provide for certain safe harbors from treatment as a publicly traded partnership, and we intend to operate such that redemptions or other transfers of OpCo Units qualify for one or more such safe harbors. For example, we intend to limit the number of OpCo Unitholders, and the OpCo LLC Agreement provides for limitations on the ability of OpCo Unitholders to transfer their OpCo Units and provides us, as managing member of OpCo, with the right to impose restrictions (in addition to those already in place) on the ability of OpCo Unitholders to redeem their OpCo Units pursuant to the Redemption Right to the extent we believe that it is necessary to ensure that OpCo will continue to be treated as a partnership for U.S. federal income tax purposes.

If OpCo were to become a publicly traded partnership, significant tax inefficiencies might result for us and for OpCo, including as a result of our inability to file a consolidated U.S. federal income tax return with OpCo.

There can be no assurance that we will purchase all the shares authorized under our share repurchase program or that such program will enhance the long-term value of our share price.

On February 24, 2026, our board of directors approved a share repurchase program. The program permits the repurchase of up to $50 million of the Company’s Class A shares through December 2027. There is no obligation for us to continue to repurchase or to repurchase any specific dollar amount of shares, and the program may be suspended, modified or discontinued at any time without prior notice. The timing, as well as the number and value of shares repurchased under the program, will be determined by the Company at its discretion and will depend on a variety of factors, including management's assessment of the intrinsic value of our Class A shares, the market price of the our Class A shares, general market and economic conditions, available liquidity, compliance with the Company's debt and other agreements, applicable legal requirements, and other considerations. The share repurchase program could affect the price of our stock and increase volatility in the market. We cannot guarantee that we will purchase all of the shares authorized under the share repurchase program or that such program will enhance the long-term value of our share price. In addition, repurchase regulations and taxes may add additional payment burden to the Company from our share repurchase program. In the past, there have been proposals to increase the amount of the U.S. federal stock repurchase excise tax from 1% to 4%; however, it is unclear whether such a change in the amount of the excise tax will be enacted and, if enacted, how soon any such change could take effect.

Item 1B. Unresolved Staff Comments

None.

Item 1C. Cybersecurity

Our cybersecurity program is designed to protect our information systems and information against cybersecurity threats that may impact the confidentiality, integrity and availability of our information systems and information. Our program includes policies, processes and technologies to assess, identify and manage risks from cybersecurity threats and aligns with the National Institute of Standards and Technology (“NIST”) Cybersecurity Framework.

Governance

Our board of directors, in coordination with the Audit Committee, oversees the Company’s processes for assessing and managing risk. Our board of directors has delegated primary responsibility for overseeing our enterprise risk management process, including oversight of information technology, cybersecurity, and data privacy risks, to the Audit Committee. Despite this delegation of primary

56

responsibility, both the Audit Committee and the board of directors are actively involved in risk oversight. The board of directors and Audit Committee regularly review the measures implemented by the Company to identify and mitigate data protection and cybersecurity risks.

Management is responsible for identifying and assessing cybersecurity risks, establishing processes to ensure that such cybersecurity risk exposures are monitored, implementing proactive mitigation measures and responding in the event of an incident. We seek to identify and mitigate cybersecurity risks through a comprehensive, cross-functional approach. The Cyber Incident Response Team is headed by the Manager’s Senior Vice President of Information Technology (the “SVP of IT”) and also includes senior representatives from various corporate and operational functions of the Manager. The Manager’s SVP of IT possesses deep experience in technology and cybersecurity, gained over a career of over 20 years managing IT functions for organizations, including network infrastructure, cloud administration, application development and cybersecurity. The SVP of IT possesses a degree in Information Systems and regularly attends educational and professional development seminars on cybersecurity trends and threats. She leads our information technology team, which is responsible for managing our internal IT and cybersecurity processes. The Manager’s SVP of IT meets quarterly with the Manager’s Risk Committee, which is comprised of senior representatives from various corporate functions and other members of our senior management to provide updates on the Company’s cyber risks and threats, cybersecurity incidents (if any), the status of projects to strengthen our information security systems, assessments of the information security program and the emerging threat landscape. We have processes in place to guide our assessment, response and notification procedures upon the occurrence of a cybersecurity incident. Further, we have partnered with a third-party cybersecurity vendor to provide managed security services in order to supplement our internal IT and cybersecurity processes. Depending on the nature and severity of the cybersecurity incident, this process provides for notifying and escalating the incident to our board of directors.

Risk Management and Strategy

Our business operations rely on the secure collection, storage, transmission and other processing of proprietary, confidential and sensitive data. Our information and operational technology networks, those of our operators and managers, and those of third parties on whom we rely, are important to our ability to perform day-to-day operations of our business. As a part of our cybersecurity risk management program, we review the various different Company policies that cover cybersecurity on an annual basis and have implemented procedures for responding to cybersecurity incidents. We provide training and awareness programs for all employees of Manager who provide services to us that include periodic and ongoing assessments to drive adoption and awareness of cybersecurity processes and controls. We have implemented network monitoring, containment and incident response tools, vulnerability management processes and penetration testing. We also actively engage with key vendors and third-party advisors and consultants that assist us with identifying, assessing and managing cybersecurity risks to our business and employ processes to detect and monitor unusual network activity. In connection with our use of third parties, we employ systems and processes designed to oversee, identify and reduce the potential impact of a security incident at such vendor or service provider.

Material Cybersecurity Risks, Threats and Incidents

The oil and gas industry has become increasingly dependent on information technology and operational technology to conduct certain processing activities. At the same time, cybersecurity incidents, including deliberate attacks or unintentional events, have increased. Due to evolving cybersecurity threats, it has and will continue to be difficult to prevent, detect, mitigate, and remediate cybersecurity incidents.

As detailed elsewhere in this Annual Report, we rely on information technology to manage our business and support our operations, including our secure processing of proprietary and other types of information. Despite ongoing efforts, our systems for protecting against cybersecurity risks may not be sufficient, and a cyber attack or security breach could result in liability under data privacy laws, regulatory penalties, damage to our reputation or loss of confidence in us, or additional costs for remediation and modification or enhancement of our information systems to prevent future occurrences. As of the date of this report, we have not experienced any material cybersecurity incidents and are not aware of any material risks from cybersecurity threats that have materially affected or are reasonably likely to materially affect the Company, including our business strategy, results of operations or financial condition. This does not guarantee that future attacks, incidents or threats will not have a material impact or that we are not currently the subject of an undetected incident or threat that may have such an impact. For additional information on cybersecurity risks we face, see “Risk Factors—Risks Related to Our Business and Operations—Cyber incidents or attacks targeting systems and infrastructure used by the oil and natural gas industry may adversely impact our operations, and a cyber incident or systems failure could result in information theft, data corruption and operational disruption and our results of operations, cash flows or financial position may be adversely impacted.”

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Item 2. Properties

As of December 31, 2025, we owned or managed more than 315,000 surface acres in and around the Delaware Basin sub-region of the Permian Basin in Texas and New Mexico. Substantially all of our land is encumbered by mortgages that secure the 2025 Revolving Credit Facility. In addition, pursuant to our SURAs and SUAs, we grant our customers rights to use our land in return for pre-determined fees and royalties. Other than such mortgages and our SURAs and SUAs, there are no material liens or encumbrances on our title to our surface estate as of December 31, 2025.

The following table shows by county our surface acreage owned and attributable to long-term leasehold or management agreements as of December 31, 2025:

|  | Number of |
Location (by county and position) |  | Surface Acres (1)(2) |
Northern Position |  |  |
Andrews County (TX) |  |  | 20,000 |
Lea County (NM) |  |  | 40,000 |
Eddy County (NM) |  |  | 1,000 |
Total |  |  | 61,000 |
Stateline Position |  |  |
Loving County (TX) |  |  | 98,000 |
Winkler County (TX) |  |  | 36,000 |
Lea County (NM) |  |  | 16,000 |
Reeves County (TX) |  |  | 19,000 |
Total |  |  | 169,000 |
Southern Position |  |  |
Reeves County (TX) |  |  | 72,000 |
Pecos County (TX) |  |  | 9,000 |
Ward County (TX) |  |  | 6,000 |
Total |  |  | 87,000 |
Total Acres |  |  | 317,000 |

(1)
The figures in this table are rounded to the nearest thousand acres.
(2)
Inclusive of approximately 14,000 long-term leasehold or managed acres.

Item 3. Legal Proceedings

Due to the nature of our business, we may become, from time to time, involved in routine litigation or subject to disputes or claims related to our business activities. In the opinion of our management, there are no pending litigation, disputes or claims against us which, if decided adversely, will have a material adverse effect on our financial condition, cash flows or results of operations. See Part II, Item 8. Financial Statements and Supplementary Data — Note 13. Commitments and Contingencies.

Item 4. Mine Safety Disclosures

Not applicable.

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PART II

Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities

Market Information

Our Class A shares are listed on the NYSE and NYSE Texas under the symbol “LB.” As of February 23, 2026, 27,838,199 Class A shares were outstanding, with two holders of record. This number does not include shareholders whose shares are held in trust by other entities and the actual number of our shareholders is greater than the number of holders of record. As of February 23, 2026, 49,250,916 Class B shares were outstanding, with six holders of record. Our Class B shares are not listed on any exchange, and there is no established public trading market for such Class B shares.

Dividends

On February 24, 2026, our board of directors declared a dividend on our Class A shares of $0.12 per share, payable on March 19, 2026 to shareholders of record as of March 5, 2026.

While we intend to pay dividends on our Class A shares in amounts and at times determined from time to time by our board of directors, we have not adopted a formal written dividend policy to pay any particular amount of dividends based on the achievement of, or derivable from, any specific financial metrics. Furthermore, we are not contractually obligated to pay any dividends and do not have any required minimum dividend amount, and the Notes and 2025 Revolving Credit Facility may limit our ability to pay dividends. If our board of directors determines to pay dividends in the future, the amount of such dividends may vary from quarter to quarter and may be significantly reduced or eliminated entirely. Our future dividends depend on our cash flow needs, which may be impacted by the availability of financing alternatives, the need to service any future indebtedness or other liquidity needs, potential acquisition opportunities and general industry and business conditions, including the level of use of our land and its resources, among other things, and will be subject to approval by our board of directors, applicable law and the terms of our existing debt instruments, including our revolving credit facility.

Performance Graph

The performance graph below compares the cumulative return to holders of our Class A shares, the Standard & Poor’s 500 Index (“S&P 500”) and the reference group defined below (the “Reference Group”) during the period beginning on June 28, 2024 and ending on December 31, 2025. The performance graph was prepared based on the following assumptions: (i) $100 was invested in our Class A shares and in each of the S&P 500 and Reference Group at the beginning of the period and (ii) the dividends were reinvested on the relevant payment dates. The results reflected in the graph below are historical and are not necessarily indicative of future performance.

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|  | June 30, 2024 |  |  | December 31, 2024 |  |  | June 30, 2025 |  |  | December 31, 2025 |
S&P 500 Index |  | $ | 100.00 |  |  | $ | 107.30 |  |  | $ | 113.20 |  |  | $ | 124.90 |
LandBridge |  | $ | 100.00 |  |  | $ | 380.60 |  |  | $ | 399.30 |  |  | $ | 291.10 |
Reference Group (1) |  | $ | 100.00 |  |  | $ | 103.10 |  |  | $ | 114.00 |  |  | $ | 128.10 |

(1)
Comparable companies include the following: Farmland Partners Inc., First Industrial Realty Trust, Inc., Franco-Nevada Corporation, Gladstone Land Corporation, OR Royalties Inc., PotlatchDeltic Corporation, Prologis, Inc., Rayonier Inc., Rexford Industrial Realty, Inc, Royal Gold, Inc., Tejon Ranch Co., TPL, The St. Joe Company, Weyerhaeuser Company, Wheaton Precious Metals Corp.

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

There was no share repurchase activity during the three months ended December 31, 2025.

Securities Authorized for Issuance under Equity Compensation Plans

See Part III, Item 12. “Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters” for information regarding securities authorized for issuance under equity compensation plans.

Recent Sales of Unregistered Equity Securities

1918 Ranch Acquisition

On November 12, 2025, to fund a portion of the purchase consideration for the 1918 Ranch Acquisition, OpCo issued 657,411 OpCo Units and the Company issued an equal number of Class B shares valued at $53.6 million. The fair value of the OpCo Units was determined based on the closing price of the Company’s Class A shares on the date of acquisition. The securities issued in connection with the 1918 Ranch Acquisition were issued pursuant to the exemption from registration contained in Section 4(a)(2) of the Securities Act.

Item 6. [Reserved]

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Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations

The following discussion and analysis of our financial condition and results of operations is based on, and should be read in conjunction with, our Financial Statements and notes thereto in Item 8, “Financial Statements and Supplementary Data” of this Annual Report. The following discussion contains “forward-looking statements” reflecting our current expectations, future plans, estimates, beliefs and assumptions concerning events and financial trends that may affect our future results of operations, cash flows and financial position. Our actual results and the timing of events may differ materially from those contained in these forward-looking statements due to a number of factors, including certain factors outside our control. Factors that could cause or contribute to such differences include, but are not limited to, market prices for oil and natural gas, production volumes, economic and competitive conditions, regulatory changes and other uncertainties, as well as those factors discussed below and elsewhere in this Annual Report, particularly in the sections titled “Risk Factors” and “Cautionary Note Regarding Forward-Looking Statements,” all of which are difficult to predict. In light of these risks, uncertainties and assumptions, the forward-looking events discussed may not occur. We assume no obligation to publicly update any of these forward-looking statements except as otherwise required by applicable law.

Except as otherwise indicated or required by context, references to “LandBridge,” the “Company,” “we,” “us,” “our” and like terms refer (i) prior to the consummation of the reorganizations of entities under common control (the “Corporate Reorganization”) and the initial public offering that occurred on July 1, 2024 (the “IPO”), to OpCo and its subsidiaries, our predecessor for financial reporting purposes and (ii) subsequent to the consummation of the Corporate Reorganization and the IPO, to LandBridge and its subsidiaries, including OpCo and its subsidiaries.

The section primarily focuses on 2025 and 2024 items and year-to-year comparisons between 2025 and 2024. Discussions of 2023 items and year-to-year comparisons between 2024 and 2023 that are not included in this report can be found in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part II, Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2024, filed with the SEC on March 6, 2025.

The historical financial information in this “Management’s Discussion and Analysis of Financial Condition and Results of Operations” reflects only the historical financial results of us or our predecessor, OpCo, as applicable, and does not give pro forma effect to the Corporate Reorganization or the IPO.

Overview

Land is a fundamental requirement for the development and production of energy and the construction and operation of critical infrastructure. As of December 31, 2025, we owned or managed more than 315,000 surface acres in and around the Delaware Basin sub-region in the prolific Permian Basin, which is the most active area for oil and gas exploration and development in the United States. Access to expansive surface acreage is necessary for oil and natural gas development, solar power generation, power storage, digital infrastructure and non-hazardous oilfield reclamation and solid waste facilities. Further, the significant industrial economy that exists to service and support energy and infrastructure development requires access to surface acreage to support those activities. Our strategy is to actively manage our land and resources to support and encourage energy and infrastructure development and other land uses that will generate long-term revenue and Free Cash Flow for us and returns to our shareholders.

We take an active approach to the commercial development of our land, seeking to maximize the long-term value of our surface acreage and our resources by identifying and seeking commercial partners looking to invest in developing and operating long-term assets within and beyond the oil and gas value chain on our land. We measure our revenue divided by our acreage as a performance metric, which we refer to as “surface use economic efficiency.” Further, we are actively pursuing additional revenue streams beyond the hydrocarbon value chain to maximize utilization of our land and resources. We have entered into, or are currently pursuing, primarily long-term commercial relationships with businesses focused on solar power generation, power storage, power generation/microgrids, cryptocurrency mining and data management, as well as other renewable energy production, among other industries and applications. Similar to the other operations conducted on our land, we expect to enter into surface use or similar agreements with the owners of these projects from which we expect to receive surface use fees and other payments in connection with the utilization of our land, but we do not expect to own or operate such projects or expect to incur significant capital expenditures in connection therewith.

We share a financial sponsor, Five Point, and our management team with WaterBridge. WaterBridge is one of the largest water midstream companies in the United States and operates a large-scale network of pipelines and other infrastructure in the Delaware Basin that, as of December 31, 2025, handles approximately 2.5 million bpd of water associated with oil and natural gas production, with approximately 4.2 million bpd of total handling capacity. These relationships provide our shared management team visibility into key areas of oil and natural gas production and long-term trends, which we leverage to encourage and support the development of critical infrastructure on our land and generate additional revenue for us. As of December 31, 2025, WaterBridge operates approximately 1.5 million bpd of water handling capacity on our land, with approximately 3.2 million bpd of additional permitted

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capacity available for future development on our land. We receive royalties for each barrel of produced water that WaterBridge handles on our land as well as surface use payments for infrastructure constructed on our land.

2025 Significant Events

1918 Ranch Acquisition

On November 12, 2025, we acquired approximately 38,000 total acres across Reeves, Loving, Winkler and Ward counties, Texas, and certain related assets from 1918 Ranch & Royalty, LLC for total purchase consideration of $262.1 million, excluding transaction costs, consisting of approximately $208.5 million in cash and 657,411 OpCo Units (together with an equal number of Class B shares) valued at $53.6 million. The fair value of the OpCo Units was determined based on the closing price of the Company’s Class A shares on the date of acquisition.

Termination of 2023 Credit Agreement

On October 3, 2025 (the “Third Amendment Effective Date”), DBR Land LLC, a Delaware limited liability company and a subsidiary of the Company (the “Borrower”), entered into the Third Amendment to Credit Agreement (the “Third Amendment”) with the guarantors party thereto, the lenders party thereto, and Texas Capital Bank, as administrative agent and letter of credit issuer (the “Administrative Agent”), to amend that certain credit agreement, dated July 3, 2023 (as amended prior to the date hereof, the “2023 Credit Agreement”) among the Borrower, the guarantors party thereto, the lenders party thereto, and the Administrative Agent. The Third Amendment provided for a new delayed draw term loan facility with total commitments of $200.0 million for the purpose of partially financing the 1918 Ranch Acquisition and to pay certain related costs and expenses (the “DDTL Facility”).

On November 10, 2025, the Borrower drew in full the $200.0 million available under the DDTL Facility to partially fund the 1918 Ranch Acquisition and pay certain related expenses. The DDTL Facility included an unused commitment fee of 37.5 basis points that accrued from the Third Amendment Effective Date until November 10, 2025, applied to the average daily unused amount of the DDTL Facility.

The 2023 Credit Agreement was terminated on November 25, 2025 in connection with the closing of the Notes and the effectiveness of the 2025 Revolving Credit Facility.

November 2025 Refinancing Transactions

2025 Revolving Credit Facility

On November 18, 2025, OpCo entered into a new revolving credit facility (the “2025 Revolving Credit Facility”) which provides for lender commitments of $275.0 million and matures on the earlier of (a) June 30, 2030, and (b) the date that is 91 days prior to the stated maturity of the Notes, if, on such date, the outstanding principal amount of the Notes is greater than $50 million. See “—Liquidity and Capital Resources—Debt Instruments—2025 Revolving Credit Facility” for additional information relating to the 2025 Revolving Credit Facility.

As of December 31, 2025, the Company had approximately $70.0 million borrowings outstanding and $205.0 million of available borrowing capacity under the 2025 Revolving Credit Facility. The weighted average interest rate on the total amount of borrowings outstanding under the 2025 Revolving Credit Facility as of December 31, 2025 was 6.13%.

Issuance of Notes

On November 25, 2025, OpCo issued $500.0 million aggregate principal amount of 6.25% fixed-rate senior unsecured notes due 2030 (the “Notes”). See “—Liquidity and Capital Resources—Debt Instruments—Notes” for additional information relating to the Notes.

On November 25, 2025, the Company used the net proceeds of $491.9 million from the issuance of the Notes, $70.0 million of borrowings under the 2025 Revolving Credit Facility and $4.8 million of cash on hand to repay all outstanding borrowings and accrued interest under the 2023 Credit Agreement, which was then terminated. At the time of repayment, the outstanding borrowings and accrued interest under the 2023 Credit Agreement totaled $564.5 million. The remaining proceeds were used to pay $2.1 million of offering expenses.

Market Condition and Outlook

Over the last several years, the global economy and the oil and natural gas industry in particular has faced substantial volatility. This has been driven by geopolitical conflicts, domestic political uncertainties, the enactment of the OBBBA, potential U.S. and foreign

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tariffs, evolving international trade policies and conflicts, OPEC+ production decisions, persistent elevated inflation, higher interest rates and capital costs and continued industry consolidation. In the Delaware Basin, sustained high levels of exploration and production activity have led to labor shortages and supply chain disruptions. These challenges have directly impacted drilling, completion and production efforts by E&P companies. Additionally, volatility in commodity prices — particularly WTI crude oil and Henry Hub natural gas benchmarks, with especially pronounced volatility in realized prices at the Waha Hub — have influenced E&P operators’ development plans, rig counts and overall activity levels.

Broader macroeconomic and policy developments, including provisions in the OBBBA (which extended certain tax incentives beneficial to fossil fuels while introducing new uncertainties) and shifts in international trade policies (such as the imposition of tariffs or product restrictions), could impair our customers’ ability to secure raw materials, equipment or financing. This, in turn, may reduce their operational activity on or around our surface acreage in the Delaware Basin. Any escalation in U.S. trade disruptions or retaliatory measures from other nations could further adversely affect demand for our land.

Despite these challenges, we believe the outlook for energy and infrastructure development, particularly within the Permian Basin, remains positive. Additionally, such development may be aided by President Trump’s various Executive Orders relating to energy production, which include expedited approvals for energy resource infrastructure as well as the removal of various impediments to the development of domestic energy resources, including oil and gas. We are well-positioned to benefit from the continued build out of supporting infrastructure in the region which will require access to surface acreage. In addition, we expect to benefit from advancements in alternative forms of energy. While these incentives could further accelerate the transition of the U.S. economy away from the use of fossil fuels, alternative energy technologies often require access to material surface acreage and supporting infrastructure, which we are also well positioned to provide and facilitate. Please see the “Business” of this Annual Report for more information.

Year-end Results

Significant financial and operating highlights for the year ended December 31, 2025 include:

•
Revenues of $199.1 million, an increase of $89.1 million as compared to the prior year;
•
Net income of $72.4 million as compared to net loss of $41.5 million in 2024;
•
Net income margin of 36% as compared to net loss margin of 38% in 2024;
•
Adjusted EBITDA(1) of $177.2 million, an increase of 83% as compared to the prior year;
•
Adjusted EBITDA Margin(1) of 89%, remained consistent with the prior year;
•
Cash flow from operating activities of $126.3 million, an increase of 87% as compared to the prior year;
•
Free Cash Flow(1) of $122.0 million, an increase of 83% as compared to the prior year;
•
Operating cash flow margin of 63%,remained consistent with the prior year; and
•
Free Cash Flow Margin(1) of 61%, remained consistent with the prior year;

(1) Adjusted EBITDA, Adjusted EBITDA Margin, Free Cash Flow and Free Cash Flow Margin are non-GAAP financial measures. See “Non-GAAP Financial Measures” for more information regarding these non-GAAP measures and reconciliations to the most comparable GAAP measures. See also “How We Evaluate Our Operations” for more information regarding Adjusted EBITDA, Adjusted EBITDA Margin, Free Cash Flow and Free Cash Flow Margin.

Net income and net income margin for the year ended December 31, 2025 include non-cash share-based compensation expense of $45.3 million, of which $8.8 million is attributable to RSUs issued by the Company and $36.5 million is attributable to LBH Incentive Units. Net loss and net loss margin for the year ended December 31, 2024 include non-cash share-based compensation expense of $95.3 million, of which $4.0 million is attributable to RSUs issued by the Company, $72.6 million is attributable to NDB Incentive Units issued prior to the IPO and $18.7 million is attributable to LBH Incentive Units. Any actual cash expense associated with such LBH Incentive Units is borne solely by LandBridge Holdings and not the Company. Distributions attributable to LBH Incentive Units are based on returns received by investors of LandBridge Holdings once certain return threshold have been met and are neither an obligation of the Company nor taken into consideration for distributions to investors in the Company. Refer to Note 2 — Summary of Significant Accounting Policies and Note 10 — Share-Based Compensation to our consolidated financial statements for additional information regarding LBH Incentive Units.

How We Generate Revenue

We generate revenue from multiple sources, including the use of our surface acreage, the sale of resources from our land and oil and gas and mineral royalties. The fees, royalty rates, payment structure and other related terms in our contracts are negotiated on a case-by-case basis, taking into account the surface use of our land, the type of resources extracted, the amount of use expected to be made of our land, and the amount of resources to be produced and/or extracted. In any given period, the amount and sources of revenues we receive from any particular customer can fluctuate based on the nature, timing and scope of such customer’s activities on our land. For example, during the initial phase of a customer’s activities on our land, we would generally expect to receive usage-based fees and revenues under our SURAs and SUAs related to installation of infrastructure necessary to support long-term operations. Over time,

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these revenues would generally be expected to migrate to royalty revenue and resource sales based on such customer’s use of our land and resources. Our revenue consists of the principal components discussed below.

Surface Use Royalties and Revenues

Surface Use Royalties. We enter into SURAs and certain overarching SUAs with operators that require royalty payments to us based on a percentage of the customer’s gross revenues derived from use of our land and/or volumetric use of infrastructure installed on our land in exchange for rights of use of our land. Royalties we receive from operations under our SURAs include produced water transportation and handling operations, skim oil recovery and produced water throughput and waste reclamation. Our SURAs generally have terms ranging from a minimum of five years to 10 years, impose only nominal obligations on us, typically do not include minimum purchase or use commitments by our customers but do generally provide for automatic renewal-based increases in royalties that are tied to the Consumer Price Index (“CPI”) or are negotiated on a case-by-case basis.

Easements and other surface-related income. SUAs permit operators to install drilling sites, pipelines, roadways, electric lines and other facilities and equipment on land owned by us. We typically receive a per-rod or per-acre fee when the contract is executed, based on the aggregate amount of our land that is utilized under such SUA, and we often receive additional fees at the beginning of each renewal period or on a monthly or annual basis. Our SUAs generally require our customers to use the resources from our land, such as brackish water and sand, for their operations on our land, for which we receive our customary fees. Our SUAs generally have terms ranging from a minimum of five years to 10 years, with early termination rights for non-use over a pre-determined period of time, typically 12 to 18 months, typically do not include minimum commitments with respect to the type and amount of infrastructure to be installed on our property or the amount of revenue to be received by us and generally provide for automatic renewal-based increases in royalties that are tied to the CPI or negotiated on a case-by-case basis.

Resource Sales and Royalties

Resource Sales. Resource sales generally include brackish water to be used primarily in well completions in exchange for a per barrel fee, which is negotiated and varies depending on the destination of the brackish water. Similarly, our customers buy other surface composite materials from us for the construction of access roads and well pads for which we receive a fixed-fee per cubic yard extracted from our surface acreage. Our agreements related to the sale of resources generally have terms ranging from a minimum of five years to 10 years, with early termination rights for non-use over a pre-determined period of time, typically 12 to 18 months.

Resource Royalties. We lease our surface acreage to customers to construct and operate, at their expense, brackish water wells and sand mines to provide in-basin water and sand for use in oil and natural gas completion operations. Such customers hold the exclusive right to the water and sand extracted from the leased surface acreage and may be required to make minimum royalty payments as a result. The agreements pursuant to which we receive resource royalties have varying primary terms of at least one year, contain rights for renewal so long as the customer continues to operate on our land and generally do not impose minimum production requirements on our customers. We typically receive a fee when the contract is executed and a fixed royalty per barrel of water or ton of sand extracted. In situations where our customers do not operate brackish water wells on our surface but require the use of water for their operations, customers generally must acquire such water from us for our customary fee.

Oil and Gas Royalties

Oil and Gas Royalties. Oil and gas royalties are received in connection with oil and natural gas mineral interests owned by us. Oil and gas royalties are recognized as revenue as oil and gas are produced or severed from the mineral lease. The oil and gas royalties we receive are dependent upon producer-specific location, contractual price differences and market prices for oil and natural gas, which, given such prices’ volatility, may cause our oil and gas royalties to fluctuate. Oil and gas royalties also include mineral lease bonus revenues, which we receive by leasing our mineral interests to E&P companies. When we execute a mineral lease contract, the lease generally transfers the rights to any oil or natural gas discovered to the E&P company and grants us the right to a specified royalty interest payable on future production.

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We expect our fee-based revenues to grow over time relative to our oil and gas royalties. While our focus is on fee-based arrangements, our oil and gas royalties fluctuate with market prices for oil and natural gas. The following table presents the amount and relative percentage of each component of our revenues for the following periods:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |
|  | Amount ($) |  |  | % |  |  | Amount ($) |  |  | % |
Surface use royalties and revenues |  |  |  |  |  |  |  |  |  |  |  |
Surface use royalties |  | $ | 72,772 |  |  |  | 36.6 | % |  | $ | 31,620 |  |  |  | 28.8 | %
Easements and other surface-related revenues |  |  | 62,002 |  |  |  | 31.1 | % |  |  | 34,115 |  |  |  | 31.0 | %
Resource sales and royalties |  |  |  |  |  |  |  |  |  |  |  |
Resource sales |  |  | 24,723 |  |  |  | 12.4 | % |  |  | 15,351 |  |  |  | 14.0 | %
Resource royalties |  |  | 23,027 |  |  |  | 11.6 | % |  |  | 12,841 |  |  |  | 11.7 | %
Oil and gas royalties |  |  | 12,589 |  |  |  | 6.3 | % |  |  | 16,027 |  |  |  | 14.5 | %
Other |  |  | 3,980 |  |  |  | 2.0 | % |  |  | - |  |  |  | 0.0 | %
Total revenue |  | $ | 199,093 |  |  |  | 100.0 | % |  | $ | 109,954 |  |  |  | 100.0 | %

Our revenues depend heavily on our customers’ activities on and around our land and may vary significantly from period to period as a result of the development of new revenue streams, fluctuations in commodity prices, regulatory developments, including policies related to tariffs and international trade, changes in volumes produced on our land and our acquisition strategy. For example, oil and natural gas prices have historically been volatile and highly susceptible to macroeconomic and geopolitical developments. Lower commodity prices may decrease our revenues as customers on and around our land decrease their activity levels in response to low commodity prices. Although we intend to pursue additional opportunities to increase our revenue streams and introduce additional revenue components, including through conventional and renewable power generation and storage projects, water treatment and desalination facilities, fueling stations, digital infrastructure, telecommunication towers and equipment and other opportunities, there can be no assurance that such revenue streams will materially diversify our revenue streams.

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Costs of Conducting our Business

Our costs consist primarily of resource sales-related expenses, other operating and maintenance expenses to maintain our surface acreage and general administrative expenses. Our principal costs are as follows:

Resource Sales-Related Expenses. Resource sales-related expenses are costs incurred for utilization and maintenance of our assets and facilities in the extraction or production of resources available on our land that are sold by us. These costs generally include utilities to operate our facilities and assets and repairs and maintenance expenses related to those assets.

Other Operating and Maintenance Expenses. Operating and maintenance expenses are costs incurred for maintaining our surface acreage and other assets, including field operating overhead and supervision, production taxes, insurance costs, ad valorem and property taxes, and repairs and maintenance expense.

General and Administrative Expenses. General and administrative expenses include a corporate shared services allocation from WaterBridge, directly incurred corporate costs and share-based compensation expense. Corporate shared services generally include the cost of shared management and administrative services. The corporate shared service allocation is based on an approximation of time spent on activities supporting us as well as by underlying business activities. The shared service allocation expense is reimbursed to WaterBridge through the Shared Services Agreement. Direct corporate costs are incurred for dedicated corporate employees, including payroll, benefits and other employment-related expenses, professional services that generally consist of audit, tax, legal and valuation services and expenses for corporate insurance policies.

Prior to the IPO, share-based compensation expense only included expense allocated to us for NDB LLC’s Incentive Unit plan. The NDB Incentive Unit awards were classified as liability awards by NDB LLC and required periodic remeasurement. On July 1, 2024, in accordance with the Division, the holders of the NDB Incentive Units were issued an identical number of LBH Incentive Units. As of the date of the Division, the LBH Incentive Units are the only incentive units attributable and allocated to the Company. The LBH Incentive Units are accounted for as a modification and have been transitioned to equity award accounting and, as such, do not require periodic remeasurements. The share-based compensation for the LBH Incentive Units is fully allocated to the noncontrolling interest as the contractual obligation to satisfy the LBH Incentive Units exists at LandBridge Holdings. Any actual cash expense associated with such LBH Incentive Units is borne solely by LandBridge Holdings and not the Company.

In connection with the IPO, our board of directors adopted the LandBridge Company LLC Long Term Incentive Plan (the “LTIP”). The LTIP allows for the grant of options, share appreciation rights (“SARs”), RSUs, share awards, dividend equivalents, other share-based awards, cash awards, substitute awards or any combination thereof. Under the LTIP, participants have been granted RSUs. Share-based compensation associated with RSUs is allocated between the Company and the noncontrolling interest based on relative ownership. Substantially all share-based compensation is included in general and administrative expense (income) with an immaterial amount included in other operating and maintenance expense on the statements of operations prior to allocation to the noncontrolling interest. Refer to Note 10 — Share-Based Compensation to our consolidated financial statements for additional information regarding share-based compensation.

How We Evaluate Our Operations

We use a variety of financial and operational metrics to assess the performance of our business.

Revenue

Revenue is a key performance metric of our company. We analyze realized monthly, quarterly and annual revenues and compare the results against our internal projections and budgets. Results are used to validate, or when applicable update, existing assumptions on macroeconomic drivers of our business, contractual mix driving average unit-level revenues and E&P customer development activity and commodity pricing, absent the impact of our operating costs.

Surface Use Economic Efficiency

We calculate surface use economic efficiency as (i) total revenues less oil and gas royalty revenues divided by (ii) owned surface acreage. or in periods in which we acquire or dispose of acreage, the weighted average surface acreage owned during the period.This metric provides valuable insight into the effectiveness of our active land management strategy by examining our ability to generate value on our owned surface and track trends of our results over time, while inherently adjusting for any surface acreage acquisitions or divestitures that may occur. Further, we believe this metric serves as a worthwhile benchmark of our team’s management and growth strategy, as well as the relative value of our surface acreage, compared to our peers.

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Adjusted EBITDA and Adjusted EBITDA Margin

Adjusted EBITDA and Adjusted EBITDA Margin are used by our management and by external users of our financial statements, such as investors, research analysts and others, to assess the financial performance of our assets over the long term to generate sufficient cash to return capital to equity holders or service indebtedness. Please read “—Non-GAAP Financial Measures” for reconciliations and additional information regarding these non-GAAP financial measures.

Free Cash Flow and Free Cash Flow Margin

Free Cash Flow and Free Cash Flow Margin are used by our management and by external users of our financial statements, such as investors, research analysts and others, to assess our ability to repay our indebtedness, return capital to our shareholders and fund potential acquisitions without access to external sources of financing for such purposes. We define Free Cash Flow as cash flow from operating activities less investment in capital expenditures. Please read “—N on-GAAP Financial Measures” for reconciliations and additional information regarding these non-GAAP financial measures.

Factors Affecting the Comparability of Our Results of Operations

In this Annual Report, we present our historical results of operations for the years ended December 31, 2025 and 2024. Our future results of operations will not be directly comparable to the historical results of operations of our predecessor for the periods presented as a result of the significant growth of our business and new contracting activity completed during each year of our operation, which are not reflected in our operating results until such contracting activity has been completed. We have also experienced additional significant growth in our business following the completion of our acquisitions, resulting in our future results of operations for periods following the consummation of such acquisitions to not be directly comparable with our historical results.

Public Company Costs

As a result of the IPO during 2024, we incurred incremental, non-recurring costs related to our transition to a publicly traded and taxable entity, including the costs of the IPO and the costs associated with the initial implementation of our Sarbanes-Oxley Act internal controls and testing. We have incurred and expect to continue to incur additional significant and recurring expenses as a publicly traded company, including costs associated with SEC reporting and compliance requirements, consisting of the preparation and filing of annual and quarterly reports, registrar and transfer agent fees, national stock exchange fees, audit fees, legal fees, investor relations expenses, incremental director and officer liability insurance costs and director and officer compensation expenses. These expenses are not included in our results of operations prior to the IPO. Additionally, we have retained additional employees and consultants, including accounting and legal personnel, in order to comply with the requirements of being a publicly traded company.

Corporate Reorganization

During 2024, we were formed to serve as the issuer in the IPO and had no operations, assets or liabilities prior to the consummation of the IPO. Certain of the historical consolidated financial statements included in this Annual Report are based on the financial statements of our accounting predecessor, OpCo, prior to the Corporate Reorganization in connection with the IPO. As a result, the historical consolidated financial data may not give you an accurate indication of what our actual results would have been if the Corporate Reorganization had been completed at the beginning of the periods presented or of what our future results of operations are likely to be.

Long-Term Incentive Plan

In order to incentivize individuals providing services to us or our affiliates, our board of directors adopted a long-term incentive plan (“LTIP”). Any individual who is our officer or employee or an officer or employee of any of our affiliates, and any other person who provides services to us or our affiliates, including our directors, may be eligible to receive awards under the LTIP at the discretion of our board of directors or a committee thereof, as applicable. The LTIP provides for the grant, from time to time, at the discretion of our board of directors, or a committee thereof, of options, share appreciation rights, restricted shares, restricted share units, share awards, dividend equivalents, other share-based awards, cash awards, substitute awards and performance awards intended to align the interests of employees, directors and service providers with those of our shareholders. As such, our historical financial data may not present an accurate indication of what our actual results would have been if we had implemented the LTIP program prior to the periods presented within.

Acquisitions

During 2025, we acquired approximately 42,000 acres, inclusive of approximately 12,000 leasehold acres and approximately 3,600 acres subject to a long-term management agreement, through various acquisitions including the 1918 Ranch Acquisition, which will impact the comparability of our results of operations. Refer to Note 4 — Asset Acquisitions within the notes to our consolidated

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financial statements for further information with respect to such acquisitions. We expect to pursue opportunistic future land acquisitions that compliment or expand our current land position, which may impact the comparability of our results.

## Credit Facilities and Notes

On November 18, 2025, OpCo entered into the 2025 Revolving Credit Facility with available capacity of $275.0 million, which matures on the earlier of (a) June 30, 2030, and (b) the date that is 91 days prior to the stated maturity of the Notes, if, on such date, the outstanding principal amount of the Notes is greater than $50 million.

On November 25, 2025, OpCo issued $500.0 million aggregate principal amount of 6.25% fixed-rate senior unsecured notes due 2030.

Income Taxes

Prior to the IPO, OpCo and its subsidiaries were primarily entities that were treated as partnerships or disregarded entities for federal income tax purposes but were subject to certain minimal Texas franchise taxes. One of our subsidiaries is a qualified REIT for federal income tax purposes. There is no tax imposed on a REIT as long as the REIT complies with the applicable tax rules and avails itself of the opportunity to reduce its taxable income through distributions. A REIT must comply with a number of organizational and operational requirements, including a requirement that it must pay at least 90% of its taxable income to shareholders.

As a result of our predominately non-taxable structure historically, income taxes on taxable income or losses realized by our predecessor, OpCo, were generally the obligation of the individual members or partners. Accordingly, the financial data attributable to our predecessor, OpCo, contains no provision for U.S. federal income taxes or income taxes in any state or locality (other than margin tax in the State of Texas). Following consummation of the IPO, although we are a limited liability company, we have elected to be taxed as a corporation and are subject to U.S. federal, state and local income taxes on our allocable share of the income and loss of OpCo.

Results of Operations

Year Ended December 31, 2025 Compared to the Year Ended December 31, 2024

| Year Ended December 31, |  |  | Variance |
| 2025 |  |  | 2024 |  |  | Amount |  |  | Percent |
Revenues: |  |  |  |  |  |  |  |
Surface use royalties | $ | 72,772 |  |  | $ | 31,620 |  |  | $ | 41,152 |  |  |  | 130 | %
Easements and other surface-related revenues |  | 62,002 |  |  |  | 34,115 |  |  |  | 27,887 |  |  |  | 82 | %
Resource sales |  | 24,723 |  |  |  | 15,351 |  |  |  | 9,372 |  |  |  | 61 | %
Resource royalties |  | 23,027 |  |  |  | 12,841 |  |  |  | 10,186 |  |  |  | 79 | %
Oil and gas royalties |  | 12,589 |  |  |  | 16,027 |  |  |  | (3,438 | ) |  |  | (21 | %)
Other |  | 3,980 |  |  |  | - |  |  |  | 3,980 |  |  |  | 100 | %
Total revenues |  | 199,093 |  |  |  | 109,954 |  |  |  | 89,139 |  |  |  | 81 | %
Resource sales-related expense |  | 2,026 |  |  |  | 2,113 |  |  |  | (87 | ) |  |  | (4 | %)
Other operating and maintenance expense |  | 4,518 |  |  |  | 3,174 |  |  |  | 1,344 |  |  |  | 42 | %
General and administrative expense |  | 62,448 |  |  |  | 112,302 |  |  |  | (49,854 | ) |  |  | (44 | %)
Depreciation, depletion and amortization |  | 11,470 |  |  |  | 8,875 |  |  |  | 2,595 |  |  |  | 29 | %
Other operating expense, net |  | 131 |  |  |  | - |  |  |  | 131 |  |  |  | 100 | %
Operating income (loss) |  | 118,500 |  |  |  | (16,510 | ) |  |  | 135,010 |  |  |  | 818 | %
Interest expense, net |  | 32,706 |  |  |  | 23,335 |  |  |  | 9,371 |  |  |  | 40 | %
Other income (loss) |  | 4,329 |  |  |  | (241 | ) |  |  | 4,570 |  |  |  | 1896 | %
Income (loss) from operations before taxes |  | 81,465 |  |  |  | (39,604 | ) |  |  | 121,069 |  |  |  | 306 | %
Income tax expense |  | 9,066 |  |  |  | 1,875 |  |  |  | 7,191 |  |  |  | 384 | %
Net income (loss) | $ | 72,399 |  |  | $ | (41,479 | ) |  | $ | 113,878 |  |  |  | 275 | %

Total revenues. Total revenues increased by $89.1 million. Please see our discussion below regarding the comparative period variances in revenue sources.

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Surface use royalties. Surface use royalties increased by $41.2 million. The increase was primarily attributable to increased produced water handling and associated skim oil royalties of $40.1 million and solid waste disposal and reclamation royalties of $1.1 million on our surface for the year ended December 31, 2025, as compared to the year ended December 31, 2024. The increase in produced water handling and skim oil royalties was primarily attributable to a significant increase in produced water handling volume of approximately 845 Mbbl/d. The volume and associated revenue increase was attributable to our 2024 Acquisitions coupled with organic growth on our Legacy Acreage.

Easements and other surface-related revenues. Easements and other surface-related revenues increased by $27.9 million. The increase was primarily attributable to oil and natural gas gathering and transportation pipelines and produced water handling infrastructure of $16.8 million, $5.2 million related to road easements, $3.9 million related to surface and subsurface drilling location easements, and $2.0 million in other surface easements and agreements.

Resource sales. Resource sales increased by $9.4 million. Brackish water sales increased $6.3 million for the year ended December 31, 2025, as compared to the year ended December 31, 2024. Brackish water sales volume increased by 10.4 million barrels, or 30%, to 44.6 million barrels for the year ended December 31, 2025, as compared to 34.2 million barrels for the year ended December 31, 2024. partially offset by a per unit sales price decreased of approximately 12%, primarily driven by the customer contract mix for the year ended December 31, 2025, as compared to the year ended December 31, 2024. Caliche sales increased $3.1 million for the same comparative period, primarily due to construction of energy infrastructure in the areas surrounding our surface acreage.

Resource royalties. Resource royalties increased by $10.2 million. The increase was primarily attributable to brackish water royalties of $8.7 million as a result of the closing of the East Stateline Ranch Acquisition in the second quarter of 2024 and the Wolf Bone Ranch Acquisition in the fourth quarter of 2024. Additionally, sand mine royalties increased $1.5 million primarily related to higher throughput volumes.

Oil and gas royalties. Oil and gas royalties decreased by $3.4 million The decrease was primarily attributable to lower net royalty volumes of $1.9 million resulting from natural production decline and $1.2 million attributable to lower realized commodity prices, primarily declining oil price. Additionally, mineral lease bonus payments decreased $0.3 million.

The table below provides operational and financial data by oil and gas royalty stream for the periods indicated.

| Year Ended December 31, |
| 2025 |  |  | 2024 |
Net royalty volumes: |  |  |  |  |
Oil (MBbls) |  | 156 |  |  |  | 179 |
Natural Gas (MMcf) |  | 656 |  |  |  | 729 |
NGL (MBbls) |  | 66 |  |  |  | 77 |
Equivalents (MBoe) |  | 331 |  |  |  | 378 |
Equivalents (MBoe/d) |  | 0.9 |  |  |  | 1.0 |
Oil and gas royalties (in thousands): |  |  |  |  |
Oil royalties | $ | 9,940 |  |  | $ | 13,346 |
Natural gas royalties |  | 1,270 |  |  |  | 665 |
NGL royalties |  | 1,315 |  |  |  | 1,610 |
Oil and gas royalties |  | 12,525 |  |  |  | 15,621 |
Mineral lease income |  | 64 |  |  |  | 406 |
Total oil and gas royalties | $ | 12,589 |  |  | $ | 16,027 |
Realized prices |  |  |  |  |
Oil ($/Bbl) | $ | 63.72 |  |  | $ | 74.56 |
Natural gas ($/Mcf) | $ | 1.94 |  |  | $ | 0.91 |
NGL ($/Bbl) | $ | 19.92 |  |  | $ | 20.91 |
Equivalents ($/Boe) | $ | 37.84 |  |  | $ | 41.33 |

Other revenue. Other revenue increased by $4.0 million. This increase was attributable to deficiencies recognized under minimum revenue contracts.

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| Year Ended December 31, |  |  | Variance |
| 2025 |  |  | 2024 |  |  | Amount |  |  | Percent |
General and administrative expense: |  |  |  |  |  |  |  |  |  |  |
General and administrative expense, excluding share-based compensation | $ | 17,374 |  |  | $ | 17,079 |  |  | $ | 295 |  |  |  | 2 | %
Share-based compensation |  | 45,074 |  |  |  | 95,223 |  |  |  | (50,149 | ) |  |  | (53 | %)
Total general and administrative expense | $ | 62,448 |  |  | $ | 112,302 |  |  | $ | (49,854 | ) |  |  | (44 | %)

General and administrative expense, inclusive of share-based compensation, decreased by $49.9 million. The decrease was primarily attributable to the change in share-based compensation expense of $50.1 million, which consists of a decrease related to the incentive units of $54.8 million, partially offset by an increase of $4.8 million related to the issuance of RSUs. The incentive units expense decrease is primarily due to the periodic remeasurements of NDB Incentive Units prior to the Division of $72.6 million in 2024 when the awards were accounted for as liability awards at NDB LLC. This was offset by an increase in incentive unit expense related to new issuances and post-modification equity award accounting amortization of $36.5 million for the year ended December 31, 2025, as compared to $18.7 million for the year ended December 31, 2024. Refer to Note 10 — Share-Based Compensation within the notes to our consolidated financial statements included elsewhere in this Annual Report.

Depreciation, depletion and amortization. Depreciation, depletion and amortization increased by $2.6 million. The increase was primarily attributable to amortization of intangibles acquired in the 2024 and 2025 acquisitions. Refer to Note 6 — Intangible Assets within the notes to our consolidated financial statements included elsewhere in this Annual Report.

| Year Ended December 31, |  |  | Variance |
| 2025 |  |  | 2024 |  |  | Amount |  |  | Percent |
Interest on credit facilities | $ | 30,469 |  |  | $ | 21,907 |  |  | $ | 8,562 |  |  |  | 39 | %
Debt issuance costs amortization and write offs |  | 2,189 |  |  |  | 1,688 |  |  |  | 501 |  |  |  | 30 | %
Interest on other |  | 48 |  |  |  | 42 |  |  |  | 6 |  |  |  | 14 | %
Total interest expense |  | 32,706 |  |  |  | 23,637 |  |  |  | 9,069 |  |  |  | 38 | %
Interest expense (income), net |  | - |  |  |  | (302 | ) |  |  | 302 |  |  |  | (100 | %)
Total interest expense, net | $ | 32,706 |  |  | $ | 23,335 |  |  | $ | 9,371 |  |  |  | 40 | %

Interest expense, net. Interest expense, net, increased by $9.4 million. The increase was primarily attributable to a higher weighted average debt balance during the year ended December 31, 2025, as compared to borrowings under our then-existing debt instruments for the year ended December 31, 2024. See “— Liquidity and Capital Resources” for additional information regarding the Company’s debt instruments and interest expense.

Other income (loss). Other income (loss) increased by $4.6 million. The increase was primarily attributable to the loss on extinguishment of the 2023 Credit Agreement in November 2025.

Income tax expense. Income tax expense increased by $7.2 million. The increase was attributable to higher taxable income in 2025 due to a full year as a taxable entity.

Non-GAAP Financial Measures

Adjusted EBITDA, Adjusted EBITDA Margin, Free Cash Flow and Free Cash Flow Margin are supplemental non-GAAP measures that we use to evaluate current, past and expected future performance. We define Adjusted EBITDA as net income (loss) before interest; taxes; depreciation, depletion and amortization; share-based compensation; non-recurring transaction-related expenses and other non-cash or non-recurring expenses. We define Adjusted EBITDA Margin as Adjusted EBITDA divided by total revenues. Although these non-GAAP financial measures are important factors in assessing our operating results and cash flows, they should not be considered in isolation or as a substitute for net income or gross margin or any other measures presented under GAAP.

Management believes Adjusted EBITDA and Adjusted EBITDA Margin are useful because they allow us to more effectively evaluate our operating performance and compare the results of our operations from period to period, and against our peers, without regard to our financing methods or capital structure. We exclude the items listed below from net income (loss) in arriving at Adjusted EBITDA and Adjusted EBITDA Margin because these amounts can vary substantially from company to company within our industry depending upon accounting methods, book values of assets, capital structures and the method by which the assets were acquired.

Management believes Free Cash Flow and Free Cash Flow Margin are useful because they allow for an effective evaluation of both our operating and financial performance, as well as the capital intensity of our business, and subsequently the ability of our operations to generate cash flow that is available to distribute to our shareholders, reduce leverage or support acquisition activities. We define

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Free Cash Flow as cash flow from operating activities less investment in capital expenditures. We define Free Cash Flow Margin as Free Cash Flow divided by total revenues.

Adjusted EBITDA and Adjusted EBITDA Margin

The following table sets forth a reconciliation of net income as determined in accordance with GAAP to Adjusted EBITDA and Adjusted EBITDA Margin for the periods indicated.

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |
Net income (loss) |  | $ | 72,399 |  |  | $ | (41,479 | )
Adjustments: |  |  |  |  |  |
Depreciation, depletion and amortization |  |  | 11,470 |  |  |  | 8,875 |
Interest expense, net |  |  | 32,706 |  |  |  | 23,335 |
Income tax expense |  |  | 9,066 |  |  |  | 1,875 |
EBITDA |  |  | 125,641 |  |  |  | (7,394 | )
Adjustments: |  |  |  |  |  |
Share-based compensation - Incentive Units (1) |  |  | 36,508 |  |  |  | 91,307 |
Share-based compensation - RSUs |  |  | 8,811 |  |  |  | 4,028 |
Transaction-related expenses (2) |  |  | 5,955 |  |  |  | 1,266 |
Non-recurring expenses (3) |  |  | - |  |  |  | 7,825 |
Other |  |  | 256 |  |  |  | 37 |
Adjusted EBITDA |  | $ | 177,171 |  |  | $ | 97,069 |
Net income (loss) margin |  |  | 36 | % |  |  | (38 | %)
Adjusted EBITDA Margin |  |  | 89 | % |  |  | 88 | %

(1)
Share-based compensation - Incentive Units for the year ended December 31, 2025, consists only of LBH Incentive Units. Share-based compensation - Incentive Units for the year ended December 31, 2024, consists of $18.7 million related to the LBH Incentive Units, and $72.6 million related to the NDB Incentive Units. NDB Incentive Units were liability awards resulting in periodic fair value remeasurement prior to the Division. Subsequent to the IPO, any actual cash expense associated with the LBH Incentive Units is borne solely by LandBridge Holdings and not the Company. Distributions attributable to LBH Incentive Units are based on returns received by investors of LandBridge Holdings once certain return thresholds have been met and are neither an obligation of the Company nor taken into consideration for distributions to investors in the Company.
(2)
Transaction-related expenses for the year ended December 31, 2025, consist of $4.9 million resulting from debt amendments and extinguishments, $0.8 million related to LandBridge Holdings redemption of 2,500,000 OpCo Units (together with a cancellation of a corresponding number of Class B shares), for an equivalent amount of Class A shares and $0.4 million of other transaction-related costs. For the year ended December 31, 2024, transaction-related expenses consisted of $0.4 million resulting from debt amendments, $0.3 million of entity structuring, $0.2 million of non-capitalizable IPO-related charges and $0.2 million of other transaction-related costs.
(3)
Non-recurring expenses for the year ended December 31, 2024 consists primarily of $5.0 million in IPO-related employee bonuses and $2.6 million related to a contract termination payment.

Free Cash Flow and Free Cash Flow Margin

The following table sets forth a reconciliation of cash flows from operating activities determined in accordance with GAAP to Free Cash Flow and Free Cash Flow Margin, respectively, for the periods indicated.

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |
Net cash provided by operating activities |  | $ | 126,273 |  |  | $ | 67,636 |
Net cash used in investing activities |  |  | (233,074 | ) |  |  | (724,352 | )
Cash used in operating and investing activities |  |  | (106,801 | ) |  |  | (656,716 | )
Adjustments: |  |  |  |  |  |
Acquisitions |  |  | 229,048 |  |  |  | 723,367 |
Proceeds from disposal of assets |  |  | (210 | ) |  |  | - |
Free Cash Flow |  | $ | 122,037 |  |  | $ | 66,651 |
Operating cash flow margin (1) |  |  | 63 | % |  |  | 62 | %
Free Cash Flow Margin |  |  | 61 | % |  |  | 61 | %

(1)
Operating cash flow margin is calculated by dividing net cash provided by operating activities by total revenue.

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Liquidity and Capital Resources

Overview

Historically, our primary sources of liquidity have been capital contributions from our financial sponsor, cash flows from operating activities and borrowings under our debt instruments. Following the completion of the IPO, our primary sources of liquidity are cash flows from operating activities and, if required, proceeds from borrowings under our revolving credit facility. Our primary liquidity and capital requirements will be for our operating expenses, servicing of our debt, the payment of dividends to our shareholders, general company needs and investing in our business, including the potential acquisition of additional surface acreage. Although we believe that we will be able to partially or fully fund our short-term and long-term capital expenditures, working capital requirements and other capital needs with cash on hand and cash flows from operating activities, we may elect to use borrowings under our revolving credit facility to finance our operating and investing activities. See “— Debt Instruments — Credit Facility.”

We strive to maintain financial flexibility and proactively monitor potential capital sources, including equity and debt financing, to meet our target liquidity and capital requirements. If market conditions were to change and our revenues were to decline significantly or operating costs were to increase, our cash flows and liquidity could be reduced and we could be required to seek alternative financing sources. As of December 31, 2025, we had working capital, defined as current assets less current liabilities, of $47.5 million and we had cash and cash equivalents of $30.7 million. As of December 31, 2024, we had working capital of $38.9 million and cash and cash equivalents of $37.0 million.

Dividends and Distributions

(in thousands, except for per share amounts) Cash Dividends | Date of Record |  | Dividends Paid to Class A Shareholders |  |  | Distributions Paid to OpCo Unitholders |  |  | Rate Per Share |
First Quarter | March 6, 2025 |  | $ | 2,326 |  |  | $ | 5,319 |  |  | $ | 0.10 |
Second Quarter | June 5, 2025 |  | $ | 2,515 |  |  | $ | 5,124 |  |  | $ | 0.10 |
Third Quarter | September 4, 2025 |  | $ | 2,534 |  |  | $ | 5,121 |  |  | $ | 0.10 |
Fourth Quarter | December 4, 2025 |  | $ | 2,784 |  |  | $ | 4,925 |  |  | $ | 0.10 |

On February 24, 2026, our board of directors declared a dividend on our Class A shares of $0.12 per share, payable on March 19, 2026 to shareholders of record as of March 5, 2026, and a corresponding required cash distribution to OpCo unitholders.

On February 24, 2026, our board of directors approved a payment for tax distributions from OpCo to LandBridge Holdings in the amount of $5.3 million. This amount is inclusive of LandBridge Holdings pro rata share of estimated federal income tax to be distributed from OpCo to the Company and an additional tax distribution in excess of the Company’s then-current income tax obligation as provided for under the OpCo LLC Agreement. This amount is expected to be paid during the first quarter of 2026.

Cash Flow

The following tables summarizes our cash flow for the periods indicated:

Year Ended December 31, 2025 Compared to the Year Ended December 31, 2024

| Year Ended December 31, |  |  | Variance |
| 2025 |  |  | 2024 |  |  | Amount |  |  | Percent |
Consolidated Statement of Cash Flow Data: |  |  |  |  |  |  |  |  |  |  |
Net cash provided by operating activities | $ | 126,273 |  |  | $ | 67,636 |  |  | $ | 58,637 |  |  |  | 87 | %
Net cash used in investing activities |  | (233,074 | ) |  |  | (724,352 | ) |  |  | (491,278 | ) |  |  | (68 | %)
Net cash provided by financing activities |  | 100,510 |  |  |  | 655,925 |  |  |  | (555,415 | ) |  |  | (85 | %)
Net decrease in cash and cash equivalents | $ | (6,291 | ) |  | $ | (791 | ) |  | $ | (5,500 | ) |  |  | (695 | %)

Net Cash Provided by Operating Activities. Net cash provided by operating activities increased $58.6 million. The increase was attributable to higher net income, net of non-cash items, of $75.9 million, partially offset by a decrease in cash flow related to working capital accounts of $17.2 million. The increase in net income, net of non-cash items, is primarily attributable to revenue growth related

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to continued commercialization of acreage, including land acquired during 2024. The decrease in cash flow from working capital accounts is primarily attributable to higher accounts receivable related to growth in our revenues, and federal tax payments related to the 2025 tax year. Please see “—Results of Operations” for more information regarding analysis of our consolidated statements of operations.

Net Cash Used in Investing Activities. Net cash used in investing activities decreased $491.3 million. The decrease was primarily attributable to lower acquisition-related expenditures of $229.0 million for the year ended December 31, 2025, as compared to $723.4 million during the year ended December 31, 2024. Please refer to Note 4 — Asset Acquisitions of our Notes to the Consolidated Financial Statements for more information on acquisitions completed in 2024 and 2025.

Net Cash Provided by (Used In) Financing Activities. Net cash provided by financing activities decreased $555.4 million. For the year ended December 31, 2025, cash provided by financing activities primarily consisted of $171.1 million of debt borrowings, net of repayments and debt issuance costs, partially offset by $63.7 million of dividends, dividend equivalents and distributions paid to shareholders, $5.8 million of required tax withholding related to the net settlement of Class A shares, and $1.1 million of offering costs paid related to the December 2024 private placement. For the year ended December 31, 2024, cash provided by financing activities consisted of $609.4 million of net proceeds from the IPO and December 2024 private placement and $250.2 million of debt borrowings, net of repayments and debt issuance costs, primarily used to fund acquisitions during the year, partially offset by the purchase of OpCo Units from LandBridge Holdings of $145.4 million and $58.2 million of dividends and distributions paid, net of contributions.

Capital Requirements

We focus our business model on entering into agreements under which our customers bear substantially all of the operating and capital expenditures related to their operations on our land, while minimizing our capital requirements for both current and future commercial opportunities, resulting in the ability to create significant free cash flows. Our contracts generally include inflation escalators, which, when combined with our relatively low operating and capital expenditures, may assist in mitigating our exposure to broader inflationary pressures. As a landowner, we incur the initial cost to acquire our acreage, but thereafter we incur modest development capital expenditures and operating expenses as it relates to operations on our land or our mineral and royalty interests, as such expenses are borne primarily by our customers. As a result, we expect that additional significant capital expenditures would be related to our acquisition of additional surface acreage, should we elect to do so.

The amount and allocation of future acquisition-related capital expenditures will depend upon a number of factors, including the size of the acquisition opportunity, our cash flows from operating activities and our investing and financing activities. For the years ended December 31, 2025 and 2024, we incurred $229.0 million and $723.4 million in acquisition-related capital expenditures, inclusive of $2.3 million and $3.1 million of transaction-related expenses, respectively.

We periodically assess changes in current and projected cash flows, acquisition and divestiture activities and other factors to determine the effects on our liquidity. We believe that our cash on hand and cash flow from operating activities will provide us with sufficient liquidity to execute our current strategy. However, our ability to generate cash is subject to a number of factors that may directly or indirectly affect us, many of which are beyond our control, including commodity prices and general economic, financial, competitive, legislative, regulatory and other factors. If we require additional capital for acquisitions or other reasons, we may seek such capital through traditional borrowings under our debt instruments, offerings of debt and equity securities or other means. If we are unable to obtain funds when needed or on acceptable terms, we may not be able to complete acquisitions that may be favorable to us.

As our board of directors declares cash dividends to our Class A shareholders, we expect the dividend to be paid from Free Cash Flow. We do not currently expect to borrow funds or to adjust planned capital expenditures to finance dividends on our Class A shares. The timing, amount and financing of dividends, if any, will be subject to the discretion of our board of directors from time to time. See “Dividend Policy.”

Debt Instruments

## Notes

On November 25, 2025, OpCo issued $500.0 million aggregate principal amount of 6.25% fixed-rate senior unsecured notes due 2030 (the “Notes”).

In connection with the offering of the Notes, OpCo and each of the Guarantors (as defined below) entered into the indenture, with UMB Bank, N.A., as trustee, relating to the issuance of the Notes (the “Indenture”). The Indenture contains customary terms, events of default and covenants relating to, among other things, the incurrence of debt, the payment of dividends or similar restricted payments, undertaking transactions with OpCo’s unrestricted affiliates, and limitations on asset sales.

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The Notes are guaranteed (the “Guarantees”), jointly and severally, on a senior unsecured basis by all of OpCo’s existing subsidiaries (collectively, the “Guarantors”).

At any time prior to December 1, 2027, OpCo may on any one or more occasions redeem up to 40% of the aggregate principal amount of the Notes (including any additional notes) issued under the Indenture at a redemption price equal to 106.25% of the principal amount of the Notes redeemed, plus accrued and unpaid interest, if any, to, but excluding, the redemption date, with an amount of cash not greater than the net cash proceeds of one or more equity offerings. At any time after December 1, 2027, OpCo may also redeem all or a part of the Notes of such series at a redemption price equal to 100% of the principal amount of the Notes redeemed plus the applicable premium set forth in the Indenture, plus accrued and unpaid interest, if any, to, but excluding, the redemption date.

If a Change of Control (as defined in the Indenture) occurs (along with a downgrade of the Notes by two rating agencies), OpCo may be required to offer to purchase the Notes at a purchase price equal to 101% of the principal amount, plus accrued and unpaid interest, if any, to the purchase date.

The Notes and the Guarantees rank equally in right of payment with all of OpCo’s and the Guarantors’ existing and future senior indebtedness and senior to all of OpCo’s and the Guarantors’ future subordinated indebtedness. The Notes and the Guarantees are effectively subordinated in right of payment to all of OpCo’s and the Guarantors’ existing and future secured debt, including debt under the 2025 Revolving Credit Facility, to the extent of the value of the assets securing such debt, and will be structurally subordinated to all liabilities of any future subsidiaries of OpCo that do not guarantee the Notes.

On November 25, 2025, the Company used the net proceeds of $491.9 million from the issuance of the Notes, $70.0 million of borrowings under the 2025 Revolving Credit Facility, and $4.8 million of cash on hand to repay all outstanding borrowings and accrued interest under the 2023 Credit Agreement (defined below). At the time of repayment, the outstanding borrowings and accrued interest under the 2023 Credit Agreement totaled $564.5 million. The remaining proceeds were used to pay $2.1 million of offering expenses.

At December 31, 2025, our fixed-rate senior unsecured notes had a gross principal amount of $500.0 million and a fair value of $506.9 million. The fair value was determined based on observable market prices of identical instruments in less active markets and is categorized accordingly as Level 2 in the fair value hierarchy.

2025 Revolving Credit Facility

On November 18, 2025, OpCo entered into the 2025 Revolving Credit Facility, a revolving credit facility with available capacity of $275.0 million that matures on the earlier of (a) June 30, 2030, and (b) the date that is 91 days prior to the stated maturity of the Notes, if, on such date, the outstanding principal amount of the Notes is greater than $50 million (the “Maturity Date”). Borrowings under the 2025 Revolving Credit Facility are secured by a first-priority lien on substantially all assets of OpCo and its subsidiaries, and is also guaranteed by each of its subsidiaries.

The 2025 Revolving Credit Facility provides for revolving borrowings subject to compliance with certain financial and other covenants common in such agreements that apply to OpCo and its restricted subsidiaries including (i) a minimum interest coverage ratio of 2.50:1.00, (ii) a maximum total net leverage ratio of 5.00:1.00, provided that the maximum total net leverage ratio may step up to 5.25:1.00 for the fiscal quarter in which a Permitted Acquisition (as defined in the 2025 Revolving Credit Facility) occurs and the two fiscal quarters following, and (iii) a maximum senior secured net leverage ratio of 3.50:1.00, in each case,measured as of the end of each fiscal quarter.

These covenants are subject to exceptions and qualifications provided in the 2025 Revolving Credit Facility, including the ability to make unlimited restricted payments subject to (i) a maximum net total leverage ratio of less than 4.50:1.00, (ii) minimum liquidity of 5% (with “liquidity” including unrestricted cash on hand of OpCo and its subsidiaries plus availability under the 2025 Revolving Credit Facility), and (iii) such other restricted payments customarily permitted for publicly traded companies with a similar market capitalization as the Company.

Principal amounts borrowed under the 2025 Revolving Credit Facility may be prepaid from time to time and commitments thereunder may be terminated without premium or penalty. Any principal amounts outstanding on the maturity date will become due and payable on such date.

At OpCo’s election, principal amounts under the 2025 Revolving Credit Facility may be borrowed as Term SOFR Loans or Base Rate Loans. Term SOFR Loans under the Credit Agreement bear interest at a variable rate equal to Term SOFR for the applicable tenor plus a leverage-based applicable margin between 2.00% and 3.00% per annum. Interest on all outstanding Term SOFR Loans is payable on the last business day of the applicable interest period. Base Rate Loans under the 2025 Revolving Credit Facility bear interest at a rate per annum equal to (x) the highest of (i) the rate of interest published by The Wall Street Journal, (ii) the Federal Funds Rate, as in effect from time to time, plus 0.50%, and (iii) Term SOFR for a one-month tenor plus 1.00%, in each case plus a

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leverage-based applicable margin between 1.00% and 2.00% per annum. Interest on all outstanding Base Rate Loans shall be payable quarterly in arrears. OpCo will also pay a commitment fee based on the applicable percentage of undrawn commitment amounts under the 2025 Revolving Credit Facility.

The estimated fair value of our credit facility approximates the principal amount outstanding because the interest rates are variable and reflective of market rates and the debt may be repaid, in full or in part, at any time without penalty.

As of December 31, 2025, we had $70.0 million of borrowings under the 2025 Revolving Credit Facility. The weighted average interest rate on the total amount of borrowings outstanding under 2025 Revolving Credit Facility for the twelve months ended December 31, 2025 was 6.13%. We are currently in compliance with all affirmative and negative covenants under the 2025 Revolving Credit Facility.

Prior Agreements

Prior to the closing of the Notes offering, certain of our subsidiaries were parties to the long-term debt agreements described below.

2023 Credit Agreement

On July 3, 2023, DBR Land, LLC, a Delaware limited liability company and a subsidiary of the Company (the “Borrower”) entered into a credit agreement (as amended prior to the date hereof, the “2023 Credit Agreement”) with the guarantors party thereto, the lenders party thereto, and Texas Capital Bank, as administrative agent and letter of credit issuer (the“Administrative Agent”), which initially provided for (i) a four-year $100.0 million term loan and (ii) a $50.0 million revolving credit facility, each of which matures on July 3, 2027. We subsequently amended to, among other things, increase the principal amount of the term loan to $355.0 million and increase the available capacity of the revolving credit facility to $100.0 million.

On October 3, 2025 (the “Third Amendment Effective Date”), the Borrower, entered into the Third Amendment to Credit Agreement (the “Third Amendment”) , to amend the 2023 Credit Agreement and provide for a new delayed draw term loan facility with total commitments of $200.0 million for the purpose of partially financing the 1918 Ranch Acquisition and to pay certain related costs and expenses (the “DDTL Facility”). On November 10, 2025, the Borrower drew in full the $200.0 million available under the DDTL Facility to partially fund the1918 Ranch Acquisition and pay certain related expenses. The DDTL Facility included an unused commitment fee of 37.5 basis points that accrued from the Third Amendment Effective Date until November 10, 2025, applied to the average daily unused amount of the DDTL Facility.

Under the 2023 Credit Agreement, the Borrower could elect for outstanding borrowings under our credit facility to accrue interest at a rate based on either (i) a forward-looking term rate based on the secured overnight financing rate (“Term SOFR”) plus 0.10%, or (ii) the base rate, in each case plus an applicable margin. Borrowings under the 2023 Credit Agreement accrued interest based on a five-tiered pricing grid tied to our current leverage ratio. The applicable margin ranged from (i) prior to the consummation of the IPO, 3.00% to 4.00% in the case of Term SOFR loans and letter of credit fees, and 2.00% to 3.00% in the case of base rate loans, and commitments fees of 0.50%, and (ii) following consummation of the IPO, 2.75% to 3.75% in the case of Term SOFR loans and letter of credit fees, and 1.75% to 2.75% in the case of base rate loans, and commitment fees ranged from 0.375% to 0.50%.

The 2023 Credit Agreement was terminated on November 25, 2025 in connection with the effectiveness of the Notes and 2025 Revolving Credit Facility.

Share Repurchase Program

On February 24, 2026, our board of directors approved a share repurchase program. The program permits the repurchase of up to $50 million of the Company’s Class A shares through December 2027. The shares may be repurchased from time to time in open market transactions, block trades, accelerated share repurchases, or privately negotiated transactions or by any combination of such methods. The timing, as well as the number and value of shares repurchased under the program, will be determined by the Company at its discretion and will depend on a variety of factors, including management’s assessment of the intrinsic value of the Company’s Class A shares, the market price of the Company's Class A shares, general market and economic conditions, available liquidity, compliance with the Company's debt and other agreements, applicable legal requirements, and other considerations. The Company is not obligated to purchase any shares under the share repurchase program, and the program may be suspended, modified, or discontinued at any time without prior notice.

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Critical Accounting Estimates

The preparation of our Consolidated Financial Statements in conformity with U.S. GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Consolidated Financial Statements. We consider our critical accounting estimates those that require subjectivity and that could inherently influence our financial result based on changes in those estimates. Our significant accounting policies are discussed in Note 2 — Summary of Significant Accounting Policies of our Notes to the Consolidated Financial Statements.

Acquisitions

Determining the fair value of assets acquired and liabilities assumed in asset acquisitions requires judgment and estimates, including the selection of valuation methodologies, estimates of future revenue, costs and cash flows, discount rates, and selection of comparable companies. The judgments made in determining the relative fair value allocated to tangible and intangible assets acquired and the liabilities assumed, as well as asset lives, can materially impact our results of operations.

Recently Issued Accounting Standards

For a summary of recently issued accounting standards, refer to Note 2 — Summary of Significant Accounting Policies of our Notes to the Consolidated Financial Statements.

Off Balance Sheet Arrangements

We currently have no off-balance sheet arrangements.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

We are exposed to market risks, which include the effects of adverse changes in commodity prices and counterparty and customer credit risks and interest rate risk as described below. The primary objective of the following information is to provide quantitative and qualitative information about our potential exposure to market risks. The term “market risk” refers to the risk of loss arising from adverse changes in commodity prices and counterparty and customer credit and interest rate risk. The disclosures are not meant to be precise indicators of expected future losses, but rather indicators of reasonably possible losses. This forward-looking information provides indicators of how we view and manage our ongoing market risk exposures.

Commodity Price Risks

One of our major market risk exposures relates to the prices that our customers receive for the oil and natural gas produced from, or serviced on, our land. The market for the use of our land and its resources is indirectly exposed to fluctuations in the price of oil and natural gas, to the extent such fluctuations impact drilling, completion and production activity levels and thus impact the activity levels of our customers in the exploration and production and oilfield services industries. Realized prices are primarily driven by the prevailing prices for oil and natural gas in the United States. We are also directly exposed to these risks with respect to revenues we receive from the oil and natural gas interests. Pricing for oil and natural gas has been historically volatile and unpredictable, and we expect this volatility to continue in the future.

During the past five years, the Henry Hub spot market price for natural gas has ranged from a low of $1.21 per MMBtu in November 2024 to a high of $23.86 per MMBtu in February 2021. The posted price for WTI has ranged from a low of $47.47 per barrel in January 2021 to a high of $123.64 per barrel in March 2022. As of December 31, 2025, the Henry Hub spot market price of natural gas was $4.00 per MMBtu and the posted price for oil was $57.26 per barrel. Lower prices may not only decrease our revenues, but also potentially the amount of oil and natural gas that our customers can produce or service economically. We expect this market will continue to be volatile in the future. A substantial or extended decline in commodity prices may adversely affect our results of operations, cash flows and financial position.

We do not currently intend to hedge our indirect exposure to commodity price risk. We may in the future enter into derivative instruments, such as collars, swaps and basis swaps, to partially mitigate the impact of commodity price volatility. These hedging instruments would allow us to reduce, but not eliminate, the potential effects of the variability in cash flow from operations due to fluctuations in oil and natural gas prices.

Market Risks

Demand for the use of land and resources are largely dependent upon the level of activity in the energy industry in the Permian Basin. These activity levels are influenced by numerous factors over which we have no control, including: the supply of and demand for oil and natural gas; the level of prices and expectations about future prices of oil and natural gas; the cost of exploring for, developing, producing and delivering oil and natural gas; the expected rates of declining current production; the discovery rates of new oil and

76

natural gas reserves; available pipeline, rail and other transportation capacity; weather conditions; domestic and worldwide economic conditions; political instability domestically, as a result of the recent elections or otherwise, and in oil-producing countries; environmental regulations; technical advances affecting energy consumption; the transition to a low-carbon economy; the price and availability of alternative fuels; technological advancements in the production of alternative energy; the ability of energy companies to raise equity capital and debt financing; and industry consolidation and merger and divestiture activity among energy companies.

The level of U.S. energy production, including oil and natural gas development activity, is volatile. Any prolonged and substantial reduction in oil and natural gas prices would likely affect development and production activity levels and therefore affect demand for oil and natural gas and the use of our land and resources. A material decline in energy, including oil and natural gas, prices or Permian Basin activity levels could have an adverse effect on our results of operations, cash flows and financial position.

Counterparty and Customer Credit Risks

We are subject to risks of loss resulting from nonpayment or nonperformance by our counter-parties and customers of their contractual obligations. Our principal exposure to credit risk is through receivables generated by the activities of customers on our land. The inability or failure of our significant customers to meet their obligations to us or their insolvency or liquidation may adversely affect our financial results. We examine the creditworthiness of any counterparty and customer and monitor our exposure to such counter-parties and customers through credit analysis, and monitoring procedures, including reviewing credit ratings, financial statements and payment history. For the year ended December 31, 2025, three customers accounted for 25%, 12% and 10% of our total revenues, respectively. For the year ended December 31, 2024, three customers accounted for 24%, 14% and 10% of our total revenues, respectively. No other customer accounted for more than 10% of total revenues. However, we believe that the credit risk associated with our counterparties and customers is acceptable.

Interest Rate Risks

Our ability to borrow and the rates offered by lenders can be adversely affected by deterioration in the credit markets and/or deterioration of our credit profile rating. We may elect for outstanding borrowings under the 2025 Revolving Credit Facility to accrue interest at a rate based on either the Term SOFR, or the base rate, plus an applicable margin, which exposes us to interest rate risk to the extent we have borrowings outstanding under the 2025 Revolving Credit Facility.

As of December 31, 2025, we had $70.0 million of borrowings under the 2025 Revolving Credit Facility. We are obligated to pay interest at variable rates and other customary fees on borrowings under this facility. Assuming no change in the amount outstanding, the impact on interest expense of a 1.0% increase or decrease in the weighted average interest rate would be $0.7 million per year. We do not currently have or intend to enter into any derivative hedge contracts to protect against fluctuations in interest rates applicable to our outstanding indebtedness.

As of December 31, 2025, we also had aggregate principal amounts outstanding of $500.0 million under the Notes. Since our Notes bear interest at fixed rates and are carried at amortized cost, fluctuations in interest rates do not have any impact on our consolidated financial statements. However, the fair value of the Notes will fluctuate with movements in market interest rates, increasing in periods of declining interest rates and declining in periods of increasing interest rates.

See “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources—Debt Instruments” for more information.

77

Item 8. Financial Statements and Supplementary Data

INDEX TO CONSOLIDATED FINANCIAL STATEMENTS

Report of Independent Registered Public Accounting Firm (PCAOB ID Number 34)

Consolidated Balance Sheets as of December 31, 2025 and 2024

Consolidated Statements of Operations for the Years Ended December 31, 2025, 2024 and 2023

Consolidated Statements of Shareholders’ and Member's Equity for the Years Ended December 31, 2025, 2024 and 2023

Consolidated Statements of Cash Flows for the Years Ended December 31, 2025, 2024 and 2023

Notes to Consolidated Financial Statements

Note 1. Organization and Nature of Operations

Note 2. Summary of Significant Accounting Policies

Note 3. Additional Financial Statement Information

Note 4. Asset Acquisitions

Note 5. Property, Plant and Equipment

Note 6. Intangible Assets

Note 7. Income Taxes

Note 8. Debt

Note 9. Shareholders’ and Member’s Equity

Note 10. Share-Based Compensation

Note 11. Earnings Per Share

Note 12. Related Party Transactions

Note 13. Commitments and Contingencies

Note 14. Subsequent Events

78

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the shareholders and the Board of Directors of LandBridge Company LLC

Opinion on the Financial Statements

We have audited the accompanying consolidated balance sheets of LandBridge Company LLC and subsidiaries (the "Company") as of December 31, 2025 and 2024, the related consolidated statements of operations, shareholders’ and member’s equity, and cash flows, for each of the three years in the period ended December 31, 2025, and the related notes (collectively referred to as the "financial statements"). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2025 and 2024, and the results of its operations and its cash flows for each of the three years in the period ended December 31, 2025, in conformity with accounting principles generally accepted in the United States of America.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company's internal control over financial reporting as of December 31, 2025, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission and our report dated February 25, 2026, expressed an unqualified opinion on the Company's internal control over financial reporting.

Basis for Opinion

These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on the Company's financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the financial statements. We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matter

The critical audit matter communicated below is a matter arising from the current-period audit of the financial statements that was communicated or required to be communicated to the audit committee and that (1) relates to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing a separate opinion on the critical audit matter or on the accounts or disclosures to which it relates.

1918 Ranch Acquisition — Refer to Notes 2, 4, and 6 to the financial statements

Critical Audit Matter Description

The Company completed the acquisition of 1918 Ranch & Royalty, LLC (the “1918 Ranch Acquisition”) on November 12, 2025 for total purchase consideration of $263.9 million. The purchase consideration consisted of approximately $208.5 million in cash and 657,411 OpCo Units (together with an equal number of Class B shares) valued at $53.6 million. The Company accounted for the acquisition of the 1918 Ranch Acquisition as an asset acquisition. Accordingly, the purchase price for assets acquired was allocated based on their relative fair value to land, surface use agreements (“intangible assets”), and brackish water supply assets. The method for determining relative fair value varied depending on the type of the asset and involved management making significant estimates related to the assumptions such as selection of comparable sales of land, adjustments for market conditions and location applied to comparables, future undiscounted cash flow projections, discount rate, and internal rate of return.

We identified the 1918 Ranch Acquisition as a critical audit matter because of the significant estimates made by management to determine the relative fair values of these assets. This required a high degree of auditor judgment and an increased extent of effort, including the need to involve our valuation specialists when performing audit procedures to determine the fair value of acquired assets.

79

How the Critical Audit Matter Was Addressed in the Audit

Our audit procedures related to the fair value of assets acquired as part of the 1918 Ranch Acquisition included the following, among others:

•
We tested the effectiveness of controls over the purchase price allocation, including management’s controls over the assumptions used in the market approach for land and income approach for intangible assets. In addition, we evaluated the work of management’s third-party specialists.
•
With the assistance of our fair value specialists, and in respect to the land acquired, we evaluated the reasonableness of the (1) valuation methodology (2) current market data, and (3) developed a range of independent estimates and compared our estimates to those used by management.
•
With the assistance of our fair value specialists, and in respect of the intangible assets acquired, we evaluated the estimates used in the income approach, including, (1) future cash flow projections, including revenue and cost assumptions, (2) assumptions used in the selection of a discount rate and (3) assumptions used in the computed internal rate of return.
•
We considered any events or transactions occurring after the 1918 Ranch Acquisition closing date that may indicate a different valuation for the acquired land and intangible assets.

/s/ Deloitte & Touche LLP
Houston, Texas
February 25, 2026

We have served as the Company’s auditor since 2022.

80

# LandBridge Company LLC and Subsidiaries

# Consolidated Balance Sheets

(in thousands)

|  | December 31, |
|  | 2025 |  |  | 2024 |
Current assets: |  |  |  |  |  |
Cash and cash equivalents |  | $ | 30,741 |  |  | $ | 37,032 |
Accounts receivable, net |  |  | 19,363 |  |  |  | 12,544 |
Related party accounts receivable |  |  | 4,945 |  |  |  | 2,111 |
Prepaid expenses and other current assets |  |  | 4,766 |  |  |  | 1,628 |
Total current assets |  |  | 59,815 |  |  |  | 53,315 |
Non-current assets: |  |  |  |  |  |
Property, plant and equipment, net |  |  | 1,084,450 |  |  |  | 902,742 |
Intangible assets, net |  |  | 136,962 |  |  |  | 45,265 |
Deferred tax assets |  |  | 80,973 |  |  |  | 29,416 |
Other assets |  |  | 3,856 |  |  |  | 1,741 |
Total non-current assets |  |  | 1,306,241 |  |  |  | 979,164 |
Total assets |  | $ | 1,366,056 |  |  | $ | 1,032,479 |
Liabilities and equity |  |  |  |  |  |
Current liabilities: |  |  |  |  |  |
Accounts payable |  | $ | 562 |  |  | $ | 489 |
Taxes payable |  |  | 1,200 |  |  |  | 2,286 |
Related party accounts payable |  |  | 781 |  |  |  | 686 |
Accrued liabilities |  |  | 7,781 |  |  |  | 7,185 |
Current portion of long-term debt |  |  | 692 |  |  |  | 424 |
Deferred revenue |  |  | 1,263 |  |  |  | 1,221 |
Other current liabilities |  |  | 7 |  |  |  | 2,119 |
Total current liabilities |  |  | 12,286 |  |  |  | 14,410 |
Non-current liabilities: |  |  |  |  |  |
Long-term debt, net of debt issuance costs |  |  | 559,593 |  |  |  | 380,815 |
Other long-term liabilities |  |  | 192 |  |  |  | 183 |
Total non-current liabilities |  |  | 559,785 |  |  |  | 380,998 |
Total liabilities |  |  | 572,071 |  |  |  | 395,408 |
Commitments and contingencies |  |  |  |  |  |
Class A shares, unlimited shares authorized and 27,838,199 shares issued and outstanding as of December 31, 2025. Unlimited shares authorized and 23,255,419 shares issued and outstanding as of December 31, 2024 |  |  | 317,069 |  |  |  | 208,427 |
Class B shares, unlimited shares authorized and 49,250,916 shares issued and outstanding as of December 31, 2025. Unlimited shares authorized and 53,227,852 shares issued and outstanding as of December 31, 2024 |  |  | - |  |  |  | - |
Retained earnings |  |  | 23,233 |  |  |  | 3,349 |
Total shareholders' equity attributable to LandBridge Company LLC |  |  | 340,302 |  |  |  | 211,776 |
Noncontrolling interest |  |  | 453,683 |  |  |  | 425,295 |
Total shareholders’ equity |  |  | 793,985 |  |  |  | 637,071 |
Total liabilities and equity |  | $ | 1,366,056 |  |  | $ | 1,032,479 |

See accompanying notes to the consolidated financial statements

81

# LandBridge Company LLC and Subsidiaries

# Consolidated Statements of Operations

# (in thousands, except share and per share amounts)

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |  |  | 2023 |
Revenues: |  |  |  |  |  |  |  |  |
Surface use royalties |  | $ | 36,604 |  |  | $ | 13,121 |  |  | $ | 7,780 |
Surface use royalties - Related party |  |  | 36,168 |  |  |  | 18,499 |  |  |  | 5,436 |
Easements and other surface-related revenues |  |  | 51,286 |  |  |  | 20,629 |  |  |  | 8,395 |
Easements and other surface-related revenues - Related party |  |  | 10,716 |  |  |  | 13,486 |  |  |  | 4,249 |
Resource sales |  |  | 23,005 |  |  |  | 14,964 |  |  |  | 18,045 |
Resource sales - Related party |  |  | 1,718 |  |  |  | 387 |  |  |  | 1,785 |
Resource royalties |  |  | 15,730 |  |  |  | 9,779 |  |  |  | 6,432 |
Resource royalties - Related party |  |  | 7,297 |  |  |  | 3,062 |  |  |  | - |
Oil and gas royalties |  |  | 12,589 |  |  |  | 16,027 |  |  |  | 20,743 |
Other |  |  | 3,980 |  |  |  | - |  |  |  | - |
Total revenues |  |  | 199,093 |  |  |  | 109,954 |  |  |  | 72,865 |
Resource sales-related expense |  |  | 2,026 |  |  |  | 2,113 |  |  |  | 3,445 |
Other operating and maintenance expense |  |  | 4,518 |  |  |  | 3,174 |  |  |  | 2,740 |
General and administrative expense (income) |  |  | 62,448 |  |  |  | 112,302 |  |  |  | (12,091 | )
Depreciation, depletion and amortization |  |  | 11,470 |  |  |  | 8,875 |  |  |  | 8,762 |
Other operating expense, net |  |  | 131 |  |  |  | - |  |  |  | - |
Operating income (loss) |  |  | 118,500 |  |  |  | (16,510 | ) |  |  | 70,009 |
Interest expense, net |  |  | 32,706 |  |  |  | 23,335 |  |  |  | 7,016 |
Other loss (income) |  |  | 4,329 |  |  |  | (241 | ) |  |  | (549 | )
Income (loss) from operations before taxes |  |  | 81,465 |  |  |  | (39,604 | ) |  |  | 63,542 |
Income tax expense |  |  | 9,066 |  |  |  | 1,875 |  |  |  | 370 |
Net income (loss) |  | $ | 72,399 |  |  | $ | (41,479 | ) |  | $ | 63,172 |
Net loss prior to the IPO |  |  | - |  |  |  | (46,877 | ) |  |  |
Net income attributable to noncontrolling interest |  |  | 42,271 |  |  |  | 288 |  |  |  |
Net income attributable to LandBridge Company LLC |  | $ | 30,128 |  |  | $ | 5,110 |  |  |  |
Net income per share of Class A shares (1) |  |  |  |  |  |  |  |  |
Basic |  | $ | 1.18 |  |  | $ | 0.28 |  |  |  |
Diluted |  | $ | 0.94 |  |  | $ | 0.07 |  |  |  |
Weighted average shares outstanding of Class A shares (1) |  |  |  |  |  |  |  |  |
Basic |  |  | 24,815,703 |  |  |  | 17,807,323 |  |  |  |
Diluted |  |  | 76,542,235 |  |  |  | 73,370,073 |  |  |  |

(1)
For the year ended December 31, 2024, represents the period from July 1, 2024 through December 31, 2024, the period following the reorganization transactions and IPO.

See accompanying notes to the consolidated financial statements

82

# LandBridge Company LLC and Subsidiaries

# Consolidated Statements of Shareholders’ and Member’s Equity

# (in thousands)

|  | Member's Equity |  |  | Class A |  |  | Class B |  |  | Retained Earnings |  |  | Non- controlling Interest |  |  | Total Shareholders' and Member's Equity |
|  | Amount |  |  | Shares |  | Amount |  |  | Shares |  | Amount |  |  | Amount |  |  | Amount |  |  | Amount |
Balance at December 31, 2022 |  | $ | 209,959 |  |  |  | - |  | $ | - |  |  |  | - |  | $ | - |  |  | $ | - |  |  | $ | - |  |  | $ | 209,959 |
Distribution to member |  |  | (105,165 | ) |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (105,165 | )
Deemed non-cash distributions |  |  | (17,219 | ) |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (17,219 | )
Net income |  |  | 63,172 |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 63,172 |
Balance at December 31, 2023 |  | $ | 150,747 |  |  |  | - |  | $ | - |  |  |  | - |  | $ | - |  |  | $ | - |  |  | $ | - |  |  | $ | 150,747 |
Contribution from member |  |  | 120,000 |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 120,000 |
Deemed non-cash contributions prior to reorganization |  |  | 72,572 |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 72,572 |
Net loss prior to reorganization |  |  | (46,877 | ) |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (46,877 | )
Effect of corporate reorganization and IPO |  |  | (296,442 | ) |  |  | 17,425,000 |  |  | 94,126 |  |  |  | 55,726,603 |  |  | - |  |  |  | - |  |  |  | 301,023 |  |  |  | 98,707 |
Deemed non-cash contributions subsequent to reorganization |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  |  | 18,735 |  |  |  | 18,735 |
Class A share-based compensation expense subsequent to reorganization |  |  | - |  |  |  | - |  |  | 979 |  |  |  | - |  |  | - |  |  |  | - |  |  |  | 3,049 |  |  |  | 4,028 |
Purchase of OpCo Units from LandBridge Holdings, net of placement agent fees |  |  | - |  |  |  | - |  |  | - |  |  |  | (2,498,751 | ) |  | - |  |  |  | - |  |  |  | (145,411 | ) |  |  | (145,411 | )
Dividends and distributions |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | (1,743 | ) |  |  | (5,573 | ) |  |  | (7,316 | )
RSU dividend equivalent rights |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | (18 | ) |  |  | (57 | ) |  |  | (75 | )
December 2024 Private Placement, net of placement agent fees and offering expenses |  |  | - |  |  |  | 5,830,419 |  |  | 337,558 |  |  |  | - |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 337,558 |
Net income subsequent to reorganization |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | 5,110 |  |  |  | 288 |  |  |  | 5,398 |
Changes in ownership interest adjustment |  |  | - |  |  |  | - |  |  | (253,241 | ) |  |  | - |  |  | - |  |  |  | - |  |  |  | 253,241 |  |  |  | - |
Tax impact of ownership interest adjustment |  |  | - |  |  |  | - |  |  | 29,005 |  |  |  | - |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 29,005 |
Balance at December 31, 2024 |  | $ | - |  |  |  | 23,255,419 |  | $ | 208,427 |  |  |  | 53,227,852 |  | $ | - |  |  | $ | 3,349 |  |  | $ | 425,295 |  |  | $ | 637,071 |
Net income |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | 30,128 |  |  |  | 42,271 |  |  |  | 72,399 |
Deemed non-cash contributions |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  |  | 36,508 |  |  |  | 36,508 |
RSU share-based compensation expense |  |  | - |  |  |  | - |  |  | 2,882 |  |  |  | - |  |  | - |  |  |  | - |  |  |  | 5,929 |  |  |  | 8,811 |
Redemption of Class B shares to Class A shares |  |  | - |  |  |  | 4,400,000 |  |  | - |  |  |  | (4,400,000 | ) |  | - |  |  |  | - |  |  |  | - |  |  |  | - |
Class A Shares issued on vesting of RSUs, net of shares withheld for tax |  |  | - |  |  |  | 182,780 |  |  | (5,750 | ) |  |  | - |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (5,750 | )
Cancellation of Class B shares |  |  | - |  |  |  | - |  |  | - |  |  |  | (234,347 | ) |  | - |  |  |  | - |  |  |  | - |  |  |  | - |
Class B Shares issued for acquisition |  |  | - |  |  |  | - |  |  | - |  |  |  | 657,411 |  |  | - |  |  |  | - |  |  |  | 53,586 |  |  |  | 53,586 |
Tax distributions |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  |  | (32,788 | ) |  |  | (32,788 | )
Dividends and distributions |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | (10,159 | ) |  |  | (20,506 | ) |  |  | (30,665 | )
RSU dividend equivalent rights |  |  | - |  |  |  | - |  |  | - |  |  |  | - |  |  | - |  |  |  | (85 | ) |  |  | (175 | ) |  |  | (260 | )
Changes in ownership interest adjustment |  |  | - |  |  |  | - |  |  | 56,437 |  |  |  | - |  |  | - |  |  |  | - |  |  |  | (56,437 | ) |  |  | - |
Tax impact of ownership interest adjustment |  |  | - |  |  |  | - |  |  | 55,641 |  |  |  | - |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 55,641 |
Offering costs |  |  | - |  |  |  | - |  |  | (568 | ) |  |  | - |  |  | - |  |  |  | - |  |  |  | - |  |  |  | (568 | )
Balance at December 31, 2025 |  | $ | - |  |  |  | 27,838,199 |  | $ | 317,069 |  |  |  | 49,250,916 |  | $ | - |  |  | $ | 23,233 |  |  | $ | 453,683 |  |  | $ | 793,985 |

# See accompanying notes to the consolidated financial statements

83

# LandBridge Company LLC and Subsidiaries

# Consolidated Statements of Cash Flow s

# (in thousands)

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |  |  | 2023 |
Cash flows from operating activities |  |  |  |  |  |  |  |  |
Net income (loss) |  | $ | 72,399 |  |  | $ | (41,479 | ) |  | $ | 63,172 |
Adjustments to reconcile net income (loss) to net cash provided by operating activities: |  |  |  |  |  |  |  |  |
Depreciation, depletion and amortization |  |  | 11,470 |  |  |  | 8,875 |  |  |  | 8,762 |
Amortization of debt issuance costs |  |  | 2,189 |  |  |  | 1,688 |  |  |  | 388 |
Share-based compensation |  |  | 45,319 |  |  |  | 95,335 |  |  |  | (17,230 | )
Loss on extinguishment of debt |  |  | 4,416 |  |  |  | - |  |  |  | - |
Deferred income tax expense (benefit) |  |  | 4,084 |  |  |  | (411 | ) |  |  | - |
Other |  |  | 16 |  |  |  | 5 |  |  |  | (246 | )
Changes in operating assets and liabilities: |  |  |  |  |  |  |  |  |
Accounts receivable |  |  | (6,834 | ) |  |  | 2,113 |  |  |  | (1,474 | )
Related party accounts receivable |  |  | (2,834 | ) |  |  | (1,074 | ) |  |  | (613 | )
Prepaid expenses and other assets |  |  | 1,301 |  |  |  | (328 | ) |  |  | 43 |
Accounts payable |  |  | 16 |  |  |  | 272 |  |  |  | 362 |
Related party accounts payable |  |  | 95 |  |  |  | 233 |  |  |  | (109 | )
Accrued liabilities and other liabilities |  |  | (1,616 | ) |  |  | 506 |  |  |  | (186 | )
Taxes payable |  |  | (3,748 | ) |  |  | 1,901 |  |  |  | 173 |
Net cash provided by operating activities |  |  | 126,273 |  |  |  | 67,636 |  |  |  | 53,042 |
Cash flows from investing activities |  |  |  |  |  |  |  |  |
Acquisitions |  |  | (229,048 | ) |  |  | (723,367 | ) |  |  | - |
Capital expenditures |  |  | (4,236 | ) |  |  | (985 | ) |  |  | (2,783 | )
Proceeds from disposal of assets |  |  | 210 |  |  |  | - |  |  |  | 11 |
Net cash used in investing activities |  |  | (233,074 | ) |  |  | (724,352 | ) |  |  | (2,772 | )
Cash flows from financing activities |  |  |  |  |  |  |  |  |
Proceeds from debt |  |  | 783,549 |  |  |  | 417,500 |  |  |  | 150,000 |
Repayments of debt |  |  | (599,198 | ) |  |  | (162,962 | ) |  |  | (77,821 | )
Dividends, dividend equivalents, and distributions paid |  |  | (63,713 | ) |  |  | (178,244 | ) |  |  | (105,165 | )
Debt issuance costs |  |  | (13,266 | ) |  |  | (4,326 | ) |  |  | (3,106 | )
Taxes paid related to net share settlement of RSUs |  |  | (5,750 | ) |  |  | - |  |  |  | - |
Offering costs |  |  | (1,112 | ) |  |  | (8,186 | ) |  |  | (1,706 | )
Proceeds from issuance of Class A shares - IPO, net of underwriting discounts and fees |  |  | - |  |  |  | 278,263 |  |  |  | - |
Proceeds from issuance of Class A shares - December 2024 Private Placement, net of placement agent fees |  |  | - |  |  |  | 339,291 |  |  |  | - |
Purchase of OpCo Units from LandBridge Holdings, net of placement agent fees |  |  | - |  |  |  | (145,411 | ) |  |  | - |
Contributions from member |  |  | - |  |  |  | 120,000 |  |  |  | - |
Net cash provided by (used in) financing activities |  |  | 100,510 |  |  |  | 655,925 |  |  |  | (37,798 | )
Net (decrease) increase in cash and cash equivalents |  |  | (6,291 | ) |  |  | (791 | ) |  |  | 12,472 |
Cash and cash equivalents - beginning of period |  |  | 37,032 |  |  |  | 37,823 |  |  |  | 25,351 |
Cash and cash equivalents - end of period |  | $ | 30,741 |  |  | $ | 37,032 |  |  | $ | 37,823 |

# See accompanying notes to the consolidated financial statements

84

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

1. Organization and Nature of Operations

LandBridge Company LLC (the “Company,” “LandBridge,” “we,” “our” and “us”) is headquartered in Houston, Texas and was formed on September 27, 2023 as a Delaware limited liability company to serve as the issuer in an initial public offering of equity (the “IPO”). We are governed by our First Amended & Restated Limited Liability Company Agreement, dated as of July 1, 2024 (the “A&R LLC Agreement”), which was entered into in connection with the IPO.

Our accounting predecessor is DBR Land Holdings LLC (“OpCo”) and its subsidiaries. OpCo is a Delaware limited liability company which was formed in September 2021. We are a holding company whose principal asset consists of membership interests in OpCo (“OpCo Units”). As the managing member of OpCo and its subsidiaries, we operate and control all of the business and affairs of OpCo and its subsidiaries, and through OpCo and its subsidiaries, conduct our business. In addition, the Company has no other operations, cash flows, or material assets or liabilities other than our investment in OpCo and certain deferred tax assets and liabilities. Refer to Note 7 — Income Taxes for additional information.

We generate revenue primarily from the use of our surface acreage, the sale of resources from our land and oil and natural gas royalties. The use of surface acreage generally includes easements or leases and various surface use royalties. Sale of resources generally includes sales of brackish water and other surface composite materials. Our assets consist mainly of fee surface acreage, oil and natural gas mineral interests, brackish water wells and ponds and related facilities.

We own surface acreage in the Delaware Basin in Texas and New Mexico and oil and natural gas mineral interests in the Delaware Basin in Texas.

Initial Public Offering and Private Placement

On July 1, 2024, we completed our IPO of 14,500,000 Class A shares representing limited liability company interests (“Class A shares”) at a price to the public of $17.00 per share. In addition, we granted the underwriters a 30-day option to purchase up to an additional 2,175,000 Class A shares at the public offering price, less underwriting discounts and commissions, which was exercised in full on July 1, 2024. In addition to the Class A shares sold in the IPO, on July 1, 2024, we sold 750,000 Class A shares at a price of $17.00 per Class A share in a concurrent private placement to an accredited investor (the “concurrent private placement”).

The closing of the IPO, including the exercise of the underwriters’ option and the concurrent private placement, resulted in net proceeds of approximately $270.9 million, after deducting underwriting discounts and commissions, placement agent fees, and other offering expenses. The Company contributed all of the net proceeds of the IPO (including the underwriters’ option and the concurrent private placement) to OpCo in exchange for OpCo Units at a per-unit price equal to the per share price paid by the underwriters for Class A shares in the IPO. OpCo distributed approximately $170.9 million to LandBridge Holdings LLC (“LandBridge Holdings”) and utilized approximately $100.0 million to repay outstanding borrowings under the 2023 Credit Agreement (as defined in Note 8 — Debt). Refer to Note 8 — Debt for additional information related to our credit facilities.

Corporate Reorganization and Amended and Restated LLC Agreement

On July 1, 2024, immediately prior to the IPO, WaterBridge NDB LLC (“NDB LLC”), the sole member of the Company prior to the corporate reorganization, was divided into two Delaware limited liability companies in accordance with a plan of division: (i) NDB LLC and (ii) LandBridge Holdings, a new Delaware limited liability company created by, and resulting from, the division (collectively, the “Division”). Following the Division and in connection with the IPO, our board of directors authorized and approved the A&R LLC Agreement.

The A&R LLC Agreement authorizes two classes of shares, Class A shares and Class B shares representing limited liability company interests in us. Only our Class A shares have economic rights and entitle holders thereof to participate in any dividends our board of directors may declare. Under the A&R LLC Agreement, the Company is authorized to issue an unlimited number of additional limited liability company interests of any type without the approval of our shareholders, subject to the rules of the New York Stock Exchange and NYSE Texas, Inc. Each holder of a Class A share is entitled to one vote on all matters to be voted on by our shareholders generally. Class B shares are entitled to vote on the same basis as the Class A shares. Holders of Class A shares and Class B shares vote together as a single class on all matters presented to our shareholders, except as otherwise required by applicable law or by the A&R LLC Agreement. We do not intend to list the Class B shares on any stock exchange.

85

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

Redemption Rights

Pursuant to the Amended and Restated Limited Liability Company Agreement of OpCo, dated as of July 1, 2024, as amended by Amendment No. 1 thereto, dated effective as of September 30, 2024 (collectively, the “OpCo LLC Agreement”), each holder of an OpCo Unit (other than the Company) (each, a “Redeeming Member”) has the right, subject to certain limitations (the “Redemption Right”), to cause OpCo to acquire all or a portion of its OpCo Units (along with the cancellation of a corresponding number of our Class B shares) for, at OpCo’s election, (x) Class A shares at a redemption ratio of one Class A share for each OpCo Unit redeemed, subject to conversion rate adjustments for equity splits, dividends and reclassifications and other similar transactions (“applicable conversion rate adjustments”) or (y) cash in an amount equal to the Cash Election Amount (as defined in the OpCo LLC Agreement) of such Class A shares. Alternatively, upon the exercise of the Redemption Right, the Company has the right, pursuant to the Call Right (as defined in the OpCo LLC Agreement), to acquire each tendered OpCo Unit directly from the Redeeming Member for, at the Company’s election, (x) one Class A share, subject to applicable conversion rate adjustments, or (y) cash in an amount equal to the Cash Election Amount of such Class A shares. Notwithstanding the foregoing, to the extent a Redeeming Member and its affiliates own at least 40% of the voting power of the Company, (i) OpCo may elect to settle a redemption by such Redeeming Member in cash only to the extent that, prior to or contemporaneously with making such election, the Company issues a number of equity securities at least equal to the number of OpCo Units subject to such redemption and contributes to OpCo an amount in cash equal to the net proceeds received by the Company from the issuance of such equity securities, and (ii) the Company may make a Cash Election (as defined in the OpCo LLC Agreement) in connection with its exercise of its Call Right with respect to a redemption by such Redeeming Member only to the extent that, prior to or contemporaneously with making such election, the Company issues a number of equity securities at least equal to the number of OpCo Units subject to such redemption.

Corporate Reorganization

The transactions described above (collectively, the “Corporate Reorganization”) have been accounted for as a reorganization of entities under common control. As a result, our consolidated financial statements recognize the assets and liabilities in the Corporate Reorganization at their historical carrying amounts, reflected in the historical financial statements of OpCo.

Private Placement

On December 19, 2024, we closed a private placement transaction pursuant to which certain persons reasonably believed to be accredited investors or qualified institutional buyers purchased an aggregate 5,830,419 Class A shares from us at $60.03 per share (the “December 2024 Private Placement”). The closing of the December 2024 Private Placement resulted in net proceeds of approximately $339.3 million, after deducting placement agent fees. Additionally, we incurred approximately $2.2 million in offering costs associated with the December 2024 Private Placement. The Company used approximately $200.0 million, net of placement agent fees, of such proceeds from the December 2024 Private Placement to partially fund the Wolf Bone Acquisition (refer to Note 4 — Asset Acquisitions), and approximately $150.0 million, net of placement agent fees, of such proceeds to purchase 2,498,751 OpCo Units (along with the cancellation of corresponding number of Class B shares) from LandBridge Holdings.

Redemptions

On November 18, 2025, LandBridge Holdings redeemed 2,500,000 OpCo Units (together with the cancellation of a corresponding number of Class B shares), for an equivalent amount of Class A shares and subsequently sold such Class A Shares in an underwritten public offering to Goldman Sachs & Co. LLC at a price of $70.00 per share. The Company did not receive any proceeds from the sale of Class A Shares by LandBridge Holdings.

On May 23, 2025, LandBridge Holdings redeemed 1,900,000 OpCo Units (together with the cancellation of a corresponding number of Class B shares), for an equivalent amount of Class A shares and subsequently sold such Class A shares in a private transaction pursuant to Rule 144 under the Securities Act through a broker-deal at a price of $75.25 per share. The Company did not receive any proceeds or incur any material expenses from the sale of the Class A shares by LandBridge Holdings.

2. Summary of Significant Accounting Policies

## Basis of Presentation and Consolidation

Our consolidated financial statements (“Financial Statements”) have been prepared in accordance with U.S. generally accepted accounting principles (“GAAP”).

All dollar amounts in the Financial Statements and tables in the notes are stated in thousands of dollars unless otherwise indicated.

86

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

In these Financial Statements, periods prior to the consummation of the Corporate Reorganization and the IPO reflect the financial statements of OpCo and its subsidiaries. Periods subsequent to the consummation of the Corporate Reorganization and the IPO reflect the financial statements of the consolidated Company, including LandBridge, OpCo and its subsidiaries.

We have determined that the members with equity at risk in OpCo lack the authority, through voting rights or similar rights, to direct the activities that most significantly impact OpCo’s economic performance; therefore, OpCo is considered a variable interest entity. As the managing member of OpCo, we operate and control all of the business and affairs of OpCo and also have the obligation to absorb losses or the right to receive benefits that could be potentially significant to us. Therefore, we are considered the primary beneficiary and consolidate OpCo.

The Financial Statements include the accounts of the Company, OpCo and its wholly owned subsidiaries. All intercompany transactions and balances have been eliminated upon consolidation.

## Adjustment of Previously Issued Financial Statements

Subsequent to the issuance of the Company’s Consolidated Financial Statements filed in our Annual Report on Form 10-K for the period ended December 31, 2024, the Company identified an error in connection with its December 2024 Private Placement of Class A shares and the corresponding purchase of 2,498,751 OpCo Units from LandBridge Holdings, along with the cancellation of a corresponding number of Class B shares held by LandBridge Holdings. The Company did not correctly rebalance the carrying amount of the non-controlling interest (“NCI”) to reflect the ownership change at OpCo in connection with the December 2024 purchase of OpCo Units, resulting in an understatement of the NCI amount and an overstatement of the Class A amount of $253.2 million, respectively, on the consolidated balance sheets and the consolidated statement of shareholders’ and member’s equity as of December 31, 2024. Additionally, the Company did not reflect the deferred tax asset generated from the step-up in tax basis associated with the December 2024 purchase of OpCo Units, resulting in an understatement of deferred tax assets and Class A amount of $29.0 million, respectively, on the consolidated balance sheets and consolidated statement of shareholders’ and member’s equity as of December 31, 2024.

We assessed the materiality of the error, both quantitatively and qualitatively, in accordance with the SEC’s Staff Accounting Bulletin No. 99 and Staff Accounting Bulletin No. 108, and concluded the error was not material to any of our previously-issued quarterly or annual financial statements. However, we determined that it was appropriate to revise the applicable items in our previously-issued financial statements. The adjustment to deferred tax assets of $29.0 million adjusts the investment in partnership amount within Note 7 — Income Taxes of the Company’s consolidated financial statements contained in the 2024 Form 10-K. The error has no impact on the results of operations in our previously reported consolidated statements of operations, including net (loss) income or net income per share of Class A shares, or to cash flows in our previously reported consolidated statements of cash flows. The following tables reflect the effects of the correction on all affected line items of the Company’s previously reported consolidated financial statements:

Consolidated Balance Sheets |  | December 31, 2024 |
(in thousands) |  | As Previously Reported |  |  | Adjustment |  |  | As Adjusted |
Deferred tax assets |  | $ | 411 |  |  | $ | 29,005 |  |  | $ | 29,416 |
Total non-current assets |  |  | 950,159 |  |  |  | 29,005 |  |  |  | 979,164 |
Total assets |  |  | 1,003,474 |  |  |  | 29,005 |  |  |  | 1,032,479 |
Class A shares, unlimited shares authorized and 23,255,419 shares issued and outstanding as of December 31, 2024. |  |  | 432,663 |  |  |  | (224,236 | ) |  |  | 208,427 |
Total shareholders’ equity attributable to LandBridge Company LLC |  |  | 436,012 |  |  |  | (224,236 | ) |  |  | 211,776 |
Noncontrolling interest |  |  | 172,054 |  |  |  | 253,241 |  |  |  | 425,295 |
Total shareholders’ and member’s equity |  |  | 608,066 |  |  |  | 29,005 |  |  |  | 637,071 |
Total liabilities and equity |  |  | 1,003,474 |  |  |  | 29,005 |  |  |  | 1,032,479 |

87

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

Consolidated Statements of Shareholders’ and Member’s Equity |  | Class A Amount |  |  | Non-controlling interest amount |  |  | Total Shareholders’ and Member’s Equity |
(in thousands) |  | As Previously Reported |  |  | Adjustment |  |  | As Adjusted |  |  | As Previously Reported |  |  | Adjustment |  |  | As Adjusted |  |  | As Previously Reported |  |  | Adjustment |  |  | As Adjusted |
Changes in ownership interest adjustment |  | $ | - |  |  | $ | (253,241 | ) |  | $ | (253,241 | ) |  | $ | - |  |  | $ | 253,241 |  |  | $ | 253,241 |  |  | $ | - |  |  | $ | - |  |  | $ | - |
Tax impact of interest adjustment |  |  | - |  |  |  | 29,005 |  |  |  | 29,005 |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 29,005 |  |  |  | 29,005 |
Balance at December 31, 2024 |  |  | 432,663 |  |  |  | (224,236 | ) |  |  | 208,427 |  |  |  | 172,054 |  |  |  | 253,241 |  |  |  | 425,295 |  |  |  | 608,066 |  |  |  | 29,005 |  |  |  | 637,071 |

Noncontrolling Interest

Our Financial Statements include a noncontrolling interest representing the percentage of OpCo Units not held by us. The noncontrolling interest is subject to change in connection with various equity transactions such as issuances of Class A shares, the redemption of OpCo Units (and corresponding cancellation of an equivalent number of Class B shares) for Class A shares, or the cancellation of OpCo Units (and corresponding cancellation of an equivalent number of Class B shares) in lieu of the payment of a tax distribution by OpCo to the Company in excess of the Company’s tax obligation for a given quarter.

## Segment Information

## The Company operates in a single operating and reportable segment. All of our assets are located in the United States. Accounting Standards Codification (“ASC”) Topic 280, Segment Reporting, defines characteristics of operating segments as being components of an enterprise in which separate discrete financial information is available for evaluation by the chief operating decision maker (“CODM”) in making decisions on how to allocate resources and assess performance. The Company’s one segment approach is consistent with the reporting structure of the Company’s internal organization, as well as with the financial information used by the Company’s CODM. The Company’s CODM is the Chief Executive Officer who allocates resources and assess performance based upon financial information at the consolidated level. The financial measure regularly provided to the CODM that is most consistent with GAAP is net income (loss), as presented on our consolidated statements of operations. The measure of segment assets is reported on the consolidated balance sheets as total assets. The Company presents all of its significant segment expenses and other metrics as used by the CODM to make decisions regarding the Company’s business, including resource allocation and performance assessment in our Financial Statements.

## Use of Estimates

The preparation of the Financial Statements in conformity with GAAP requires management to make certain estimates and assumptions that affect the amounts reported in the Financial Statements and accompanying notes.

The Company evaluates its estimates and related assumptions regularly, including those related to the fair value measurements of assets acquired in asset acquisitions, the collectability of accounts receivable, the assessment of recoverability and useful lives of long-lived assets, including property, plant and equipment, intangible assets, and the valuation of the Incentive Units. Changes in facts and circumstances or additional information may result in revised estimates, and actual results may differ from such estimates.

## Fair Value Measurements

Fair value is the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. Whenever available, fair value is based on or derived from observable market prices or parameters. When observable market prices or inputs are not available, unobservable prices or inputs are used to estimate the fair value. The three levels of the fair value measurement hierarchy are as follows:

•
Level 1: Quoted market prices in active markets for identical assets or liabilities.
•
Level 2: Inputs other than quoted prices included in Level 1 that are observable for the asset or liability, either directly or indirectly.
•
Level 3: Unobservable inputs that are not corroborated by market data.

The carrying value of the Company’s cash and cash equivalents, accounts receivable, net of current expected credit losses, and

88

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

accounts payable and accrued liabilities reported on the consolidated balance sheets approximate fair value due to their highly liquid nature or short-term maturity.

The Company adjusts the carrying amount of certain non-financial assets, property, plant and equipment and definite-lived intangible assets, to fair value on a non-recurring basis when they are impaired.

The fair value of debt is the estimated amount the Company would have to pay to transfer its debt, including any premium or discount attributable to the difference between the stated interest rate and market rate of interest at the balance sheet date. Refer to Note 8 — Debt for additional information.

Recurring fair value measurements were performed for NDB Incentive Units (defined below) prior to the Division and award modifications (when the incentive units were accounted for as liability awards at NDB LLC), as disclosed in Note 10 — Share-Based Compensation.

There were no transfers between the fair value hierarchy levels f or the years ended December 31, 2025 and 2024.

Cash and Cash Equivalents

The Company considers all highly liquid investments with original maturities of three months or less to be cash equivalents. The Company maintains cash balances that may at times exceed federally insured limits.

Accounts Receivable

The Company extends credit to customers and other parties in the normal course of business. Accounts receivable consists of trade receivables recorded at the invoiced amount, plus accrued revenue that is earned but not yet billed, less an estimated allowance for doubtful accounts. Account receivables are generally due within 45 days or less. An allowance for expected credit losses is determined based upon historical write-off experience, aging of accounts receivables, current macroeconomic industry conditions and customer collectability patterns. Accounts receivable are charged against the allowance when determined to be uncollectible. When the Company recovers amounts that were previously written off, those amounts are offset against the allowance and reduce expense in the year of recovery.

As of December 31, 2025 and 2024, the Company had balances of immaterial amounts in allowance for doubtful accounts. There were immaterial amounts of write-offs and no recoveries for the years ended December 31, 2025, 2024 and 2023.

As of December 31, 2025, the Company had four customers that accounted for approximately 21%, 19%, 14% and 11% of accounts receivable, respectively. As of December 31, 2024, the Company had three customers that accounted for approximately 19%, 15%, and 14% of accounts receivable, respectively.

The Company accrues oil and gas royalties for amounts not received during the period but produced based on historical production volumes and current market prices. Produced water and other surface use royalties are also accrued for during the period based on historical trends or expected activity and contract prices. These accrued amounts are both included within accounts receivable, net on the consolidated balance sheets.

Property, Plant and Equipment

Property, plant, and equipment is stated at cost or, upon acquisition, at its fair value. Expenditures for construction activities, major improvements and betterments that extend the useful life of an asset are capitalized, while expenditures for maintenance and repairs are expensed as incurred. Costs of abandoned projects are charged to operating expense upon abandonment. The cost of assets sold or disposed of, and the related accumulated depreciation are removed from the accounts in the period of sale or disposal, and the resulting gains or losses are recorded in earnings in the respective period. Refer to Note 5 – Property, Plant and Equipment.

Depreciation is computed using the straight-line method over the estimated useful lives for each asset group, as noted below:

Water wells, pipelines, facilities, ponds and related equipment |  | 3 - 30 years
Buildings |  | 30 years
Vehicles, equipment, furniture and other |  | 3 - 5 years

## The Company follows the successful efforts method of accounting for its oil and natural gas properties acquired. Under this method, costs to acquire mineral and royalty interests in oil and natural gas properties are capitalized when incurred. Acquisitions of oil and natural gas properties are recorded at their estimated fair value as of the acquisition date.

89

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

## Proved properties

## Costs of proved oil and natural gas properties are depleted on a basin-wide basis utilizing the units-of-production method using total proved reserves.

## Unproved properties

## Costs of unproved oil and natural gas properties are not subject to depletion. These costs are transferred into costs subject to depletion on an ongoing basis as wells are completed and as proved reserves are established or confirmed.

## Intangible Assets

Our intangible assets with definite useful lives include water contracts and surface use agreements. The amounts are presented at the Company’s cost basis. Such intangible assets with definite lives are amortized on a straight-line basis and assume no residual value. Refer to Note 6 - Intangible Assets for further information.

Debt Issuance Costs

Debt issuance costs represent costs associated with long-term financing and are amortized over the term of the related debt using a method which approximates the effective interest method. The Company’s debt issuance costs associated with the revolving credit facility are deferred and presented within prepaid expenses and other current assets, and other assets on the consolidated balance sheets. Debt issuance costs associated with the term loan and senior unsecured notes are reflected as a reduction of long-term debt on the consolidated balance sheets. Refer to Note 8 – Debt for further information.

Offering Costs

Offering costs consist of costs related to underwriting, legal, accounting, and other expenses incurred through the balance sheet date that are directly related to the IPO and the December 2024 Private Placement. These costs were offset against proceeds upon consummation of the IPO and December 2024 Private Placement. As of December 31, 2025 and 2024, the Company had $0.5 million and $10.4 million of offering costs included in shareholders’ and member’s equity on the consolidated balance sheets, of which $0.5 million was accrued as of December 31, 2024. Prior to the consummation of the IPO, offering costs were deferred. As of December 31, 2025 and 2024, we had no deferred offering costs included in other assets on the consolidated balance sheets related to the IPO and December 2024 Private Placement.

## Acquisitions

To determine if a transaction should be accounted for as a business combination or an asset acquisition, we first calculate the relative fair value of the assets acquired and liabilities assumed. We first apply a screen to determine if substantially all of the relative fair value of the acquired gross assets is concentrated in a single identifiable asset or group of similar identifiable assets. If the screen is met, the transaction is accounted for as an asset acquisition. If the screen is not met, further determination is required as to whether or not the Company has acquired inputs and processes that have the ability to create outputs, which would meet the definition of a business. If this further determination does not meet the definition of a business the transaction is accounted for as an asset acquisition. We record asset acquisitions using the cost accumulation model. Under the cost accumulation model of accounting, the cost of the acquisition, including certain transaction costs, are allocated to the assets acquired using relative fair values. All other transactions are recorded as business combinations. We record the assets acquired and liabilities assumed in a business combination at their acquisition date fair values. Transactions in which we acquire control of a business are accounted for under the acquisition method. The identifiable assets, liabilities and any noncontrolling interests are recorded at the estimated fair value as of the acquisition date. The purchase price in excess of the fair value of assets acquired and liabilities assumed is recorded as goodwill.

Impairment of Long-Lived Assets

Management reviews the Company’s long-lived assets, which primarily includes property, plant and equipment and definite-lived intangible assets, for impairment whenever events or changes in circumstances indicate that the carrying value of the assets might not be recoverable. Assets are grouped at the lowest level for which there are identifiable cash flows that are largely independent of the cash flows of other groups of assets for purposes of assessing recoverability. Recoverability is generally determined by comparing the carrying value of the asset to the expected undiscounted future cash flows of the asset. If the carrying value of the asset is not recoverable, the amount of impairment loss is measured as the excess, if any, of the carrying value of the asset over its estimated fair value.

Proved reserves

90

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

The estimated quantities of oil, natural gas and NGLs which geological and engineering data demonstrate with reasonable certainty to be economically recoverable in future years from known reservoirs under existing economic conditions and operating methods, i.e., prices and costs as of the date the estimate is made. Prices include consideration of changes in existing prices provided by contractual arrangements (“Proved Reserves”). The Company evaluates its proved oil and natural gas properties for impairment when events or changes in circumstances indicate the related carrying value may not be recoverable. This evaluation is performed on a basin-wide basis. The Company assesses the valuation of its proved oil and natural gas properties for impairment by comparing the carrying value to estimated undiscounted future net cash flows using estimated production and prices at which the Company estimates the commodity will be sold. If the carrying value exceeds undiscounted future net cash flows, the measurement of impairment is based on estimated fair value utilizing a discounted future cash flows analysis. The impairment recorded is the amount by which the carrying value exceeds the fair value. In the impairment assessment, the Company estimates the fair value of proved oil and natural gas properties using valuation techniques that convert future cash flows to a single undiscounted amount. Significant inputs and assumptions to the valuation of proved oil and natural gas properties include estimates of reserves, future production volumes, future operating and development costs, future commodity prices and a market-based weighted average cost of capital rate.

Unproved reserves

Reserves that are based on geoscience and/or engineering data similar to that used in estimates of Proved Reserves, but technical or other uncertainties preclude such reserves being classified as proved reserves (“Unproved reserves”) Unproved oil and natural gas properties are also evaluated periodically for impairment. Impairment is assessed when events and circumstances indicate the carrying value may not be recoverable, at which an impairment loss is recognized to the extent the carrying value exceeds the estimated recoverable value. Impairment assessment criteria includes, but is not limited to, commodity prices forecasts, macroeconomic conditions and current and future operator activity in the basin.

We did no t recognize any impairment for the years ended December 31, 2025, 2024 and 2023.

## Share-Based Compensation

## Incentive Units

The Company accounts for share-based compensation expense for incentive units granted in exchange for employee services. Incentive units are subject to time-based vesting, and vest to the participant over the course of the vesting period which is generally three years. Forfeitures are accounted for upon occurrence.

Prior to the Division, our management and employees participated in an equity-based incentive unit plan, managed by NDB LLC, the direct parent of the Company. The incentive units consisted of time-based awards of profits interests in NDB LLC (the “NDB Incentive Units”).

The NDB Incentive Units represented a substantive class of equity of NDB LLC and were accounted for under Financial Accounting Standards Board (“FASB”) ASC Topic 718, Compensation — Stock Compensation (“ASC 718”). Features of the NDB Incentive Units included the ability for NDB LLC to repurchase NDB Incentive Units during a 180-day option period, whereby the fair value price was determined as of the termination date, not the repurchase date, which temporarily takes away the rights and risks and rewards of ownership from the NDB Incentive Unit holder during the option period. Under ASC 718, a feature for which the employee could bear the risks, but not gain the rewards, normally associated with equity ownership requires liability classification. NDB LLC classified the NDB Incentive Units as liability awards. The liability related to the NDB Incentive Units was recognized at NDB LLC as the entity responsible for satisfying the obligation. Share-based compensation income or expense allocated to the Company was recognized as a deemed non-cash contribution to or distribution from member’s equity on the consolidated balance sheets. The share-based compensation income or expense was recognized consistent with NDB LLC’s classification of a liability award resulting in the initial measurement, and subsequent remeasurements, recognized ratably over the vesting period.

At each reporting period, the NDB Incentive Units were remeasured at their fair value, consistent with liability award accounting, using a Monte Carlo Simulation. The Monte Carlo Simulation requires judgment in developing assumptions, which involve numerous variables. These variables include, but are not limited to, the expected unit price volatility over the term of the awards, the expected distribution yield and the expected life of the NDB Incentive Units. The vested portion of the NDB Incentive Unit liability was allocated pro rata to the Company, and other NDB LLC operating subsidiaries, as general and administrative expense or income on the consolidated statements of operations. The allocation was based on the Company’s share of the aggregate equity value derived in NDB LLC’s business enterprise valuation.

The Company updated its assumptions each reporting period based on new developments and adjusted such amounts to fair value based on revised assumptions, if applicable, over the vesting period. The fair value measurement was based on significant inputs not observable in the market, and thus represented Level 3 inputs within the fair value hierarchy.

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Notes to the Consolidated Financial Statements (Continued)

The risk-free rate was determined by reference to the U.S. Treasury yield curve in effect at the time of grant of each award and updated at each balance sheet date for the time period approximating the expected term of such award. The expected distribution yield was based on no previously paid distributions and no intention of paying distributions on the NDB Incentive Units for the foreseeable future.

Due to the Company not having sufficient historical volatility, the Company used the historical volatilities of publicly traded companies that were similar to the Company in size, stage of life cycle and financial leverage.

On July 1, 2024, as a result of the Division, holders of NDB Incentive Units received an identical number of LBH Incentive Units consisting of time-based awards of profits interests in LandBridge Holdings. Following the Division, the LBH Incentive Units held at LandBridge Holdings are the only incentive units attributable and allocated to the Company. There are 31,000 LBH Incentive Units currently authorized pursuant to the A&R LLC Agreement.

Further, in connection with the Division, the repurchase feature of the incentive units was amended such that the repurchase price is the fair value determined as of the repurchase date, which subjects the Incentive Unit holder to the normal rights, risks and rewards of ownership. The repurchase feature is a non-contingent call option as the call becomes effective upon (i) the employee’s termination of employment either by the Company (with or without cause) or (ii) voluntary resignation by employee and it is assured that all employees will eventually terminate. Under ASC 718, a feature for which the employee could bear the risks and rewards normally associated with equity ownership and a non-contingent call option not probable to be exercised within six months requires equity classification. As such, beginning on July 1, 2024, the LBH Incentive Units are no longer required to be remeasured at fair value and no longer require liability award accounting, as the modification results in equity award classification and accounting. Refer to Note 10 — Share-Based Compensation for additional information related to the modification. The fair value measurement of any new issuances, after the Division, are based on significant inputs not observable in the market, and thus represented Level 3 inputs within the fair value hierarchy.

Distributions attributable to LBH Incentive Units are based on returns received by investors of LandBridge Holdings once certain return thresholds have been met. LBH Incentive Units are solely a payment obligation of LandBridge Holdings, and neither the Company nor OpCo has any cash or other obligation to make payments in connection with the LBH Incentive Units.

LTIP and Restricted Share Units

## In connection with the IPO, our board of directors adopted the LandBridge Company LLC Long Term Incentive Plan (the “LTIP”). The LTIP allows for the grant of options, share appreciation rights, restricted share units (“RSUs”), share awards, dividend equivalents, other share-based awards, cash awards, substitute awards, or any combination thereof.

## There were 3,854,456 Class A shares reserved for delivery under the LTIP as of December 31, 2025, subject to increase on January 1 of each calendar year by a number of shares equal to the lesser of (x) 5% of the total number of Class A shares and Class B shares outstanding as of December 31 of the immediately preceding calendar year; (y) the number of shares required to bring the total shares available for issuance under the LTIP to 5% of the total number of Class A shares and Class B shares outstanding as of December 31 of the immediately preceding calendar year; or (z) such smaller number of shares as determined by our board of directors.

RSUs issued to participants are recorded on grant date at fair value. Expense is recognized on a straight-line basis over the requisite service period (generally the vesting period of the award) as either other operating and maintenance expense or general and administrative expense in the consolidated statements of operations. We have elected to account for forfeitures as they occur. Therefore, compensation cost previously recognized for an award that is forfeited because of failure to satisfy a service condition will be reversed in the period of the forfeiture. RSUs include dividend equivalent rights that permit holders of granted but unvested RSUs to receive nonforfeitable distributions alongside common equity holders of the Company as if such RSUs were granted as of the applicable record date for such distribution.

Refer to Note 10 — Share-Based Compensation for additional information.

Earni ngs Per Share Attributable to LandBridge

We use the two-class method in our computation of earnings per share. Our RSUs include dividend equivalent rights that permit holders of granted but unvested RSUs to receive a non-forfeitable cash amount equal in value to dividends paid with respect to a specified number of shares and are contemplated as participating when the Company is in a net income position. These awards participate in dividend equivalents on a basis equivalent to other Class A shares but do not participate in losses. Class B shares do not have economic rights and are not entitled to participate in any dividends our board of directors may declare but are entitled to vote on the same basis as the Class A shares.

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Notes to the Consolidated Financial Statements (Continued)

Basic earnings (loss) per share (“EPS”) of our Class A shares is computed on the basis of the weighted average number of shares outstanding during each period. The diluted EPS of our Class A shares contemplates adjustments to the numerator and the denominator under the if-converted method for the convertible Class B shares. The Company uses the treasury stock method or two-class method when evaluating dilution for RSUs. The more dilutive of the two methods is included in the calculation for diluted EPS. Refer to Note 11 — Earnings Per Share for additional information.

Revenue Recognition

Surface use royalties

The Company enters into surface use royalty agreements that generate recurring surface use royalty revenue. When we execute a surface use royalty agreement, it generally transfers all rights of use of the surface acreage as specified in the agreement and grants us the right to a royalty calculated on the basis of use, gross revenues or volumetric use. Surface use royalties, include but are not limited to, produced water handling and throughput royalties, skim oil royalties, and waste and reclamation royalties. Surface use royalty revenue includes variable consideration that is dependent upon volumetric use and is typically constrained at the inception of the agreement but is resolved when volumes are produced and settled. Surface use royalty payments are typically received one month following the month of production. The Company accrues surface use royalties produced but not yet paid based on historical or estimated basis of the royalty and contract prices. The difference between estimated and actual amounts received for royalties are recorded in the period the payment is received. Refer to Note 3 – Additional Financial Statement Information for additional information regarding amounts accrued on the consolidated statements of operations.

Easements and other surface-related income

Easement and other surface use agreement contracts permit operators to install pipelines, roadways, electric lines, and other equipment on land owned by the Company. When the Company executes the contract, receives payment and the contract becomes effective, we make available the respective parcel of land to the grantee. Revenue is recognized upon the execution of the agreement at the effective date as the performance obligation has been satisfied and the customer has right of use. In the event of a renewal of an existing contract, the Company recognizes the revenue upon receipt of the renewal payment and the contract becomes effective. At that point, the Company has satisfied its performance obligation and control has been transferred to the grantee. Refer to Note 3 – Additional Financial Statement Information for additional information regarding amounts accrued on the consolidated statements of operations.

In certain instances, these contracts may include a provision for royalties. Royalties associated with the use of surface acreage are included in surface use royalties above.

Resource sales and royalties

Resource sales generally includes brackish water and other surface, composite material, such as caliche, that the Company sells to E&P companies and other customers. Resource sales revenue is generally recognized upon delivery of the brackish water or other surface material as the Company's performance obligation has been deemed satisfied at that point in time. In certain instances, a third party other than a customer may be involved in a resource sale transaction, such as a revenue sharing agreement or brokered sale transaction. In these instances, the Company will either act as the principal or the agent in the transaction. If the Company is deemed to be acting as the principal, the revenues are reported on a gross basis in resource sales and corresponding costs reported as resource sales-related expense. If the Company is deemed to be acting as the agent, revenue is recorded net of the corresponding costs and included in the resource sales lines of the consolidated statements of operations. The Company enters into resource royalty agreements that generate recurring resource royalty revenue. When we execute a resource royalty agreement, it generally transfers all rights to explore and produce a resource as specified in the agreement and grants us the right to a royalty on future production of that resource. Resource royalty agreements include, but are not limited to, sand, brackish water, and other resources that can be extracted from the Company's surface estate. Resource royalty revenue includes variable consideration that is dependent upon production from those resources, which is typically constrained at the inception of the agreement but is resolved when volumes are produced and settled. Resource royalty payments are typically received one month following the month of production. The Company accrues resource royalties produced but not yet paid based on historical or estimated royalty production and contract prices. The difference between estimated and actual amounts received for royalties are recorded in the period the payment is received. Refer to Note 3 – Additional Financial Statement Information for additional information regarding amounts accrued on the consolidated statements of operations.

In certain instances, resource royalty contracts provide for a bonus payment. These bonus payments are nonrefundable. Resource royalty bonus revenues are recognized when the agreement is executed as control is transferred and the Company has satisfied its performance obligation at that point in time.

93

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Notes to the Consolidated Financial Statements (Continued)

Oil and gas royalties

Oil and gas royalties are received in connection with oil and natural gas mineral interests owned by the Company. Oil and gas royalties are recognized as revenue as oil and gas are produced or severed from the mineral lease. The oil and gas royalties we receive includes variable consideration that is dependent upon market prices for oil and gas, and producer specific location and contractual price differences. As a result, our oil and gas royalty revenues are typically constrained at the inception of the contract but will be resolved once volumes are produced and settled. Oil and gas royalty payments are typically received one to three months following the month of production. The Company accrues oil and gas royalties produced but not yet paid based on historical or estimated royalty interest production and current market prices, net of estimated location and contract pricing differentials. The difference between estimated and actual amounts received for oil and gas royalties are recorded in the period the payment is received. Refer to Note 3 – Additional Financial Statement Information for additional information regarding amounts accrued on the consolidated statements of operations.

Oil and gas royalties also include mineral lease bonus revenues. The Company receives lease bonus revenue by leasing its mineral interests to exploration and production (“E&P”) companies. When we execute a mineral lease contract, it generally transfers the rights to any oil or gas discovered to the E&P company and grants us the right to a specified royalty interest payable on future production. Mineral lease bonuses are nonrefundable. Mineral lease bonus revenues are recognized when the agreement is executed as control is transferred and the Company has satisfied its performance obligation at that point in time.

Contract Liabilities

Contract liabilities primarily relate to revenue sharing arrangements or other surface use agreements where the Company may receive payments from customers in advance of the related performance obligation being satisfied. Contract liabilities are recognized as earned over time or at a point in time based on the provisions set forth in the agreement. Current and non-current contract liabilities are presented in other current liabilities and other long-term liabilities on the consolidated balance sheets, respectively.

Income Taxes

The Company has elected to be treated as a corporation for U.S. federal income tax purposes and is subject to U.S. federal and state corporate income taxes. The Company had no activity or holdings prior to the IPO. U.S. federal income tax expense (benefit) included in the consolidated statements of operations is calculated primarily based on the Company's share of net income (loss) of OpCo, which is taxed as a partnership. State income tax expense (benefit) included in the consolidated statements of operations is primarily based on the Texas Franchise Tax liability applicable to the Company and OpCo on a consolidated basis.

OpCo is treated as a partnership, or, prior to the IPO, a disregarded entity, for U.S. federal income tax purposes, and therefore, has not been subject to U.S. federal income tax at an entity level. As a result, the consolidated net income (loss) in our historical financial statements does not reflect the tax expense (benefit) we would have incurred if we were subject to U.S. federal income tax at an entity level during the periods prior to the IPO. OpCo continues to be treated as a partnership for U.S. federal income tax purposes, and as such, is not subject to U.S. federal income tax. Instead, taxable income is allocated to members, including the Company, and taxable income (loss) of OpCo is reported in the respective tax returns of its members.

Provisions for income taxes are based on taxes payable or refundable for the current year and deferred taxes on temporary differences between the tax basis of assets and liabilities and their reported amounts in our Financial Statements. Deferred tax assets and liabilities are included in our Financial Statements at currently enacted income tax rates applicable to the period in which the deferred tax assets and liabilities are expected to be realized or settled. As changes in tax laws or rates are enacted, deferred tax assets and liabilities are adjusted through the current period’s provision for income taxes.

The Company evaluates the realizability of our deferred tax assets as of each reporting date, weighing all positive and negative evidence. A valuation allowance is recorded to reduce the carrying value of our deferred tax assets when it is more likely than not that some or all of our deferred tax assets will not be realized. Refer to Note 7 – Income Taxes for additional information.

Concentrations of Risk

In the normal course of business, we maintain cash balances in excess of federally insured limits. The Company regularly monitors these institutions’ financial condition. We have not experienced any losses in our accounts and believe we are not exposed to any significant credit risk on cash or cash equivalents.

94

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

Significant Customers

Customers that individually comprised more than 10% of the Company’s consolidated revenues were as follows:

|  | Year Ended December 31,
|  | 2025 |  | 2024 |  | 2023
Customer A |  | 25% |  | 24% |  | 13%
Customer B |  | 12% |  | -% |  | -%
Customer C |  | 10% |  | 14% |  | 15%
Customer D |  | ** |  | 10% |  | 14%
Customer E |  | ** |  | ** |  | 13%

## **Less than 10%

## Other Contingencies

## The Company recognizes liabilities for other contingencies when there is exposure that indicates it is both probable and the amount of loss can be reasonably estimated. These types of liabilities may also arise from acquisition related transactions or other commercial agreements entered into from time to time by the Company. Refer to Note 13 – Commitments and Contingencies for additional information on specific contingent liabilities.

## Recently Adopted Accounting Pronouncements

## In December of 2023, the FASB issued ASU 2023-09, Income Taxes (Topic 740). This guidance further enhances income tax disclosures, primarily through standardization and disaggregation of rate reconciliation categories and income taxes paid by jurisdiction. This ASU was effective for annual periods beginning after December 15, 2024. The adoption of ASU 2023-09 had no effect on the Company's financial position, results of operations or cash flows as it modified disclosure requirements only. The Company adopted the ASU retrospectively for the year ended December 31, 2025, with comparative period income tax disclosures adjusted to reflect the change in accounting guidance. Refer to Note 7 – Income Taxes for additional information.

Recent Accounting Pronouncements Not Yet Adopted

## In November 2024, the FASB issued ASU 2024-03, Income Statement-Reporting Comprehensive Income-Expense Disaggregation Disclosures (Subtopic 220-40). This guidance requires tabular disclosure of specified natural expenses in certain expense captions, a qualitative description of amounts that are not separately disaggregated, and disclosure of the Company's definition and total amount of selling expenses. We plan to adopt this guidance and conform with the disclosure requirements when it becomes mandatorily effective for annual periods beginning after December 15, 2026. The adoption of ASU 2024-03 is not expected to have any effect on the Company’s financial position, results of operations or cash flows as it modifies disclosure requirements only.

3. Additional Financial Statement Information

Other balance sheet information is as follows:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |
Accrued liabilities |  |  |  |  |  |
Accrued interest |  | $ | 3,554 |  |  | $ | 3,795 |
Accrued professional fees |  |  | 2,571 |  |  |  | 1,459 |
Accrued property taxes |  |  | 586 |  |  |  | 616 |
Accrued payroll |  |  | 545 |  |  |  | 280 |
Accrued operating and capital expenses |  |  | 525 |  |  |  | 1,035 |
Total accrued liabilities |  | $ | 7,781 |  |  | $ | 7,185 |

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LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

Other income statement information is as follows related to accrued revenue amounts within the consolidated statements of operations:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |  |  | 2023 |
Accrued Revenue |  |  |  |  |  |  |  |  |
Surface use royalties |  | $ | 2,469 |  |  | $ | 2,033 |  |  | $ | 674 |
Surface use royalties - Related party |  |  | 3,763 |  |  |  | 2,054 |  |  |  | 826 |
Easements and other surface-related revenues |  |  | 2,545 |  |  |  | 2,755 |  |  |  | 1,692 |
Easements and other surface-related revenues - Related party |  |  | 14 |  |  |  | 3 |  |  |  | 51 |
Resource sales |  |  | 2,559 |  |  |  | 1,282 |  |  |  | 642 |
Resource sales - Related party |  |  | 218 |  |  |  | 18 |  |  |  | 113 |
Resource royalties |  |  | 875 |  |  |  | 1,170 |  |  |  | 610 |
Resource royalties - Related party |  |  | 625 |  |  |  | 415 |  |  |  | - |
Oil and gas royalties |  |  | 1,595 |  |  |  | 1,680 |  |  |  | 3,241 |
Other |  |  | 3,980 |  |  |  | - |  |  |  | - |
Total accrued revenue |  | $ | 18,643 |  |  | $ | 11,410 |  |  | $ | 7,849 |

Supplemental cash flow information is as follows:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |  |  | 2023 |
Supplemental cash flow information: |  |  |  |  |  |  |  |  |
Cash paid for income taxes |  | $ | 8,730 |  |  | $ | 385 |  |  | $ | 213 |
Cash paid for interest |  | $ | 26,963 |  |  | $ | 19,677 |  |  | $ | 5,914 |
Non-cash investing and financing activities: |  |  |  |  |  |  |  |  |
Class B Shares issued for acquisition |  | $ | 53,586 |  |  | $ | - |  |  | $ | - |
Offering costs in accrued liabilities |  | $ | - |  |  | $ | 545 |  |  | $ | 1,997 |
Acquisition and capital expenditures in accounts payable and accrued liabilities |  | $ | 450 |  |  | $ | 896 |  |  | $ | - |
Insurance financing |  | $ | 819 |  |  | $ | 464 |  |  | $ | 350 |
Asset financing |  | $ | 62 |  |  | $ | - |  |  | $ | 251 |

4. Asset Acquisitions

On November 12, 2025, OpCo acquired approximately 38,000 total acres across Reeves, Loving, Winkler and Ward counties, Texas, and certain related assets from 1918 Ranch & Royalty, LLC (the “1918 Ranch Acquisition”) for total purchase consideration of $263.9 million, inclusive of transaction costs. The acreage acquired consists of approximately 22,400 fee simple acres, approximately 12,000 leasehold acres and approximately 3,600 acres subject to a long-term management agreement. The purchase consideration consisted of (i) approximately $208.5 million in cash and (ii) 657,411 OpC o Units (together with an equal number of Class B shares) valued at $53.6 million. The fair value of the OpCo Units was determined based on the closing price of the Company’s Class A shares on the date of acquisition. Refer to Note 8 - Debt and Note 9 - Shareholders’ and Member’s Equity for further information regarding funding of the purchase price. The purchase consideration was allocated based on relative fair value to land value of $158.8 million, surface use agreements of $97.1 million and brackish water supply assets of $8.0 million.

On April 11, 2025, the Company acquired approximately 800 surface acres in Reeves County, Texas, from a private third-party seller for total purchase consideration of $0.7 million, inclusive of transaction costs. The purchase consideration was all attributed to land value.

On February 25, 2025, the Company acquired approximately 3,000 surface acres in Lea County, New Mexico, from a private third-party seller for total purchase consideration of $17.1 million inclusive of transaction costs. The purchase consideration was all attributed to land value.

On December 19, 2024, the Company acquired approximately 46,000 surface acres in Reeves and Pecos County, Texas from a private, third-party seller, for total purchase consideration of $246.8 million, inclusive of transaction costs (the “Wolf Bone Acquisition”). The purchase consideration was all attributed to land value.

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Notes to the Consolidated Financial Statements (Continued)

On November 22, 2024, the Company acquired approximately 5,820 surface acres in Lea County, New Mexico from a private, third-party seller, for total purchase consideration of $26.8 million, inclusive of transaction costs. The purchase consideration was attributed to land value of $18.9 million, intangible asset value of $5.1 million and other assets of $2.7 million.

On November 1, 2024, the Company acquired approximately 1,280 surface acres in Winkler County, Texas, supply water assets and a related commercial contract from a private, third-party seller for total purchase consideration of $20.5 million, inclusive of transaction costs. Of the $20.5 million total purchase consideration, $1.1 million was retained by the Company and is payable to seller within one year, contingent on no pre-closing liabilities being identified. The total purchase consideration was attributed to intangible asset value of $13.6 million, supply water assets of $4.0 million, land value of $3.8 million, other assets of $0.2 million and an assumed liability of $1.1 million.

On May 10, 2024, the Company acquired approximately 103,000 surface acres in the Loving and Winkler counties, Texas, and Lea County, New Mexico from a private third-party seller, for total purchase consideration of $362.6 million, inclusive of transaction costs. The purchase consideration was attributed to land value of $359.7 million and other assets of $2.9 million.

On May 10, 2024, the Company acquired approximately 34,000 surface acres in Lea County, New Mexico and Andrews County, Texas from the same private third-party seller, for total purchase consideration of $42.2 million, inclusive of transaction costs. The purchase consideration was all attributed to land value.

On March 18, 2024, the Company acquired approximately 11,000 acres of land in Lea County, New Mexico for total purchase consideration of $26.4 million, inclusive of transaction costs. The purchase consideration was attributed to land value of $25.9 million and intangible asset value of $0.5 million.

5. Property, Plant and Equipment

Property, plant and equipment, net of accumulated depreciation and depletion consisted of the following:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |
Oil and natural gas properties |  |  |  |  |  |
Proved |  | $ | 36,179 |  |  | $ | 36,068 |
Unproved |  |  | 2,932 |  |  |  | 3,043 |
Total oil and natural gas properties |  |  | 39,111 |  |  |  | 39,111 |
Land and land improvements |  |  | 1,031,128 |  |  |  | 855,092 |
Water wells, pipelines, facilities, ponds and related equipment |  |  | 29,981 |  |  |  | 21,109 |
Buildings, vehicles, equipment, furniture and other |  |  | 7,778 |  |  |  | 5,162 |
Construction in progress |  |  | 107 |  |  |  | 14 |
|  |  | 1,108,105 |  |  |  | 920,488 |
Less: accumulated depreciation and depletion |  |  | (23,655 | ) |  |  | (17,746 | )
Total property, plant and equipment, net |  | $ | 1,084,450 |  |  | $ | 902,742 |

Depreciation expense and depletion expense for the years ended December 31, 2025, 2024 and 2023 are shown in the following table:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |  |  | 2023 |
Depreciation expense |  | $ | 3,289 |  |  | $ | 2,616 |  |  | $ | 2,357 |
Depletion expense |  |  | 2,740 |  |  |  | 3,575 |  |  |  | 4,050 |
Total depreciation and depletion expense |  | $ | 6,029 |  |  | $ | 6,191 |  |  | $ | 6,407 |

97

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

6. Intangible Assets

Intangible assets, net of accumulated amortization consisted of the following:

| Year Ended December 31, |
| 2025 |  |  | 2024 |
Water contracts | $ | 28,556 |  |  | $ | 28,556 |
Surface use agreements |  | 121,385 |  |  |  | 24,247 |
Subtotal |  | 149,941 |  |  |  | 52,803 |
Less: accumulated amortization |  | (12,979 | ) |  |  | (7,538 | )
Total intangible assets, net | $ | 136,962 |  |  | $ | 45,265 |
| Year Ended December 31, |
Accumulated amortization | 2025 |  |  | 2024 |
Water contracts | $ | 6,476 |  |  | $ | 3,516 |
Surface use agreements |  | 6,503 |  |  |  | 4,022 |
Total accumulated amortization | $ | 12,979 |  |  | $ | 7,538 |

On November 12, 2025, the Company acquired surface use agreements as part of the 1918 Ranch Acquisition. The purchase consideration attributable to the contracts was approximately $97.1 million, which will be amortized over a term of 15 years.

On November 22, 2024, the Company acquired surface use agreements as part of an acquisition of land in Lea County, New Mexico. The purchase consideration attributable to the surface use agreements was approximately $5.1 million, which will be amortized over a term of 15 years.

On November 1, 2024, the Company acquired a water contract as part of an acquisition of land in Winkler County, Texas. The purchase consideration attributable to the water contract was approximately $13.6 million, which will be amortized over a term of 7 years.

On March 18, 2024, the Company acquired a surface use agreement as part of an acquisition of land in Lea County, New Mexico. The purchase consideration attributable to the surface use agreement was approximately $0.5 million, which will be amortized over a term of 30 years.

The Company recognized $5.4 million, $2.6 million and $2.2 million in amortization expense for the years ended December 31, 2025, 2024 and 2023, respectively. The remaining weighted average amortization period for the surface use agreements and water contracts was 13.5 years and 10.9 years as of December 31, 2025 and 2024, respectively.

Future amortization expense related to such intangibles for the next five years and thereafter as of December 31, 2025 is as follows:

| Amortization Expense |
2026 | $ | 11,035 |
2027 |  | 11,035 |
2028 |  | 11,035 |
2029 |  | 11,035 |
2030 |  | 11,035 |
Thereafter |  | 81,787 |
Total | $ | 136,962 |

7. Income Taxes

Our predecessor, OpCo, is a Delaware limited liability company treated as a partnership for U.S. federal income tax purposes and, therefore, has not been subject to U.S. federal income tax at an entity level. As a result, the consolidated net income in our historical financial statements does not reflect the tax expense we would have incurred if we were subject to U.S. federal income tax at an entity

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LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

level during the periods prior to the IPO. Instead, taxable income is allocated to members, including the Company, and, except for Texas franchise tax, any taxable income of OpCo is reported in the respective tax returns of its members.

Income Tax Provision

The components of income tax expense (benefit) are as follows:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |  |  | 2023 |
Current tax expense |  |  |  |  |  |  |  |  |
Federal |  | $ | 3,900 |  |  | $ | 1,693 |  |  | $ | - |
State |  |  | 1,082 |  |  |  | 593 |  |  |  | 370 |
Total current tax expense |  |  | 4,982 |  |  |  | 2,286 |  |  |  | 370 |
Deferred tax expense (benefit) |  |  |  |  |  |  |  |  |
Federal |  |  | 3,995 |  |  |  | (406 | ) |  |  | - |
State |  |  | 89 |  |  |  | (5 | ) |  |  | - |
Total deferred tax expense (benefit) |  |  | 4,084 |  |  |  | (411 | ) |  |  | - |
Total income tax expense |  | $ | 9,066 |  |  | $ | 1,875 |  |  | $ | 370 |

More than 50% of the effect of the state and local income taxes recorded for the years ended December 31, 2025 and December 31, 2024 are attributable to the state of Texas.

Effective Tax Rate

The Company's overall effective tax rate differs from the U.S statutory rate primarily due to the fact that prior to the IPO, OpCo was structured as a partnership for U.S. federal income tax and subsequent to the IPO, the OpCo income (loss) attributable to the noncontrolling interests in OpCo is not subject to U.S. federal income tax at the Company or OpCo.

The reconciliation of income taxes at the federal statutory level to provision for income taxes is as follows:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |  |  | 2023 |
|  | $ |  |  | % |  |  | $ |  |  | % |  |  | $ |  |  | % |
U.S. federal statutory income tax rate |  | $ | 17,108 |  |  |  | 21.0 | % |  | $ | (8,317 | ) |  |  | 21.0 | % |  | $ | 13,344 |  |  |  | 21.0 | %
State tax, net of federal benefit |  |  | 996 |  |  |  | 1.2 | % |  |  | 566 |  |  |  | (1.4 | %) |  |  | 370 |  |  |  | 0.6 | %
Pre-IPO non-taxable loss (income) |  |  | - |  |  |  | 0.0 | % |  |  | 9,794 |  |  |  | (24.7 | %) |  |  | (13,344 | ) |  |  | (21.0 | %)
Noncontrolling interests |  |  | (8,806 | ) |  |  | (10.8 | %) |  |  | (168 | ) |  |  | 0.4 | % |  |  | - |  |  |  | 0.0 | %
REIT built-in gains tax |  |  | 123 |  |  |  | 0.1 | % |  |  | - |  |  |  | 0.0 | % |  |  | - |  |  |  | 0.0 | %
Other adjustments |  |  | (355 | ) |  |  | (0.4 | %) |  |  | - |  |  |  | 0.0 | % |  |  | - |  |  |  | 0.0 | %
Total effective tax rate |  | $ | 9,066 |  |  |  | 11.1 | % |  | $ | 1,875 |  |  |  | (4.7 | %) |  | $ | 370 |  |  |  | 0.6 | %

Income Taxes Paid by Jurisdiction

The Company’s total cash paid for income taxes, by jurisdiction is as follows:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |  |  | 2023 |
Federal |  | $ | 8,027 |  |  | $ | - |  |  | $ | - |
State |  |  | 703 |  |  |  | 385 |  |  |  | 213 |
Total income taxes paid |  | $ | 8,730 |  |  | $ | 385 |  |  | $ | 213 |

99

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

Deferred Tax Assets and Liabilities

The tax effects of temporary differences that give rise to our deferred tax assets and liabilities are as follows:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |
Deferred tax assets |  |  |  |  |  |
Investment in partnership |  | $ | 82,069 |  |  | $ | 29,188 |
Disallowed interest carryforward |  |  | - |  |  |  | 228 |
Total deferred tax assets |  |  | 82,069 |  |  |  | 29,416 |
Deferred tax liabilities |  |  | - |  |  |  | - |
Valuation allowance |  |  | (1,096 | ) |  |  | - |
Net deferred tax assets |  | $ | 80,973 |  |  | $ | 29,416 |

The Company recorded a deferred tax asset on its investment in OpCo due to an increase in tax basis on its investment in OpCo in connection with historical redemptions and exchanges of Class B Shares by members of OpCo for Class A Shares in the Company. As of December 31, 2025, the Company determined it is unlikely to realize all tax benefits associated with the prior tax basis step-up and as a result has recorded a partial valuation allowance of $1.1 million against its deferred tax assets.

During the year ended December 31, 2025, members of OpCo redeemed 4.4 million OpCo Units (together with the cancellation of 4.4 million of Class B Shares) for an equivalent amount of Class A Shares and subsequently sold the Class A shares to the public. The Company did not receive any proceeds from the sale of the Class A Shares. The redemption and exchange of these OpCo Units is treated as a taxable purchase by the Company. As a result of the purchases the Company's tax basis in OpCo increased and the Company recorded a deferred tax asset of $55.4 million, net of the partial valuation allowance, as this increase is expected to be recovered through future amortization deductions afforded to the Company. Because the deferred tax asset arose in connection with a transaction between the Company and shareholders, the initial deferred tax asset, as well as the impact of the partial valuation allowance, is recorded in Class A Shares on the consolidated balance sheets. Refer to Note 9 - Shareholders’and Member’s Equity.

Additionally, for the year ended December 31, 2024 the Company adjusted its deferred tax assets related to it’s investment in OpCo to reflect the deferred tax asset of $29.4 million generated from the step-up in tax basis associated with the December 2024 Private Placement. Refer to Note 2 - Summary of Significant Accounting Policies.

The Company evaluates uncertain tax positions for recognition and measurement in the financial statements. To recognize a tax position, the Company determines whether it is more likely than not that the tax position will be sustained upon examination. A tax position that meets the more likely than not threshold is measured to determine the amount of benefit to be recognized in the financial statements. As of December 31, 2025 and 2024, the Company has no significant uncertain tax positions.

The Company files income tax returns in the U.S. federal jurisdiction and New Mexico on a separate basis. The Company and OpCo file the Texas Franchise Tax on a consolidated basis. There are currently no federal or state income tax examinations underway for these jurisdictions. The Company's federal and state returns remain open to examination for tax years 2021 through 2024.

On July 4, 2025, the OBBBA was signed into law which makes permanent many of the tax provisions enacted in 2017 as part of the Tax Cuts and Jobs Act that were set to expire at the end of 2025. The Company has evaluated the impact of the legislation and has concluded it does not have a material impact on the results of operations.

100

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

8. Debt

As of December 31, 2025 and 2024, our debt consisted of the following:

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |
Notes |  | $ | 500,000 |  |  | $ | - |
Term loan |  |  | - |  |  |  | 355,000 |
Revolving credit facility |  |  | 70,000 |  |  |  | 30,000 |
Other |  |  | 726 |  |  |  | 496 |
Total debt |  |  | 570,726 |  |  |  | 385,496 |
Current portion of long-term debt |  |  | (692 | ) |  |  | (424 | )
Unamortized debt issuance costs |  |  | (10,441 | ) |  |  | (4,257 | )
Total long-term debt |  | $ | 559,593 |  |  | $ | 380,815 |

## Notes

On November 25, 2025, OpCo, as the issuer, issued $500.0 million aggregate principal amount of 6.25% fixed-rate senior unsecured notes due 2030 (the “Notes”).

In connection with the offering of the Notes, OpCo and each of the Guarantors (as defined below) entered into an indenture, dated as of November 25, 2025 (the “Indenture”), with UMB Bank, N.A., as trustee, relating to the issuance of the Notes. The Indenture contains customary terms, events of default and covenants relating to, among other things, the incurrence of debt, the payment of dividends or similar restricted payments, undertaking transactions with OpCo’s unrestricted affiliates, and limitations on asset sales.

The Notes are guaranteed (the “Guarantees”), jointly and severally, on a senior unsecured basis by all of OpCo’s existing subsidiaries (collectively, the “Guarantors”).

At any time prior to December 1, 2027, OpCo may on any one or more occasions redeem up to 40% of the aggregate principal amount of the Notes (including any additional notes) issued under the Indenture at a redemption price equal to 106.25% of the principal amount of the Notes redeemed, plus accrued and unpaid interest, if any, to, but excluding, the redemption date, with an amount of cash not greater than the net cash proceeds of one or more equity offerings. At any time after December 1, 2027, OpCo may also redeem all or a part of the Notes of such series at a redemption price equal to 100% of the principal amount of the Notes redeemed plus the applicable premium set forth in the Indenture, plus accrued and unpaid interest, if any, to, but excluding, the redemption date.

If a Change of Control (as defined in the Indenture) occurs with respect to any series of notes (along with a downgrade of the notes by two rating agencies), OpCo may be required to offer to purchase the Notes at a purchase price equal to 101% of the principal amount, plus accrued and unpaid interest, if any, to the purchase date.

The Notes and the Guarantees rank equally in right of payment with all of OpCo’s and the Guarantors’ existing and future senior indebtedness and senior to all of the OpCo’s and the Guarantors’ future subordinated indebtedness. The Notes and the Guarantees are effectively subordinated in right of payment to all of OpCo’s and the Guarantors’ existing and future secured debt, including debt under OpCo’s 2025 Revolving Credit Facility (as defined below), to the extent of the value of the assets securing such debt, and will be structurally subordinated to all liabilities of any future subsidiaries of OpCo’s that do not guarantee the Notes.

On November 25, 2025, the Company used the net proceeds of $491.9 million from the issuance of the Notes, $70.0 million of borrowings under the 2025 Revolving Credit Facility (as defined below), and $4.8 million of cash on hand to repay all outstanding borrowings and accrued interest under the 2023 Credit Agreement (as defined below). At the time of repayment, the outstanding borrowings and accrued interest totaled $564.5 million. The remaining proceeds were used to pay $2.1 million of syndication and legal fees. As a result of the repayment, the Company recorded a loss on extinguishment of debt of $4.4 million which is included in other income (loss) on the consolidated statements of operations.

At December 31, 2025, our fixed-rate senior unsecured notes had a carrying value of $500.0 million and a fair value of $506.9 million. The fair value was determined based on observable market prices of identical instruments in less active markets and is categorized accordingly as Level 2 in the fair value hierarchy.

101

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

## 2025 Revolving Credit Facility

On November 18, 2025, OpCo entered into a revolving credit agreement (the “2025 Revolving Credit Facility”) which provides for lender commitments of $275.0 million and matures on the earlier of (a) June 30, 2030, and (b) the date that is 91 days prior to the stated maturity of the Notes, if, on such date, the outstanding principal amount of the Notes is greater than $50 million (the “Maturity Date”). Borrowings under the 2025 Revolving Credit Facility are secured by a first-priority lien on substantially all assets of OpCo and its subsidiaries, and is also guaranteed by each of its subsidiaries. As of December 31, 2025, the Company had $70.0 million outstanding borrowings under the 2025 Revolving Credit Facility. The weighted average interest rate on the total amount of borrowings under the 2025 Revolving Credit Facility as of December 31, 2025 was 6.13%.

The 2025 Revolving Credit Facility replaced the 2023 Credit Agreement (as defined below) and in accordance with ASC 470-50, Debt Modifications and Extinguishments, the Company concluded that the 2025 Revolving Credit Facility should be accounted for as a debt modification. As a result, the debt issuance costs of $2.2 million incurred as part of the 2025 Revolving Credit Facility along with the remaining debt issuance costs of $0.7 million, associated with the 2023 Credit Agreement as of the modification date will be amortized over the life of the 2025 Revolving Credit Facility.

Short-term debt issuance costs of $0.6 million and $0.5 million associated with the 2025 Revolving Credit Facility and 2023 Credit Agreement as of December 31, 2025 and 2024, respectively, are deferred and presented in prepaid expenses and other current assets on the consolidated balance sheets. Long-term debt issuance costs of $2.2 million and $0.7 million associated with the 2025 Revolving Credit Facility and 2023 Credit Agreement as of December 31, 2025 and 2024, respectively, are deferred and presented in other assets on the consolidated balance sheets.

The 2025 Revolving Credit Facility provides for revolving borrowings subject to compliance with various financial and other covenants common in such agreements that apply to OpCo and its restricted subsidiaries, including (i) a minimum interest coverage ratio of 2.50:1.00, (ii) a maximum total net leverage ratio of 5.00:1.00, provided that the maximum total net leverage ratio may step up to 5.25:1.00 for the fiscal quarter in which a Permitted Acquisition (as defined in the 2025 Revolving Credit Facility) occurs and the two fiscal quarters following, and (iii) a maximum senior secured net leverage ratio of 3.50:1.00, in each case, measured as of the end of each fiscal quarter.

These covenants are subject to exceptions and qualifications provided in the 2025 Revolving Credit Facility, including the ability to make unlimited restricted payments subject to (i) a maximum net total leverage ratio of less than 4.50:1.00, (ii) minimum liquidity of 5% (with “liquidity” including unrestricted cash on hand of OpCo and its subsidiaries plus availability under the 2025 Revolving Credit Facility), and (iii) such other restricted payments customarily permitted for publicly traded companies with a similar market capitalization as the Company.

Principal amounts borrowed under the 2025 Revolving Credit Facility may be prepaid from time to time and commitments thereunder may be terminated without premium or penalty. Any principal amounts outstanding on the Maturity Date will become due and payable on such date.

At OpCo’s election, principal amounts under the 2025 Revolving Credit Facility may be borrowed as Term SOFR Loans or Base Rate Loans. Term SOFR Loans under the 2025 Revolving Credit Facility bear interest at a variable rate equal to Term SOFR for the applicable tenor plus a leverage-based applicable margin between 2.00% and 3.00% per annum. Interest on all outstanding Term SOFR Loans is payable on the last business day of the applicable interest period. Base Rate Loans under the 2025 Revolving Credit Facility bear interest at a rate per annum equal to (x) the highest of (i) the rate of interest published by The Wall Street Journal, (ii) the Federal Funds Rate, as in effect from time to time, plus 0.50%, and (iii) Term SOFR for a one-month tenor plus 1.00%, in each case plus a leverage-based applicable margin between 1.00% and 2.00% per annum. Interest on all outstanding Base Rate Loans is payable quarterly in arrears. OpCo will also pay a commitment fee between 0.375% and 0.50% based on the undrawn commitment amounts under the 2025 Revolving Credit Facility.

102

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

2023 Credit Agreement

On July 3, 2023, DBR Land, L LC, a Delaware limited liability company and a subsidiary of the Company (the “Borrower”), entered into a credit agreement (as amended prior to the date hereof, the “2023 Credit Agreement”) with the guarantors party thereto, the lenders party thereto, and Texas Capital Bank, as administrative agent and letter of credit issuer, which initially provided for (i) a four-year $100.0 million term loan (the “Term loan”) and (ii) a $50.0 million revolving credit facility, each of which matures on July 3, 2027. We subsequently amended to, among other things, increase the principal amount of the term loan to $355.0 million and increase the available capacity of the revolving credit facility to $100.0 million.

On October 3, 2025 (the “Third Amendment Effective Date”), the Borrower entered into the Third Amendment to Credit Agreement (the “Third Amendment”) to amend the 2023 Credit Agreement and provide for a new delayed draw term loan facility with total commitments of $200.0 million for the purpose of partially financing the 1918 Ranch Acquisition and to pay certain related costs and expenses (the “DDTL Facility”). On November 10, 2025, the Borrower drew in full the $200.0 million available under the DDTL Facility. The DDTL Facility included an unused commitment fee of 37.5 basis points that accrued from the Third Amendment Effective Date until November 10, 2025, applied to the average daily unused amount of the DDTL Facility.

Under the 2023 Credit Agreement, the Borrower could elect for outstanding borrowings under our credit facility to accrue interest at a rate based on either (i) a forward-looking term rate based on the secured overnight financing rate (“Term SOFR”) plus 0.10%, or (ii) the base rate, in each case plus an applicable margin. The applicable margin ranged from (i) prior to the consummation of the IPO, 3.00% to 4.00% in the case of Term SOFR loans an d letter of credit fees, and 2.00% to 3.00% in the case of base rate loans, and commitments fees of 0.50%, and (ii) following consummation of the IPO, 2.75% to 3.75% in the case of Term SOFR loans and letter of credit fees, and 1.75% to 2.75% in the case of base rate loans, and commitment fees ranged from 0.375% to 0.50%.

The weighted average interest rate on the total amount of borrowings under the 2023 Credit Agreement prior to its termination during the year ended December 31, 2025 and as of December 31, 2024, was 7.65% and 8.39% in the case of the revolving credit borrowings and 7.56% and 8.47% in the case of term loan borrowings, respectively.

The 2023 Credit Agreement was terminated on November 25, 2025 in connection with the effectiveness of the Notes and 2025 Revolving Credit Facility. The accrued interest payable related to the 2023 Credit Agreement was zero and $3.4 million as of December 31, 2025 and 2024, respectively.

## Debt Maturities

The following table summarizes the Company’s debt obligations as of December 31, 2025. Estimated future payments for the debt based on the amount outstanding are shown below:

|  | As of December 31, |
|  | 2026 |  |  | 2027 |  |  | 2028 |  |  | 2029 |  |  | 2030 |  |  | Total |
Notes |  | $ | - |  |  | $ | - |  |  | $ | - |  |  | $ | - |  |  | $ | 500,000 |  |  | $ | 500,000 |
Revolving credit facility |  |  | - |  |  |  | - |  |  |  | - |  |  |  | - |  |  |  | 70,000 |  |  |  | 70,000 |
Other |  |  | 692 |  |  |  | 20 |  |  |  | 14 |  |  |  | - |  |  |  | - |  |  |  | 726 |
Total debt |  | $ | 692 |  |  | $ | 20 |  |  | $ | 14 |  |  | $ | - |  |  | $ | 570,000 |  |  | $ | 570,726 |

9. Shareholders’ and Member’s Equity

Shareholders’ Equity

Holders of Class A shares and Class B shares vote together as a single class on all matters presented to our shareholders, except as otherwise required by applicable law or by the A&R LLC Agreement. Class B shares are not entitled to participate in any dividends our Board may declare.

Member’s Equity

Prior to the Division, NDB LLC held 100% of the limited liability company interests of OpCo. OpCo’s limited liability company interests were generally consistent with ordinary equity ownership interests. Distributions (including liquidating distributions) were to be made to the sole member at a time to be determined by the board of managers. There were no restrictions on distributions. The sole

103

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

member’s equity account was adjusted for distributions paid to, and additional capital contributions that were made by the sole member. All revenues, costs and expenses of OpCo were allocated to the sole member in accordance with the initial limited liability company agreement of LandBridge, dated as of September 27, 2023 (the “Prior LLC Agreement”).

Share Repurchase Program

On February 24, 2026, our board of directors approved a share repurchase program. The program permits the repurchase of up to $50 million of the Company’s Class A shares through December 2027. The shares may be repurchased from time to time in open market transactions, block trades, accelerated share repurchases, or privately negotiated transactions or by any combination of such methods. The timing, as well as the number and value of shares repurchased under the program, will be determined by the Company at its discretion and will depend on a variety of factors, including management's assessment of the intrinsic value of the Company’s Class A shares, the market price of the Company’s Class A shares, general market and economic conditions, available liquidity, compliance with the Company’s debt and other agreements, applicable legal requirements, and other considerations. The Company is not obligated to purchase any shares under the share repurchase program, and the program may be suspended, modified or discontinued at any time without prior notice.

Issuances

On November 12, 2025, to fund a portion of the purchase consideration for the 1918 Ranch Acquisition, OpCo issued 657,411 OpCo Units and the Company issued an equal number of Class B shares valued at $53.6 million. The fair value of the OpCo Units was determined based on the closing price of the Company’s Class A shares on the date of acquisition. Refer to Note 4 - Asset Acquisitions for additional information regarding the transaction.

Redemptions

On November 18, 2025, LandBridge Holdings redeemed 2,500,000 OpCo Units (together with the cancellation of a corresponding number of Class B shares), for an equivalent amount of Class A shares and subsequently sold such Class A Shares in an underwritten public offering to Goldman Sachs & Co. LLC at a price of $70.00 per share. The Company did not receive any proceeds and incurred $0.8 million in expenses from the sale of Class A Shares by LandBridge Holdings.

On May 23, 2025, LandBridge Holdings redeemed 1,900,000 OpCo Units (together with the cancellation of a corresponding number of Class B shares), for an equivalent amount of Class A shares and subsequently sold such Class A shares in a private transaction pursuant to Rule 144 under the Securities Act through a broker-deal at a price of $75.25 per share. The Company did not receive any proceeds or incur any material expenses from the sale of the Class A shares by LandBridge Holdings.

During the year ended December 31, 2024, no Class B shares were redeemed for Class A shares.

Cancellations

In December 2024, as part of the December 2024 Private Placement we purchased 2,498,751 OpCo Units from LandBridge Holdings, which resulted in the cancellation of a corresponding number of Class B shares. Refer to Note 1 - Organization and Nature of Operations.

In lieu of the payment of tax distributions by OpCo to the Company in excess of the Company's then-current income tax obligation, OpCo and the Company cancelled OpCo Units held by LandBridge Holdings, along with a corresponding number of Class B shares. The number of cancelled OpCo Units was determined based on the Company’s volume weighted average Class A share price for the 10 consecutive trading days ending on and including the last full trading day immediately prior to the relevant tax distribution date.

|  |  |  |  |  | Year Ended December 31, |
Class B Share Cancellations Due to Tax Distributions |  |  |  |  |  | 2025 |  |  | 2024 |
First Quarter |  |  |  |  |  |  | 34,674 |  |  |  | - |
Second Quarter |  |  |  |  |  |  | 79,686 |  |  |  | - |
Third Quarter |  |  |  |  |  |  | 119,987 |  |  |  | - |
Total |  |  |  |  |  |  | 234,347 |  |  |  | - |

104

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

Dividends and Distributions

(in thousands, except for per share amounts) Cash Dividends |  | Date of Record |  | Dividends Paid to Class A Shareholders |  |  | Distributions Paid to OpCo Unitholders |  |  | Rate Per Share |
First Quarter |  | March 6, 2025 |  | $ | 2,326 |  |  | $ | 5,319 |  |  | $ | 0.10 |
Second Quarter |  | June 5, 2025 |  |  | 2,515 |  |  |  | 5,124 |  |  | $ | 0.10 |
Third Quarter |  | September 4, 2025 |  |  | 2,534 |  |  |  | 5,121 |  |  | $ | 0.10 |
Fourth Quarter |  | December 4, 2025 |  |  | 2,784 |  |  |  | 4,925 |  |  | $ | 0.10 |
Total |  |  |  | $ | 10,159 |  |  | $ | 20,489 |  |  |  |

Tax Distributions to LandBridge Holdings |  |  |  |  |  |  |  | Year Ended December 31, 2025 |
First Quarter |  |  |  |  |  |  |  | $ | 5,821 |
Second Quarter |  |  |  |  |  |  |  |  | 16,650 |
Third Quarter |  |  |  |  |  |  |  |  | 7,140 |
Fourth Quarter |  |  |  |  |  |  |  |  | 3,177 |
Total |  |  |  |  |  |  |  | $ | 32,788 |

On February 24, 2026, our board of directors declared a dividend on our Class A shares of $0.12 per share, payable on March 19, 2026 to shareholders of record as of March 5, 2026, and a corresponding required cash distribution to OpCo unitholders.

On February 24, 2026, our board of directors approved a payment for tax distributions from OpCo to LandBridge Holdings in the amount of $5.3 million. This amount is inclusive of LandBridge Holdings pro rata share of estimated federal income tax to be distributed from OpCo to the Company and an additional tax distribution in excess of the Company’s then-current income tax obligation as provided for under the OpCo LLC Agreement. This amount is expected to be paid during the first quarter of 2026.

10. Share-Based Compensation

## A summary of the Company’s aggregate share-based compensation expense (income) is shown below. Share-based compensation expense related to incentive units allocated to the Company is recognized as a deemed non-cash contribution to or distribution from shareholders’ equity on the consolidated balance sheets. Substantially all share-based compensation expense (income) is included in general and administrative expense (income) on the consolidated statements of operations.

|  | Year Ended December 31, |
|  | 2025 |  |  | 2024 |  |  | 2023 |
Incentive Units |  | $ | 36,508 |  |  | $ | 91,307 |  |  | $ | (17,230 | )
Restricted Share Units |  |  | 8,811 |  |  |  | 4,028 |  |  |  | - |
Total share-based compensation expense (income) (1) |  | $ | 45,319 |  |  | $ | 95,335 |  |  | $ | (17,230 | )

105

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

(1)
The tax benefit associated with share-based compensation expense was $1.1 million for the year ended December 31, 2025.

## Share-based compensation expense related to incentive units for the year ended December 31, 2025, consists only of the Incentive Units. Share-based compensation expense related to incentive units for the year ended December 31, 2024, consists of $18.7 million related to the Incentive Units, and consists of $72.6 million related to the NDB Incentive Units. Share-based compensation income related to incentive units for the year ended December 31, 2023 consists only of NDB Incentive Units. NDB Incentive Units were liability awards resulting in periodic fair value remeasurement prior to the Division. Following the Division, Incentive Units are equity awards and do not require periodic remeasurements. Any cash expense associated with Incentive Units will be borne solely by LandBridge Holdings and not the Company. Such incentive units are not dilutive of public ownership.

## Incentive Units

Prior to the Division, our management and employees participated in an equity-based incentive unit plan managed by NDB LLC, the direct parent of the Company. The NDB Incentive Units consisted of time-based awards of profits interest in NDB LLC.

On July 1, 2024, as a result of the Division, holders of NDB Incentive Units received an identical number of LBH Incentive Units consisting of time-based awards of profits interest in LandBridge Holdings. Pursuant to the Division, the LBH Incentive Units held at LandBridge Holdings are the only incentive units attributable and allocated to the Company.

The incentive units received by the NDB Incentive Unit holders in conjunction with the Division were considered a modification of the awards under ASC 718. As discussed above, the NDB Incentive Units that previously received liability award accounting are now accounted for as equity awards at LandBridge Holdings. In conjunction with the modification, there was no immediate incremental expense recognized as the fair value of the modified equity awards at the modification date was less than the fair value of the liability awards remeasured immediately prior to modification. As of the modification date, the LBH Incentive Units had $24.2 million of unrecognized share-based compensation expense that will be recognized over a weighted average remaining term of 2.0 y ears.

LBH Incentive Units granted during December 31, 2025 and 2024 were estimated using a Monte Carlo Simulation with the following inputs:

|  | 10/1/2025 |  |  | 12/9/2024 |  |  | 10/29/2024 |  |  | 7/18/2024 |  |  | 7/1/2024(1) |
Share price |  | $ | 55.56 |  |  | $ | 62.29 |  |  | $ | 53.84 |  |  | $ | 28.45 |  |  | $ | 22.96 |
Expected life (in years) |  |  | 2.0 |  |  |  | 2.1 |  |  |  | 2.2 |  |  |  | 2.0 |  |  |  | 1.5 |
Risk-free interest rate |  |  | 3.5 | % |  |  | 4.0 | % |  |  | 4.0 | % |  |  | 4.4 | % |  |  | 4.8 | %
Dividend yield |  |  | 0 | % |  |  | 0 | % |  |  | 0 | % |  |  | 0 | % |  |  | 0 | %
Volatility |  |  | 40.0 | % |  | 40% - 76% |  |  | 35% - 72% |  |  | 40% - 132% |  |  | 40% - 225% |
Marketability discount |  | 17% - 30% |  |  | 13% - 22% |  |  | 12% - 22% |  |  | 12% - 30% |  |  | 11% - 32% |

(1)
The LBH Incentive Units utilized the same inputs for the modification date fair value as it occurred on the same date as the 7/1/2024 grant date.

A summary of LBH Incentive Units activity during the year ended December 31, 2025 is shown in the following table:

|  | Incentive Units |  |  | Weighted Average Grant Date Fair Value |  |  | Weighted Average Remaining Contractual Term (years) |
Outstanding at December 31, 2024 (1) |  |  | 30,020 |  |  | $ | 5,130 |  |  |  |
Granted |  |  | 200 |  |  |  | 7,175 |  |  |  |
Forfeited |  |  | - |  |  |  | - |  |  |  |
Outstanding at December 31, 2025 |  |  | 30,220 |  |  | $ | 5,144 |  |  |  | 0.9 |

(1)
The units outstanding as of December 31, 2024 reflect the effects of the Division and only include the LBH Incentive Units. The grant date fair value per unit amount includes the modification date weighted average per unit fair value of $7,959 per unit.

As of December 31, 2025, remaining unrecognized compensation expense for the LBH Incentive Units was $45.3 million and the weighted average remaining vesting period was approximately 1.5 years.

Share-based compensation expense for the year ended December 31, 2024, includes $1.2 million of additional expense related to accelerated vesting due to an employee departure. There were no accelerations for the years ended December 31, 2025 and 2023.

106

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

## Restricted Share Units

Under the LTIP, participants were granted RSUs which are subject to graded vesting generally ranging from one to three years. The fair value of the awards is based on our share price on the date of grant with compensation expense recognized on a straight-line basis over the applicable vesting period.

A summary of RSU activity during the year ended December 31, 2025 is shown in the following table:

|  | RSUs |  |  | Weighted Average Grant Date Fair Value |
Nonvested at December 31, 2024 |  |  | 749,529 |  |  | $ | 31.37 |
Granted (1) |  |  | 57,393 |  |  |  | 56.17 |
Forfeited |  |  | - |  |  |  | - |
Vested (2) |  |  | (269,441 | ) |  |  | 31.48 |
Nonvested at December 31, 2025 |  |  | 537,481 |  |  | $ | 33.96 |

(1)
The weighted average grant date fair values of RSUs granted was $56.17 and $31.36 for the years ended December 31, 2025 and 2024, respectively.
(2)
Included within the 269,441 RSUs that vested during the period, 86,661 RSUs were surrendered by employees to the Company to settle tax withholding requirements. The total fair value of RSUs vested was $8.5 million for the year ended December 31, 2025

As of December 31, 2025, remaining unrecognized compensation expense for the RSUs was $13.9 million and the weighted average remaining vesting period was approximately 1.8 years.

## Defined Contribution Plan

WaterBridge Management Company LLC, an affiliate of the Company, sponsors a defined contribution plan available to all eligible employees. Qualifying participants receive a matching contribution based on the amount participants contribute to the plan up to 7% of their qualifying compensation. Contributions of an immaterial amount were made during the years ended December 31, 2025, 2024 and 2023.

11. Earnings Per Share

The Company’s unvested RSUs are deemed to be participating securities; therefore, the Company applies the two-class method for the calculation of basic EPS for the Class A shares. Diluted EPS attributable to Class A shares is calculated under both the two-class method and the treasury stock method, and the more dilutive of the two calculations is presented.

Class B Shares are considered potentially dilutive shares of Class A shares because they are convertible into Class A shares on a one-for-one basis; therefore, the Company applies the if-converted method for the calculation of diluted EPS for the Class A shares.

We determined that the presentation of EPS for the period prior to the IPO would not be meaningful due to the significant nature of the Corporate Reorganization on our capital structure. Therefore, EPS information has not been presented for periods prior to the IPO.

107

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

The following table sets forth the computation of basic and diluted EPS attributable to our Class A shares for the year ended December 31, 2025 and the period July 1, 2024 to December 31, 2024, which represents the period subsequent to the IPO.

(in thousands, except for share and per share amounts) |  | Year Ended December 31, 2025 |  |  | Period of July 1 - December 31, 2024 |
Numerator |  |  |  |  |  |
Net income |  | $ | 72,399 |  |  | $ | 5,398 |
Less: Net income attributable to noncontrolling interest |  |  | 42,271 |  |  |  | 288 |
Net income attributable to LandBridge Company LLC |  |  | 30,128 |  |  |  | 5,110 |
Less: Earnings allocated to participating securities |  |  | 753 |  |  |  | 198 |
Basic net income attributable to LandBridge Company LLC |  | $ | 29,375 |  |  | $ | 4,912 |
Plus: Net income attributable to noncontrolling interest |  |  | 42,271 |  |  |  | 288 |
Plus: Undistributed earnings reallocation adjustment to participating securities |  |  | (18 | ) |  |  | 90 |
Diluted net income attributable to shareholders |  | $ | 71,628 |  |  | $ | 5,290 |
Denominator |  |  |  |  |  |
Basic weighted average shares outstanding |  |  | 24,815,703 |  |  |  | 17,807,323 |
Dilutive Class B shares outstanding |  |  | 51,726,532 |  |  |  | 55,562,750 |
Diluted weighted average shares outstanding |  |  | 76,542,235 |  |  |  | 73,370,073 |
Basic net income per share of Class A shares |  | $ | 1.18 |  |  | $ | 0.28 |
Diluted net income per share of Class A shares |  | $ | 0.94 |  |  | $ | 0.07 |

Class B shares outstanding as of December 31, 2025 were determined to be dilutive and have been included in the computation of diluted net income per share. In addition, weighted-average RSUs of 636,229 were evaluated under the treasury stock method for potentially dilutive effects and were determined to be anti-dilutive for the year ended December 31, 2025 and have been excluded from the computation of diluted net income per share.

Class B shares outstanding as of December 31, 2024 were determined to be dilutive and have been included in the computation of diluted net income per share. In addition, weighted-average RSUs of 693,123 were evaluated under the treasury stock method for potentially dilutive effects and were determined to be anti-dilutive for the year ended December 31, 2024 and have been excluded from the computation of diluted net income per share.

12. Related Party Transactions

|  |  | Year Ended December 31, |
| Financial Statements Location |  | 2025 |  |  | 2024 |  |  | 2023 |
Revenues - Related Party |  |  |  |  |  |  |  |  |  |
Affiliate access agreements | Surface use royalties |  | $ | 36,168 |  |  | $ | 18,499 |  |  | $ | 5,436 |
Data center agreement | Easements and other surface-related revenues |  |  | - |  |  |  | 8,000 |  |  |  | - |
Affiliate access agreements | Easements and other surface-related revenues |  |  | 10,716 |  |  |  | 5,486 |  |  |  | 4,249 |
Affiliate access agreements | Resource royalties |  |  | 7,297 |  |  |  | 3,062 |  |  |  | - |
Affiliate access agreements | Resource sales |  |  | 1,718 |  |  |  | 387 |  |  |  | 1,785 |
|  |  | $ | 55,899 |  |  | $ | 35,434 |  |  | $ | 11,470 |

|  |  | December 31, |
| Financial Statements Location |  | 2025 |  |  | 2024 |
Accounts Receivable - Related Party |  |  |  |  |  |  |
Affiliate access agreements | Related party accounts receivable |  | $ | 4,945 |  |  | $ | 2,111 |
Accounts Payable - Related Party |  |  |  |  |  |  |
Shared services agreement | Related party accounts payable |  | $ | 781 |  |  | $ | 686 |

108

LandBridge Company LLC and Subsidiaries

Notes to the Consolidated Financial Statements (Continued)

Shared Services Agreement

The Company is party to a services agreement with WaterBridge Operating LLC (“WaterBridge Operating”), an affiliate of the Company, and other affiliates pursuant to which the Company receives common management and general, administrative, overhead and operating services in support of the Company’s operations and development activities. The Company reimburses all fees incurred by WaterBridge Operating or its affiliates for services provided to the Company under the agreement. For shared services, the basis of allocation is an approximation of time spent on activities supporting the Company. For shared expenses paid on behalf of the Company, the costs are directly allocated to the Company based on its pro rata share of the expenses. For the years ended December 31, 2025, 2024 and 2023, the Company paid approximately $17.2 million, $10.1 million and $5 million for the shared services and direct cost reimbursements, respectively.

Affiliate Facility Access Agreements

The Company is party to facility access and surface use agreements and easements and rights-of-way with WaterBridge Infrastructure LLC and its subsidiaries (“WaterBridge”). Under these agreements, the Company has granted WaterBridge certain rights to construct, operate and maintain produced water, brackish water and waste reclamation facilities on our land, as applicable, in the ordinary course of business. Each of these agreements includes a standard fee schedule and provision for specified surface use activities. Each of these agreements also includes a provision for royalties related to certain specified activities.

Equity Sponsor Services Agreement

Five Point Infrastructure LLC (“Five Point”), our financial sponsor, invoices the Company, and the Company reimburses Five Point in cash, for expenses associated with the Company’s use of Five Point’s geographic information system (“GIS”) and certain legal services provided by Five Point. The reimbursement includes allocated Five Point personnel costs and third-party software and hardware expenses and is determined based on the Company’s use of Five Point’s total services for such period. For the years ended December 31, 2025, 2024 and 2023, the GIS and legal services reimbursements paid were $0.5 million, $0.3 million and $0.2 million, respectively. As of December 31, 2025 and 2024, the Company had no amount and an immaterial amount due to Five Point, respectively.

Data Center Agreement

The Company is party to a lease development agreement for the development of a data center and related facilities on approximately 2,000 acres of our land in Reeves County, Texas with Powered Land Partners LLC, a joint venture between a third-party developer and funds affiliated with Five Point (“PowLan”). PowLan is obligated to meet certain timing milestones to maintain its lease, to include the commencement of site development within a two-year period and construction of the data center within a subsequent four-year period. To the extent PowLan does not commence site development within two years of entry into the lease development agreement or commence construction of the data center within a subsequent four-year period, the agreement will automatically terminate. The lease development agreement includes, among other things, a non-refundable deposit, for a two-year site selection and pre-development period. The deposit of $8.0 million was paid in December 2024 and is included within Easements and other surface-related revenues - Related Party on the consolidated statements of operations for the year ended December 31, 2024.

13. Commitments and Contingencies

For the years ended December 31, 2025 and 2024, the Company had no material commitments.

Litigation

The Company records liabilities related to litigation and other legal proceedings when they are either known or considered probable and can be reasonably estimated. Legal proceedings are inherently unpredictable and subject to significant uncertainties, and significant judgment is required to determine both probability and the estimated amount. As a result of these uncertainties, any liabilities recorded are based on the best information available at the time. As any new information becomes available, the Company reassesses the potential liability related to pending litigation. As of December 31, 2025 and 2024, the Company h ad no amounts recorded in liabilities related to any legal matters.

109

Item 9. Changes in and Disagreements With Accountants on Accounting and Financial Disclosure

None.

Item 9A. Controls and Procedures

Disclosure Controls and Procedures

Under the supervision and with the participation of our management, our principal executive officer and principal financial officer have evaluated the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act), as of the end of the period covered by this Annual Report. Our disclosure controls and procedures are designed to provide reasonable assurance that the information we are required to disclose in reports that we file or submit under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC, and to provide reasonable assurance that the information we are required to disclose in reports that we file or submit under the Exchange Act is accumulated and communicated to our management, including our principal executive officer and principal financial officer, as appropriate, to allow timely decisions regarding required disclosure. Based on such evaluation, our principal executive officer and principal financial officer have concluded that our disclosure controls and procedures were effective at a reasonable level of assurance as of December 31, 2025.

In designing and evaluating our disclosure controls and procedures, management recognizes that disclosure controls and procedures, no matter how well conceived and operated, can provide only reasonable, not absolute, assurance that the objectives of the disclosure controls and procedures are met. Additionally, in designing disclosure controls and procedures, our management necessarily was required to apply its judgment in evaluating the cost-benefit relationship of possible disclosure controls and procedures. The design of any system of controls also is based in part upon certain assumptions about the likelihood of future events, and there can be no assurance that any design will succeed in achieving its stated goals under all potential future conditions; over time, controls may become inadequate because of changes in conditions, or the degree of compliance with policies or procedures may deteriorate. Because of the inherent limitations in a control system, misstatements due to error or fraud may occur and not be detected.

Management’s Annual Report on Internal Control Over Financial Reporting

Our management, including our Chief Executive Officer and Chief Financial Officer, is responsible for establishing and maintaining adequate internal control over financial reporting. Our internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with GAAP. Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

Management assessed the effectiveness of the Company’s internal control over financial reporting as of December 31, 2025 using the criteria set forth in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”). Based on this assessment, management concluded that the Company maintained effective internal control over financial reporting as of December 31, 2025.

Our internal control over financial reporting as of December 31, 2025 has been audited by Deloitte & Touche LLP, an independent registered public accounting firm, as stated in their report below.

Changes in Internal Control over Financial Reporting

There were no changes in internal control over financial reporting that occurred during the year ended December 31, 2025 that have materially affected, or are reasonably likely to have a material effect on, the Company’s internal control over financial reporting.

110

REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM

To the shareholders and the Board of Directors of LandBridge Company LLC

Opinion on Internal Control over Financial Reporting

We have audited the internal control over financial reporting of LandBridge Company LLC and subsidiaries (the “Company”) as of December 31, 2025, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2025, based on criteria established in Internal Control — Integrated Framework (2013) issued by COSO.

We have also audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated financial statements as of and for the year ended December 31, 2025, of the Company and our report dated February 25, 2026, expressed an unqualified opinion on those financial statements.

Basis for Opinion

The Company’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the effectiveness of internal control over financial reporting, included in the accompanying Management’s Annual Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion on the Company’s internal control over financial reporting based on our audit. We are a public accounting firm registered with the PCAOB and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.

Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

/s/ Deloitte & Touche LLP

Houston, Texas
February 25, 2026

111

Item 9B. Other Information

Trading Arrangements

During the three months ended December 31, 2025, n on e of our directors or officers (as defined in Rule 16a-1(f) under the Exchange Act) adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408(c) of Regulation S-K.

Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections

Not applicable.

PART III

Item 10. Directors, Executive Officers and Corporate Governance

The information required by this item is incorporated herein by reference to the 2026 Proxy Statement, which will be filed with the SEC not later than 120 days subsequent to December 31, 2025.

We have adopted a Code of Business Conduct and Ethics and Whistleblower Policy (“Code of Ethics”) that applies to all of our directors, officers and employees, including our principal executive, principal financial and principal accounting officers, or persons performing similar functions, and other employees of the Company or its affiliates who provide services to the Company. Our Code of Ethics is posted on our website located at https://www.landbridgeco.com/investor-relations/governance/governance-documents/default.aspx. We intend to disclose future amendments to certain provisions of the Code of Ethics, and waivers of the Code of Ethics granted to executive officers and directors, on the website within four business days following the date of the amendment or waiver.

We have an insider trading policy governing the purchase, sale and other dispositions of our securities that applies to all of our personnel, including directors, officers, employees, and other covered persons. We believe that our insider trading policy and repurchase procedures are reasonably designed to promote compliance with insider trading laws, rules and regulations, and listing standards applicable to the Company. A copy of the Company’s insider trading policy is included as Exhibit 19.1 to this Annual Report.

Item 11. Executive Compensation

The information required by this item is incorporated herein by reference to the 2026 Proxy Statement, which will be filed with the SEC not later than 120 days subsequent to December 31, 2025.

Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

The information required by this item is incorporated herein by reference to the 2026 Proxy Statement, which will be filed with the SEC not later than 120 days subsequent to December 31, 2025.

Item 13. Certain Relationships and Related Transactions, and Director Independence

The information required by this item is incorporated herein by reference to the 2026 Proxy Statement, which will be filed with the SEC not later than 120 days subsequent to December 31, 2025.

Item 14. Principal Accountant Fees and Service s

The information required by this item is incorporated herein by reference to the 2026 Proxy Statement, which will be filed with the SEC not later than 120 days subsequent to December 31, 2025.

PART IV

Item 15. Exhibits and Financial Statement Schedules

(a) The following documents are filed as a part of this report:

112

(1) Financial Statements: The consolidated financial statements and related notes, together with the report of Deloitte & Touche LLP, Independent Registered Public Accounting Firm, appear in Part II, Item 8. Financial Statements and Supplementary Data, of this Annual Report.

(2) Financial Statement Schedules: All schedules for which provision is made in the applicable accounting regulations of the SEC are not required under the related instruction or are inapplicable and, therefore, have been omitted.

(3) Exhibits: The exhibits listed below on the Index to Exhibits are filed or incorporated by reference as part of this Form 10-K.

Item 16. Form 10–K Summary

None.

113

Exhibits

Exhibit Number | Description
2.1# | Purchase and Sale Agreement, dated as of November 19, 2024, by and between Wolf Bone Ranch Partners LLC, as seller, and DBR Land LLC, as purchaser (incorporated by reference to Exhibit 2.1 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on November 22, 2024).
2.2#+ | Purchase, Sale and Contribution Agreement, dated October 3, 2025, by and among LandBridge Company LLC, DBR Land Holdings LLC, 1918 Ranch & Royalty LLC and the other parties thereto (incorporated by reference to Exhibit 2.1 to the Company’s Quarterly Report on Form 10-Q (File No. 001-42150) filed with the SEC on November 12, 2025).
3.1 | Certificate of Formation of LandBridge Company LLC (incorporated by reference to Exhibit 3.1 to the Company’s Registration Statement on Form S-1 (File No. 333-279893) filed with the SEC on May 31, 2024).
3.2 | Amended and Restated Limited Liability Company Agreement of LandBridge Company LLC, dated as of July 1, 2024 (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on July 3, 2024).
4.1 | Description of Securities of the Registrant (incorporated by reference to Exhibit 4.1 to the Company’s Annual Report on Form 10-K (File No. 001-42150) filed with the SEC on March 6, 2025).
4.2 | Registration Rights Agreement, dated as of July 1, 2024, by and among LandBridge Company LLC and LandBridge Holdings LLC (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on July 3, 2024).
4.3 | Registration Rights Agreement, dated as of December 19, 2024, by and among LandBridge Company LLC and each of the other signatories thereto (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on December 23, 2024).
4.4 | Indenture, dated as of November 25, 2025, by and among DBR Land Holdings LLC, the guarantors party thereto and UMB Bank, N.A., as trustee (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on November 25, 2025).
10.1† | LandBridge Company LLC Long Term Incentive Plan (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on July 3, 2024).
10.2† | Form of Restricted Share Unit Award Agreement (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on July 16, 2024).
10.3 | DBR Land Holdings LLC Amended and Restated Limited Liability Company Agreement, dated as of July 1, 2024 (incorporated by reference to Exhibit 4.2 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on July 3, 2024).
10.4 | Amendment No. 1 to Amended and Restated Limited Liability Company Agreement of DBR Land Holdings LLC, dated as of July 1, 2024 (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on October 4, 2024).
10.5† | Form of Indemnification Agreement (incorporated by reference to Exhibit 10.3 to the Company’s Registration Statement on Form S-1 (File No. 333-279893) filed with the SEC on June 7, 2024).
10.6 | Shareholder’s Agreement, dated as of July 1, 2024, by and among LandBridge Company LLC and LandBridge Holdings LLC (incorporated by reference to Exhibit 4.3 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on July 3, 2024).
10.7 | Master Reorganization Agreement, dated as of July 1, 2024, by and among LandBridge Company LLC, LandBridge Holdings LLC, DBR Land LLC and DBR Land Holdings LLC (incorporated by reference to Exhibit 2.1 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on July 3, 2024).

114

Exhibit Number | Description
10.8 | Revolving Credit Agreement, dated as of November 18, 2025, among DBR Land Holdings LLC, Texas Capital Bank, as administrative and collateral agent, and the lenders party thereto (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-Q (File No. 001-42150) filed with the SEC on November 19, 2025).
10.9 | Amended and Restated Services Agreement, dated effective February 27, 2019, by and among WaterBridge Resources LLC, WaterBridge Management Company LLC, WaterBridge Co-invest LLC, WaterBridge Holdings LLC, each of the entities listed on Schedule I thereto, each of the entities listed on Schedule II thereto and each of the entities listed on Schedule III thereto (incorporated by reference to Exhibit 10.6 to the Company’s Registration Statement on Form S-1 (File No. 333-279893) filed with the SEC on May 31, 2024).
10.10# | Form of Common Shares Purchase Agreement (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K (File No. 001-42150) filed with the SEC on November 22, 2024).
19.1 | LandBridge Company LLC Insider Trading Policy, adopted as of August 6, 2024 (incorporated by reference to Exhibit 19.1 to the Company’s Annual Report on Form 10-K (File No. 001-42150) filed with the SEC on March 6, 2025).
21.1* | List of Subsidiaries of LandBridge Company LLC.
23.1* | Consent of Deloitte & Touche LLP, independent registered public accounting firm.
31.1* | Certification of Chief Executive Officer of LandBridge Company LLC pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2* | Certification of Chief Financial Officer of LandBridge Company LLC pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as adopted pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1** | Certification of Chief Executive Officer of LandBridge Company LLC pursuant to 18 U.S.C. § 1350, as adopted pursuant to the Sarbanes-Oxley Act of 2002.
32.2** | Certification of Chief Financial Officer of LandBridge Company LLC pursuant to 18 U.S.C. § 1350, as adopted pursuant to the Sarbanes-Oxley Act of 2002.
97.1 | LandBridge Company LLC Clawback Policy, adopted as of June 27, 2024 (incorporated by reference to Exhibit 19.1 to the Company’s Annual Report on Form 10-K (File No. 001-42150) filed with the SEC on March 6, 2025).
101* | Inline XBRL Document Set for the consolidated financial statements and accompanying notes in Part II, Item 8, “Financial Statements and Supplementary Data” of this Annual Report.
104* | Cover Page Interactive Data File (embedded within the Inline XBRL document and included in Exhibit 101).

* Filed herewith.

** Furnished herewith and not deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, as amended, and shall not be deemed to be incorporated by reference into any filing under the Securities Act of 1933, as amended, or the Securities Exchange Act of 1934, as amended.

† Identifies management contracts and compensatory plans or arrangements.

# Certain confidential information contained in this agreement has been omitted because it is both (i) not material and (ii) the type of information that the Company treats as private or confidential.

+ Certain portions of this exhibit (indicated by “[***]”) have been omitted pursuant to Item 601(b)(2) of Regulation S-K. The Company agrees to furnish supplementally a copy of any omitted information to the U.S. Securities and Exchange Commission or its staff upon request.

115

SIGNA TURES

Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.

| LandBridge Company LLC
Date: February 25, 2026 | (Registrant)
| By: | /s/ Jason Long
|  | Jason Long
|  | Chief Executive Officer
|  | (Principal Executive Officer)

116

Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated.

Name | Title | Date
/s/ Jason Long | Chief Executive Officer and Director | February 25, 2026
Jason Long | (Principal Executive Officer) |
/s/ Scott L. McNeely | Chief Financial Officer | February 25, 2026
Scott L. McNeely | (Principal Financial Officer) |
/s/ Jason Williams | Chief Administrative Officer | February 25, 2026
Jason Williams | (Principal Accounting Officer) |
/s/ David N. Capobianco | Director | February 25, 2026
David N. Capobianco |  |
/s/ Matthew K. Morrow | Director | February 25, 2026
Matthew K. Morrow |  |
/s/ Michael Sulton | Director | February 25, 2026
Michael Sulton |  |
/s/ Frank Bayouth | Director | February 25, 2026
Frank Bayouth |  |
/s/ Ben Moore | Director | February 25, 2026
Ben Moore |  |
/s/ Kara Goodloe Harling | Director | February 25, 2026
Kara Goodloe Harling |  |
/s/ Charles Watson | Director | February 25, 2026
Charles Watson |  |
/s/ Ty Daul | Director | February 25, 2026
Ty Daul |  |
/s/ Valerie P. Chase | Director | February 25, 2026
Valerie P. Chase |  |
/s/ Andrea Nicolás | Director | February 25, 2026
Andrea Nicolás |  |

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