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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-K

For the fiscal year ended December 31, 2024

or

For the transition period from ______ to ______

Commission File Number: 001-40955

Aris Water Solutions, Inc.

(Exact name of registrant as specified in its charter)

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(832) 304-7003

(Registrant’s telephone number, including area code)

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

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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.

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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 its 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 ☒

Aggregate market value of Common Stock held by nonaffiliates as of June 30, 2024: $507.4 million

As of February 24, 2025, the registrant had 30,971,735 shares of Class A common stock, $0.01 par value per share, and 27,493,565 shares of Class B common stock, $0.01 par value per share, outstanding.

DOCUMENTS INCORPORATED BY REFERENCE

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Portions of the Registrant’s definitive proxy statement for the 2025 Annual Meeting of Shareholders (the “2025 Proxy Statement”), which will be filed with the Securities and Exchange Commission within 120 days after December 31, 2024, are incorporated by reference into Part III of this Annual Report on Form 10-K where indicated.

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TABLE OF CONTENTS

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Introductory Note Regarding Definitions

The registrant, Aris Water Solutions, Inc. (“Aris Inc.”), was incorporated on May 26, 2021 as a Delaware corporation. Aris Inc. was formed to serve as the issuer of equity in an IPO, which was completed on October 26, 2021. Concurrent with the completion of the IPO, Aris Inc. became the new parent holding company of Solaris Midstream Holdings, LLC (“Solaris LLC”), a Delaware limited liability company. Except as otherwise indicated or required by the context, all references to “Aris Inc.,” “Solaris LLC,” the “Company,” “we,” “our,” and “us” or similar terms refer to (i) Solaris LLC and its consolidated subsidiaries before the completion of the Corporate Reorganization in connection with the IPO (discussed in the notes to our consolidated financial statements included in Item 8. Financial Statements and Supplementary Data) and (ii) Aris Inc. and its consolidated subsidiaries as of the completion of the Corporate Reorganization and thereafter.

Cautionary Note Regarding Forward-Looking Statements

This Annual Report on Form 10‑K (the “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 contained in this Annual Report, including, without limitation, statements regarding our future results of operations or financial condition, business strategy and plans and objectives of management for future operations, are forward-looking statements. In some cases, you can identify forward-looking statements by terminology such as “anticipate,” “guidance,” “preliminary,” “project,” “estimate,” “outlook,” “expect,” “continue,” “will,” “intend,” “plan,” “targets,” “believe,” “forecast,” “future,” “potential,” “should,” “may,” “possible,” “could” and variations of such words or similar expressions.

You should not rely on forward-looking statements as predictions of future events. We have based the forward-looking statements contained in this Annual Report primarily on our current expectations and projections about future events and trends that we believe may affect our business, financial condition and operating results. The outcome of the events described in these forward-looking statements is subject to risks, uncertainties and other factors described in the section titled “Risk Factors” and elsewhere in this Annual Report, including, but not limited to, the following:

Many of the factors that will determine our future results are beyond the ability of management to control or predict. 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. All forward-looking statements, expressed or implied, included in this Annual Report are expressly qualified in their entirety by this cautionary statement.

The forward-looking statements in this Annual Report relate only to events as of the date on which the statements are made. We undertake no obligation to update any forward-looking statements made in this Annual Report to reflect events or circumstances after the date of this Annual Report or to reflect new information or the occurrence of unanticipated events, except as required by law. We may not actually achieve the plans, intentions or expectations disclosed in our forward-looking statements, and you should not place undue reliance on our forward-looking statements. Our forward-looking statements do not reflect the potential impact of any future acquisitions, mergers, dispositions, joint ventures or investments.

For the definitions of certain terms and abbreviations used in this Annual Report, see Glossary of Terms.

Summary of Our Risk Factors

An investment in our Class A common stock involves substantial 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 our 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

Legal and Regulatory Risks

Risks Related to Our Class A Common Stock

You should carefully read and consider the information set forth under Part I, Item 1A - Risk Factors.

Part I

Items 1. and 2. Business and Properties

Our Company

We are a leading, growth-oriented environmental infrastructure and solutions company that directly helps our customers reduce their water and carbon footprints. We deliver full-cycle water handling and recycling solutions that increase the sustainability of energy company operations. Our integrated pipelines and related infrastructure create long-term value by delivering high-capacity, comprehensive produced water management, recycling and supply solutions to operators in the core areas of the Permian Basin.

We provide critical environmental solutions to many of the most active and well-capitalized companies operating in the Permian Basin, including the following companies and/or their affiliates: ConocoPhillips and Chevron U.S.A. Inc. Operators are increasingly focused on minimizing their environmental impact as a measure of success with an emphasis on rapidly increasing the use of recycled produced water in their operations. Our expansive infrastructure, advanced logistics and water treatment methods allow us to reliably gather our customers’ produced water and recycle it for use in their operations. We believe our solutions make a significant contribution to the ability of our customers to achieve their sustainability-related objectives. Since inception, we have been committed to responsibly developing, operating and deploying technology to safely reduce our customers’ environmental footprint.

Our Commitment to Sustainability and Governance Leadership

Our business strategy and operations align with the increasing focus of local communities, regulators and stakeholders on ensuring the safety of oil and gas operations and minimizing environmental and local community impacts. We have a leading track record in environmental stewardship in the areas in which we operate by setting and meeting ambitious sustainability targets. This leadership highlights the strong technical, operational and financial capabilities of our management team that has decades of experience operating and leading companies in the environmental, infrastructure, water treatment and energy industries.

Our business provides reliable and sustainable water solutions which address the operational and environmental demands of the energy industry and actively reduce emissions. Through our significant investment in permanent pipeline infrastructure to safely gather and transport produced water, we minimize the need for produced water trucking, a major contributor of GHG emission, traffic congestion and road safety concerns in the communities in which we operate. Additionally, we are leaders in the evaluation, piloting and advancement of water treatment technologies, including the development of solutions for the use of treated produced water outside of the oil and gas industry. For example, we are piloting and developing proprietary processes for treating produced water for environmental, agricultural and industrial water demand, including evaluating the use of treated produced water as process water for recharging aquifer systems and other industrial uses.

Our strong company culture includes commitments to our employees and our shareholders, which we believe will benefit all of our constituents. We have created a work environment that seeks to provide equal employment opportunities and foster an inclusive company culture. Additionally, we prioritize safety in our operations through rigorous training, structured protocols and ongoing automation of our operations.

We believe alignment of our management and our Board with our shareholders, including the establishment of a well-rounded and independent Board, is conducive to creating long-term value. Additionally, through our management’s substantial equity ownership in us and our incentive compensation programs, our management team remains highly motivated to continue creating shareholder value.

Our Full-Cycle Water Handling and Recycling Solutions

Produced Water

Produced water naturally exists in underground formations and is brought to the surface during crude oil and natural gas production. Produced water is produced throughout the entire life of the well and is of particular importance to operators in the Permian Basin given the high produced water-to-oil ratio prevalent across the basin. Many of our customers have stated goals of managing produced water volumes in an environmentally-responsible and cost-effective manner, highlighting the importance of our water management expertise and integrated and extensive asset base. We believe they will increasingly outsource water management to integrated produced water infrastructure and recycling companies like us to manage their water-related needs in a cost and capital effective manner, creating new business development and acquisition opportunities for us.

Water Recycling

Recycling produced water displaces the use of scarce groundwater which would otherwise be used for oil and gas operations. Treatment of produced water is required prior to reuse, which involves the removal of residual hydrocarbons, reduction of free iron and other solids along with the removal of bacteria to customer specifications. We have made a significant investment in our vast network of produced water gathering pipelines and recycling facilities, which has positioned us as a leading independent third-party provider of recycled produced water gathered on a proprietary network in the Permian Basin. The scale of our system allows us to gather significant produced water volumes across a wide geographic area from multiple customers. The increasing volumes of produced water aggregated on our systems provide differentiated support for our recycling operations and ensures that sufficient volumes of recycled water are available to our customers when and where needed. Our expansive asset base allows us to deliver cost-effective, high-capacity and reliable produced water recycling solutions to operators, encouraging and enabling their rapid adoption of the use of recycled produced water while minimizing the use of groundwater in energy production.

Between July 2019 (the month when we began recycling at scale) and December 31, 2024, we recycled approximately 433 million barrels, or approximately 18.2 billion gallons, of produced water. We are committed to providing our customers with a more secure and sustainable alternative to fresh and other sources of groundwater through our innovative technologies and recycling capabilities. By reducing our customers’ dependence on groundwater, we can contribute to their sustainability efforts and the sustainability of the broader energy industry while also providing benefits to our stakeholders and the communities in which we operate.

Full-Cycle Water Management

The volume of water required for hydraulic fracturing and the volume of produced water generated from oil and gas production have significantly increased in the Permian Basin. Additionally, energy producers are increasingly focused on maximizing sustainability and minimizing the environmental impact in the areas in which they operate. These trends represent significant challenges for energy producers. We provide access to a substantial and growing source of produced water that can be recycled to support energy production. We believe energy producers will increasingly depend on our expansive integrated produced water gathering and recycling assets that are designed specifically to meet these challenges. By developing these partnerships and outsourcing full-cycle produced water management, energy producers can preserve capital for their core operations and ultimately lower water management costs and do so in an environmentally-responsible way.

The figure below demonstrates the movement of produced water through our pipelines for handling or recycling and the multiple points at which we can collect fees on the same barrel of water:

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Our Operations and Assets

Our Operations

We manage our business through a single operating segment comprising two primary revenue streams, Produced Water Handling and Water Solutions.

Our Produced Water Handling business gathers, transports and, unless recycled, handles produced water generated from oil and natural gas production. Our Produced Water Handling business is supported by long-term contracts with acreage dedications or MVCs, primarily with large, well-capitalized operators.

Our Water Solutions business develops and operates recycling facilities to treat, store and recycle produced water. By aggregating significant volumes of produced water from multiple customers on our connected pipeline networks, we can efficiently recycle large volumes of produced water and deliver this recycled water back to our customers in the time frames, volumes and specifications required by their operations. As

needed, we also supplement our recycled produced water with non-potable groundwater to meet the demands of our customers’ operations.

Our business is driven by gathering produced water volumes for our Produced Water Handling business and delivering recycled water volumes to customers for our Water Solutions business. In our Produced Water Handling business, we grew our handling volumes from approximately 1,042,000 barrels per day for the year ended December 31, 2023 to approximately 1,120,000 barrels per day for the year ended December 31, 2024, an increase of 7%. Within our Water Solutions business, we grew our recycled volumes sold from approximately 324,000 barrels per day on average for the year ended December 31, 2023 to approximately 377,000 barrels per day on average for the year ended December 31, 2024, an increase of 16%, and we decreased our groundwater volumes sold from approximately 126,000 barrels per day on average for the year ended December 31, 2023 to approximately 51,000 barrels per day on average for the year ended December 31, 2024, a decrease of 60% as a result of a shift towards providing more recycled produced water as a proportion of total Water Solutions volumes.

Recent Operating Developments

Surface Acreage Acquisition

In November 2024, we purchased approximately 45,000 surface acres and site improvements (referred to as the “McNeill Ranch Acquisition”) in New Mexico and Texas for total cash consideration of $46.1 million, inclusive of transaction costs, to secure potential disposal capacity for long-term growth. This purchase was considered an asset acquisition, and the allocation of assets consisted of $43.2 million to land and $2.9 million to site improvements and other.

Operating Metrics

Total volumes and per barrel operating metrics were as follows for the periods indicated:

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Asset Overview

Our recognized operational capability is supported by our automated and high-capacity integrated pipeline network. Our pipeline and water handling assets are comprised primarily of pipelines, pumps and handling and recycling facilities located entirely in the Delaware and Midland sub-basins of the broader Permian Basin. These interconnected assets support both our Produced Water Handling and Water Solutions businesses. We currently have approximately 790 miles of produced water pipeline, which includes approximately 600 miles of larger diameter (12- to 24-inch) pipelines. We have 68 produced water handling facilities and operate 20 high-capacity produced water recycling facilities. Our systems provide an alternative to operators managing their own produced water infrastructure.

The following map describes our active assets as of December 31, 2024:

Our Assets

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Produced Water Handling Facilities

Our handling facilities, which are designed to process, store and/or dispose of produced water that is not recycled, are essential to our ability to deliver reliable and cost-effective water gathering services to existing and prospective customers across a large geographic footprint. As of December 31, 2024, we have 68 produced water handling facilities which had approximately 1.9 million barrels per day of capacity.

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We have secured significant permits and rights-of-way for additional pipelines and water handling facilities. As of December 31, 2024, we had approximately 195 miles of additional permitted pipeline rights-of-way and approved permits for an additional 23 produced water handling facilities with approximately 0.7 million barrels per day of permitted handling capacity. This backlog of permitted handling capacity provides us with valuable optionality and a competitive advantage as it helps us to react quickly to meet existing and new customer demand without potential permitting delays.

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Recycling Facilities

Our recycling facilities include water filtration, treatment, storage and redelivery assets. Our recycling facilities are at strategic locations on our pipeline network where there is both significant customer demand for recycled produced water and high volumes of produced water available. As of December 31, 2024, we had 20 facilities operational in the Delaware Basin with approximately 1.5 million barrels per day of treatment capacity and access to approximately 16.4 million barrels of owned or leased storage capacity.

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We also have the option to rapidly expand our recycling footprint as needed by developing an additional 10 locations that are either permitted or in the process of being permitted. We operate and construct both fixed treatment facilities and modular treatment systems that we can quickly assemble to capitalize on market opportunities.

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Our Customers and Contracts

Customers

We have long-term contracts with some of the most active and well-capitalized oil and gas operators in the Permian Basin which are increasingly focused on sustainability and minimizing the environmental impact of their operations. Since inception, we have consistently won new contracts and deepened relationships with existing customers, many of which have executed multiple contracts with us. As of December 31, 2024, we have approximately 100 contracts for our Produced Water Handling and Water Solutions businesses with approximately 37 different customers across approximately 625,000 dedicated acres.

As of December 31, 2024, the weighted average remaining life of our produced water handling acreage dedication contracts was approximately 6.8 years. Our largest customers for the year ended December 31, 2024 were affiliates of ConocoPhillips and Chevron U.S.A. Inc. These customers represented approximately 53% of our revenue for the year ended December 31, 2024. See Part II, Item 8. Financial Statements and Supplementary Data – Note 3. Additional Financial Statement Information.

Contracts — Produced Water Handling

As produced water volumes from oil and natural gas production in the Permian Basin have significantly grown in recent years, long-term contract structures like those used in the hydrocarbon midstream sector have been adopted for water services. In our Produced Water Handling business, we primarily enter into two types of contracts with our customers: acreage dedications and MVCs. These contractual arrangements are generally long-term. All produced water transported on our gathering pipeline infrastructure for handling or recycling is subject to fee-based contracts, which are generally subject to limited annual CPI-based adjustments.

Acreage Dedications. Acreage dedications are term contracts pursuant to which a customer dedicates all water produced from current and future wells that they own or operate in a dedicated area to our system. In turn, we commit to gather and handle such produced water. During 2024, we added approximately 10,000 net dedicated acres, while divesting approximately 10,000 acres. As of December 31, 2024, our acreage dedications covered a total of approximately 625,000 acres and had a weighted average remaining life of approximately 6.8 years.

MVCs. Under our MVC contracts, our customers guarantee to (i) deliver a certain minimum daily volume of produced water to our pipeline network at an agreed upon fee, or (ii) pay a deficiency fee if the minimum daily volume is not met for a specified period. As of December 31, 2024, our contracted aggregate MVCs totaled approximately 100,000 bwpd of produced water, and the weighted average remaining life of our MVCs was 2.1 years.

Spot Arrangements. We also enter into spot arrangements whereby we can elect to gather and handle our customers’ produced water to the extent we have capacity on our systems when they request offtake capacity. We refer to these volumes as spot volumes. When producers have a need for produced water handling services at locations which are not otherwise contracted to us, we will enter into spot arrangements in order to utilize available capacity and increase volume throughput on our systems.

Skim Oil Sales. As part of our water processing activities, we aggregate and sell recovered crude oil, also known as skim oil.

The following table provides an overview of our active contracts:

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Acreage dedications and minimum volume commitments were as follows:

Certain contracts included in the table above include both an acreage dedication and a minimum volume commitment. These contracts represent approximately 56,000 acres of the total acreage under contract and 85 kbwpd of the total volumetric commitment.

Delivery Commitment

In 2023, we entered into an agreement with an unaffiliated water disposal company to dispose a minimum volume of produced water over a term of seven years, for a total financial commitment of approximately $28.0 million, undiscounted, and not including annual CPI adjustments. As of December 31, 2024, the remaining minimum commitment was $22.4 million, undiscounted. See Part II, Item 1. Financial Statements – Note 13. Commitments and Contingencies for more information.

Contracts ─ Water Solutions

Our Water Solutions contracts are primarily structured as spot contracts or acreage dedications where we agree to supply water, including recycled water, to our customers for their operations.

We believe our integrated business model, history of operational execution, asset footprint and commitment to produced water recycling are important to current and prospective customers and support our leading position in water recycling in the Permian Basin.

Innovation in Recycling and Sustainable Water Management

Our goal is to maximize the amount of produced water we recycle as a percentage of the produced water we gather. We are partnered with leading oil and gas operators, technology providers, scientists and universities in the field of water treatment to identify, adapt and demonstrate innovative technologies for beneficial reuse of produced water. With a focus on commercialization, we are evaluating both technical and economic aspects of best available technologies to safely and effectively generate clean water from produced water. We have identified potential opportunities for clean water generated from produced water including replenishing surface water, supplementing irrigation water demand, industrial cooling and other industrial uses, and future recharging of aquifer systems.

Mineral Extraction Agreement

In the second quarter of 2024, we signed a letter of intent for a development partner to construct an iodine extraction facility, as we continue to evaluate commercial opportunities for mineral extraction. We are in the process of site selection at one of our Permian Basin produced water management facilities, and our goal is for this facility to be operational by the end of 2025.

NAWI

In April 2024, we signed an agreement with the National Alliance for Water Innovation (“NAWI”) to further investigate treatment of produced water using one of the pilot technologies, working with alliance members and Texas A&M University, New Mexico State University, SLAC National Accelerator Laboratory and other parties. Operational data was collected in November 2024 for this study, and the team is in the process of evaluating this data to further our understanding of produced water treatment.

Beneficial Reuse Joint Industry Project

In November 2022, we announced that we had entered into a beneficial reuse strategic agreement (the “Joint Industry Project” or “JIP”) with Chevron U.S.A. Inc. (“Chevron U.S.A.”) and ConocoPhillips to develop and pilot technologies and processes to treat produced water for potential beneficial reuse opportunities. In January 2023, ExxonMobil Corporation joined the JIP, and in July 2024, Coterra Energy Inc. (“Coterra”) joined the JIP. We previously referred to this agreement as the Beneficial Reuse Strategic Agreement.

Our goal under the JIP is to develop cost effective and scalable methods of treating produced water to create a potential water source for industrial, commercial and non-consumptive agricultural purposes. We are leading the engineering, construction and execution of the testing protocols and pilot projects, while leveraging the combined technical expertise of Chevron U.S.A., ConocoPhillips, ExxonMobil and Coterra (collectively with us, the “alliance members”). The treated water has the potential for use in a variety of applications, including non-consumptive agriculture, surface water replenishment and industrial uses. The alliance members are working with appropriate regulators to ensure that end-use applications are properly permitted, including surface discharge. Specifically, we have submitted two permit applications to the Texas Commission on Environmental Quality to permit discharge of clean water to a local reservoir. Our pilot-to-commercialization work with treatment technologies includes several phases, with a goal to complete Phase 1 testing and performance evaluation of pilot technologies by the end of the second quarter of 2025. We are in

the planning process for Phase 2 testing which will build upon and scale Phase 1 and is expected to launch in the second half of 2025.

Water Standard Asset Acquisition

In October 2022, we acquired certain intellectual property rights and related proprietary treatment technologies and assets from Water Standard Management (US), Inc. (“Water Standard”) that are currently being applied onsite in pilot operations to accelerate the advanced treatment and beneficial reuse of produced water in the Permian Basin. See Part II, Item 8. Financial Statements and Supplementary Data – Note 4. Acquisitions.

Our People

As of December 31, 2024, we had a total of 276 employees, 126 of which service our corporate function, and 150 that work in field locations. We hire independent contractors on an as needed basis. We and our employees are not subject to any collective bargaining agreements.

Safety is one of our greatest priorities, and we have implemented safety management systems, procedures, trainings and other tools to help protect our employees and contractors. We strive to hire local employees and have provided mentoring programs for employees to develop specialized skills necessary for our industry. We also provide career development programs to create opportunities for advancement. We encourage development of local leadership and team-based collaboration at our worksites. Our benefits include (i) health care for full-time employees and their eligible dependents, (ii) access to a Safe Harbor 401(k) Plan with a portion eligible for fully-vested employer matched contributions, (iii) basic life, accidental death and dismemberment, and short and long-term disability insurance, (iv) a family and medical leave policy which affords eligible (hourly and salaried) employees with temporary leave for a serious health condition, the care of a family member, or the birth or adoption of a child, (v) paid parental leave following the birth, adoption or placement of a child, (vi) wages that exceed state and federal standards and minimums, and (vii) our 2021 Equity Incentive Plan, which gives most employees an opportunity to share in our success.

We aim to attract and retain talented individuals. Our employee demographic profile aids us in promoting inclusion of thought, skill, knowledge and culture across our organization. As of December 31, 2024, greater than 50% of our workforce is minority and/or female. We also support local communities where we operate by giving to and volunteering with first responders and local charities.

Organizational Structure and Corporate Information

Consolidation

We are a holding company, and our principal asset is a membership interest in Solaris LLC. As the sole managing member of Solaris LLC, we operate and control all of the business and affairs of Solaris LLC, and through Solaris LLC and its subsidiaries, conduct its business. We are responsible for all operational, management and administrative decisions relating to Solaris LLC’s business. As a result, we consolidate the financial results of Solaris LLC and its subsidiaries and report a noncontrolling interest related to the portion of

Solaris LLC units not owned by us, which reduces net income attributable to our Class A common stockholders. As of December 31, 2024, we owned an approximate 53% interest in Solaris LLC.

Ownership Structure

The following diagram reflects our ownership structure as of December 31, 2024:

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Redemption Rights

Under the Solaris LLC Agreement, Legacy Owners of Solaris LLC units, subject to certain limitations, have the right, pursuant to a redemption right, to cause Solaris LLC to acquire all or a portion of their Solaris LLC units for, at Solaris LLC’s election, (x) shares of our Class A common stock at a redemption ratio of one share of Class A common stock for each Solaris LLC unit redeemed, subject to conversion rate adjustments for stock splits, stock dividends and reclassifications or (y) an equivalent amount of cash. Alternatively, upon the exercise of the redemption right, we have the right, pursuant to a call right, to acquire each tendered Solaris LLC unit directly from the Legacy Owner for, at our election, (x) one share of Class A common stock or (y) an equivalent amount of cash.

During the years ended December 31, 2024, 2023 and 2022, 50,000, 31,954 and 4,140,585 Solaris LLC units, respectively, were converted (together with an equal number of shares of Class B common stock) into shares of our Class A common stock. As of December 31, 2024, we owned an approximate 53% interest in Solaris LLC, and the Legacy Owners owned an approximate 47% interest in Solaris LLC.

General

Aris Inc. was incorporated as a Delaware corporation on May 26, 2021. Our principal executive office is located at 9651 Katy Freeway, Suite 400, Houston, Texas 77024, and we have additional offices in Midland, Texas and Carlsbad, New Mexico.

Our website address is www.ariswater.com. Our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and amendments to reports filed or furnished pursuant to Sections 13(a) and 15(d) of the Exchange Act are available, free of charge, through our website, as soon as reasonably practicable after those reports and other information are electronically filed with or furnished to the SEC.

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 serve as distribution channels of material company information for purposes of Regulation FD.

Information contained on our website or linked therein or otherwise connected thereto does not constitute part of and is not incorporated by reference into this Annual Report.

Competition

We compete with public and private water infrastructure companies as well as operators developing systems in-house for produced water handling and recycling in the areas in which we operate. Competition in the water infrastructure industry is based on the geographic location of facilities, business reputation, operating reliability and flexibility, business service offerings, available capacity and pricing arrangements for the services offered. We compete with other companies that provide similar services in our areas of operations, but we benefit from our relationships with large operators in the Permian Basin, including ConocoPhillips, and our reputation as a proven, reliable service provider and our deep commitment to recycling and sustainability. As we seek to expand our water gathering, recycling and handling services to new customers, we will continue to face a high level of competition.

Seasonality

In general, seasonal factors have not had a significant direct effect on our business other than timing impacts of oil and gas completion activity that have historically been weighted to the back half of the year. However, extreme weather conditions during parts of the year could adversely impact the well-completion activities of our customers, who are oil and natural gas operators, and/or affect their ability to flow gas, which may result in temporary curtailments and shut-in wells, thereby reducing the amount of produced water to be gathered and either recycled or handled, as well as the volume of Water Solutions barrels sold to our customers.

Insurance

Our assets may experience physical damage as a result of an accident or natural disaster. These hazards can also cause personal injury and loss of life, severe damage to and destruction of property and equipment, pollution or environmental damage and suspension of operations. Litigation arising from such an event may result in us being named a defendant in lawsuits asserting large claims. We maintain our own general liability, product liability, property, business interruption, directors’ and officers’ liability, workers compensation, cybersecurity and pollution liability insurance policies, among other policies, at varying levels of deductibles and limits that we believe are reasonable and prudent under the circumstances to cover our operations and assets. As we continue to grow, we will continue to evaluate our policy limits and retentions as they relate to the overall cost and scope of our insurance program.

Regulation

We are subject to a variety of laws in connection with our operations, including those related to the environment, health and safety, personal privacy and data protection, intellectual property, advertising and marketing, labor, competition and taxation. These laws and regulations are constantly evolving and may be interpreted, implemented, amended or revised in a manner that could harm our business. It also is possible that as our business grows and evolves, we will become subject to additional laws and regulations. There is no assurance that compliance with current laws and regulations or amended or newly adopted laws and regulations can be maintained in the future or that future expenditures required to comply with all such laws and regulations in the future will not be material. In the course of implementing our programs to comply with applicable laws and regulations, certain instances of potential non-compliance may be identified from time to time. We cannot predict the outcome of these matters, and cannot estimate a range of reasonably possible losses, if any. This section sets forth the summary of material laws and regulations relevant to our business operations.

Environmental and Occupational Safety and Health Matters

Our operations and the operations of our customers are subject to federal, state and local laws and regulations in the U.S. relating to protection of natural resources and the environment, health and safety aspects of our operations and waste management, including the disposal of waste and other materials. Numerous governmental entities, including the EPA and analogous state agencies, have the power to enforce compliance with these laws and regulations and the permits issued under them, often requiring difficult and costly actions. These laws and regulations may, among other things (i) require the acquisition of permits to take fresh water from surface water and groundwater, construct pipelines or containment facilities, drill wells and other regulated activities; (ii) restrict the types, quantities and concentration of various substances that can be released into the environment or injected into non-producing belowground formations; (iii) limit or prohibit our operations on certain lands lying within wilderness, wetlands and other protected areas; (iv) require remedial measures to mitigate pollution from former and ongoing operations; (v) impose specific safety and health criteria addressing worker protection; and (vi) impose substantial liabilities for pollution resulting from our operations. Any failure on our part or the part of our customers to comply with these laws and regulations could result in the impairment or cancellation of operations, assessment of sanctions, including administrative, civil and criminal penalties, injunctions, reputational damage, 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 of our activities in a particular area.

The trend in U.S. environmental regulation has recently been to place more restrictions and limitations on activities that may affect the environment, though this has been subject to change over the past decade. Any new laws and regulations, amendment of existing laws and regulations, reinterpretation of legal requirements or increased governmental enforcement that result in more stringent and costly construction, completion or water-management activities, or waste handling, storage transport, disposal, or remediation requirements could have a material adverse effect on our financial position and results of operations. The following is a summary of the more significant existing environmental and occupational safety and health laws in the U.S., as amended from time to time, to which our operations are subject and for which compliance may have a material adverse impact on our capital expenditures, results of operations or financial position.

Hazardous substances and wastes. The RCRA, and comparable state statutes regulate the generation, transportation, treatment, storage, disposal and cleanup of hazardous and non-hazardous 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 waters, 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 non-hazardous waste provisions, state laws or other federal laws. However, it is

possible that certain oil and gas drilling and production wastes now classified as non-hazardous could be classified as hazardous wastes in the future. Any loss of the RCRA exclusion for drilling fluids, produced waters and related wastes could result in an increase in our and our oil and gas producing customers’ costs to manage and dispose of generated wastes, which could have a material adverse effect on our and our customers’ results of operations and financial position. Effective December 7, 2023, the EPA issued “technical corrections” to RCRA hazardous waste regulations, correcting and clarifying specific provisions promulgated in the Hazardous Waste Generator Improvements rule, the Hazardous Waste Pharmaceuticals rule, and the Definition of Solid Waste rule. States may adopt these rules and may also modify them to become more stringent.

Wastes containing NORM may also be generated in connection with our operations. Certain processes used to produce oil and gas may enhance the radioactivity of NORM, which may be present in oilfield wastes. NORM is subject primarily to individual state radiation control regulations. Texas and New Mexico have both enacted regulations governing the handling, treatment, storage and disposal of NORM. 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, the management of waste piles, containers and tanks containing NORM, as well as restrictions on the uses of land with NORM contamination.

CERCLA, also known as the Superfund law, and comparable state laws impose liability, without regard to fault or legality of conduct, on classes of persons considered to be responsible for the release of a “hazardous substance” into the environment. These persons include the current and past owner or operator of the site where the hazardous substance release occurred and anyone who disposed or arranged for the disposal of a hazardous substance released at the site. Under CERCLA, such persons may be subject to joint and several, strict liability for the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. CERCLA also authorizes the EPA and, in some instances, third parties to act in response to threats to the public health or the environment and to seek to recover from the responsible classes of persons the costs they incur. In addition, neighboring landowners and other third parties may file claims for personal injury and property damage allegedly caused by the hazardous substances released into the environment. We generate materials in the course of our operations that may be regulated as hazardous substances.

Water discharges and use. The Federal Water Pollution Control Act, also known as the Clean Water Act (“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. Spill Prevention, Control and Countermeasure Plan requirements imposed under the CWA require appropriate containment berms and similar structures to help prevent the contamination of navigable waters in the event of a petroleum hydrocarbon tank spill, rupture or leak. In addition, the CWA and analogous state laws require individual permits or coverage under general permits for discharges of stormwater runoff from certain types of facilities. Federal and state regulatory agencies can impose administrative, civil and criminal penalties for non-compliance with discharge permits or other requirements of the CWA and analogous state laws and regulations.

The CWA also prohibits the discharge of dredge and fill material into regulated waters, including wetlands, unless authorized by permit. In 2015, the EPA and the U.S. Army Corps of Engineers (the “Corps”) under the Obama Administration published a final rule attempting to clarify the federal jurisdictional reach over waters of the U.S. However, the EPA rescinded this rule in 2019 and promulgated the Navigable Waters Protection Rule in 2020. The Navigable Waters Protection Rule defined what waters qualify as navigable waters of the United States under Clean Water Act jurisdiction. This rule was generally viewed as narrowing the scope of waters of the United States as compared to the 2015 rule, and litigation in multiple federal district courts challenged the rescission of the 2015 rule and the promulgation of the Navigable Waters Protection Rule. Then, in June 2021, the Biden Administration announced plans to develop its own definition for such waters, and in August 2021, a federal judge for the U.S. District Court for the District of Arizona issued an order

striking down the Navigable Water Protection Rule. On December 7, 2021, the U.S. Environmental Protection Agency and the Department of the Army (“the agencies”) announced a proposed rule to revise the definition of “waters of the United States” restoring the pre-2015 definition of “waters of the United States,” with updates to reflect consideration of Supreme Court decisions. The public comment period on the proposed rule closed on February 7, 2022. The final revised definition of “waters of the United States” was issued on December 30, 2022. The rule broadened the scope of the “waters of the United States” consistent with the framework of the pre-2015 regulations (also called the 1986 regulations). An expanded scope of the Clean Water Act’s jurisdiction in areas where we conduct operations bears the risk of causing us to incur increased costs and restrictions, delays or cancellations in permitting or projects, which developments could expose us to significant costs and liabilities. However, the Supreme Court’s decision on May 25, 2023 in Sackett v. EPA held that the Clean Water Act extends only to wetlands that have a continuous surface connection with “waters of the United States”- a narrowing (and reversal) of the Ninth Circuit’s interpretation. Further, the Trump administration may seek to return to the water policies advanced during the first Trump administration, focusing on less regulation under the Clean Water Act (including less wetlands protection) and potential repeal of the Biden administration’s “waters of the United States” rules.

Water handling facilities and seismicity. Saltwater disposal via underground injection is regulated pursuant to the 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 injection well 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 underground injection wells. Although we monitor the injection process of our wells, any leakage from the subsurface portions of the injection wells could cause degradation of fresh groundwater resources, potentially resulting in suspension of our UIC permit, 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 UIC disposal well regulations or the inability to obtain permits for new disposal wells in the future may affect our ability to dispose of produced water and other substances, which could affect our business.

Furthermore, in response to seismic events in the past several years near underground disposal wells used for the disposal by injection of produced water resulting from oil and gas activities, federal and some state agencies are investigating whether such wells have caused or contributed to increased seismic activity, and some states have restricted, suspended, or shut down the use of disposal wells within the vicinity of seismic events. In response to these concerns, regulators in some states have imposed, or are considering imposing, additional requirements in the permitting of produced water disposal wells or otherwise to assess any relationship between seismicity and the use of such wells.

We currently operate in the states of New Mexico and Texas, where the NMOCD and the TRC, respectively, have the authority to regulate disposal activity, including the authority to address seismic activity in their respective states. For example, the TRC requires applicants for new disposal wells that will receive non-hazardous produced water or other oil and natural gas waste to conduct seismic activity searches utilizing the U.S. Geological Survey. The searches are intended to determine the potential for earthquakes within a circular area of 100 square miles around a proposed new disposal well. If the permittee or an applicant for a disposal well permit fails to demonstrate that the produced water or other fluids are confined to the disposal zone, or if scientific data indicates such a disposal well is likely to be, or determined to be, contributing to seismic activity, then the TRC may deny, modify, suspend or terminate the permit application or existing operating permit for that disposal well. The TRC has used this authority to deny permits for certain waste disposal wells.

Most recently, in 2021, the NMOCD and TRC created SRAs with action plans to address seismic activity as further discussed below.

New Mexico

The NMOCD has implemented a Seismic Response Protocol, which outlines certain reporting and curtailment requirements for operators in SRAs to follow in response to seismic events based on the magnitude and proximity to the event. The NMOCD created the Hat Mesa SRA in Northern Lea County, New Mexico in response to a seismic event that occurred in that area in the fourth quarter of 2021. The Hat Mesa SRA and associated Seismic Response Protocol resulted in additional reporting requirements, including more frequent reporting with daily injection volume and pressure data for operators within 10 miles of the seismic event, and the reduction of monthly injection volumes for wells within six miles of the seismic event. We operate four wells located within the Hat Mesa SRA that are subject to the protocol. In September 2023, we temporarily curtailed one of these wells in response to a seismic event in Lea County, New Mexico. Due to the uncertainty regarding the causal factors of the event, the NMOCD did not create an SRA nor require the operators of disposal wells within 10 miles of the seismic event to follow the established Seismicity Response Protocol. Therefore, we returned the temporarily curtailed well to pre-curtailment levels beginning on November 1, 2023. As of December 31, 2024, we have partially curtailed injection in one of the wells by approximately 5 kbwpd and continue to operate the partially curtailed well. However, to date we have not had an operational impact on gathering volumes. We are also required to submit daily injection and pressure volumes on a weekly reporting basis. There was no further seismic activity within the Hat Mesa SRA in 2023 or 2024.

Texas

The TRC established the Stanton SRA in 2022. The Stanton SRA is located in Martin County and the western portion of Howard County. Saltwater disposal well operators within the Stanton SRA created a response plan which began on May 15, 2022. The plan employed a two-tiered approach based on the depth of the disposal zone (shallow versus deep disposal wells) and includes expanded data collection efforts, contingency responses for future seismicity, and scheduled checkpoint updates with TRC staff. Following the sale of our assets located in Martin County in 2023, we no longer operate any wells within the Stanton SRA.

The Northern Culberson-Reeves SRA was established in 2021 and expanded in 2022, which expansion partially overlaps with our operations in Northern Culberson, Reeves, and Loving Counties, Texas. However, to date the Northern-Culberson-Reeves SRA has not had a material impact on our operations.

See Part I, Item 1A. Risk Factors ─ Legislation or regulatory initiatives intended to address seismic activity could restrict our ability to recycle or handle produced water gathered from our E&P customers and, accordingly, could have a material adverse effect on our business.

See also Part II, Item 7. Management’s Discussion and Analysis of Results of Operations ─ General Trends and Outlook – Seismicity for a discussion of the impact on our business.

Hydraulic fracturing activities. 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. For example, the EPA has asserted regulatory authority pursuant to the SDWA UIC program over hydraulic fracturing activities involving the use of diesel and issued guidance covering such activities, as well as published an Advanced Notice of Proposed Rulemaking regarding TSCA reporting of the chemical substances and mixtures used in hydraulic fracturing.

Various policy makers, regulatory agencies and political candidates at the federal, state and local levels have proposed restrictions on hydraulic fracturing, including its outright prohibition. Some state and local governments 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 states where we or our customers operate. In recent years, for example, various bills have been introduced in the New Mexico Senate to place a moratorium on hydraulic fracturing, and in 2024, a ban on hydraulic fracturing came into effect in California, following a years-long moratorium.

In the event that new federal, state or local restrictions or bans on the hydraulic fracturing process are adopted in areas where we or our customers conduct business, we or 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 our services and have a material adverse effect on our liquidity, consolidated results of operations, and consolidated financial condition. However, it is possible that, under the second Trump administration, hydraulic fracturing will increase, particularly on federal lands.

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 to obtain pre-approval 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 oil and gas projects. Over the next several years, we or our customers may incur certain capital expenditures for air pollution control equipment or other air emissions-related issues. For example, in 2015, the EPA issued a final rule under the CAA, lowering the NAAQS for ground-level ozone from the current standard of 75 parts per million to 70 parts per million under both the primary and secondary standards to provide requisite protection of public health and welfare, respectively. Since that time, the EPA has issued area designations with respect to ground-level ozone and final requirements that apply to state, local, and tribal air agencies for implementing the 2015 NAAQS for ground-level ozone, which the EPA reaffirmed in 2020.

Climate Change. Numerous regulatory initiatives related to climate change have been enacted, and are likely to continue to be developed, 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. At the federal level, in December 2009, the EPA determined that emissions of carbon dioxide, methane and other GHGs endanger public health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the Earth’s atmosphere and other climatic changes. Based on these findings, the EPA began adopting and implementing regulations to restrict emissions of GHGs under existing provisions of the CAA. In November 2021, the EPA also proposed New Source Performance Standards updates and emission guidelines to reduce methane and other pollutants from the oil and gas industry.

During the Biden administration, the President and the Democratic Party identified climate change as a priority. The Biden Administration, for example, reentered the United States into the Paris Agreement in February 2021. In addition, the Biden Administration issued multiple executive orders pertaining to environmental regulations and climate change, including the Executive Order on Protecting Public Health and the Environment and Restoring Science to Tackle the Climate Crisis and Executive Order on Tackling the Climate Crisis at Home and Abroad. In the latter executive order, President Biden established climate change as a primary foreign policy and national security consideration, affirmed that achieving net-zero GHG emissions by or before midcentury is a critical priority, affirmed the Biden Administration’s desire to establish the United States as a leader in addressing climate change, generally further integrated climate change and environmental justice considerations into government agencies’ decision-making, and eliminated fossil fuel subsidies, among other measures. Under the Paris Agreement, the Biden Administration committed the United States to reducing its GHG emissions by 50-52% from 2005 levels by 2030. In November 2021, the United States and other countries entered into the Glasgow Climate Pact, which includes a range of measures designed to address climate change, including but not limited to the phase-out of fossil fuel subsidies, reducing methane emissions 30% by 2030, and cooperating toward the advancement of the

development of clean energy. In August 2022, the Inflation Reduction Act of 2022 was enacted and included a $369 billion investment in modernizing the American energy system. The legislation is aimed at helping the United States achieve the 50-52% reduction of GHGs from 2005 levels by 2030. In December 2022, the EPA issued a supplemental proposal to update, strengthen, and expand the standards proposed in November 2021 and further reduce methane and volatile organic compound emissions from oil and natural gas facilities. In May 2023, the EPA proposed revised new source performance standards under Clean Air Act section 111(b) for GHG emissions from certain sources.

While Congress has from time to time considered legislation to reduce emissions of GHGs, there has not been significant new activity in the form of adopted legislation to reduce emissions of GHGs in recent years. Instead, the federal government has worked through agencies, such as the EPA, to target and reduce GHG emissions through regulations and standards, and many states (and their state level environmental agencies) have established rules aimed at reducing or tracking GHG emissions. In January 2019, New Mexico’s governor signed an executive order declaring that New Mexico would support the goals of the Paris Agreement by joining the U.S. Climate Alliance, a bipartisan coalition of governors committed to reducing GHG emissions consistent with the goals of the Paris Agreement. The stated objective of the executive order is to achieve a statewide reduction in GHG emissions of at least 45% by 2030 as compared to 2005 levels. The executive order also requires New Mexico regulatory agencies to create an “enforceable regulatory framework” to ensure methane emission reductions. Pursuant to that executive order, in 2020, the New Mexico Oil Conservation Division and New Mexico Environment Department proposed certain rules regarding the reduction of natural gas waste and the control of emissions. The final rule, known as the Ozone Precursor Rule, was published on July 26, 2022 and became effective on August 5, 2022. It is more protective than current federal requirements. The New Mexico Ozone Precursor Rule includes, among other things, requirements that upstream and midstream operators reduce natural gas waste by a fixed amount each year and achieve a reduction in ozone precursor pollutants (volatile organic compounds and oxides of nitrogen) of approximately 260 million pounds annually. The Ozone Precursor Rule contains requirements applicable to produced water management units (“PWMUs”) (defined to include recycling facilities, permanent pits, and ponds designed to accumulated produced water—the incidental byproduct of well completion and oil and gas production—with storage capacity of at least 50,000 barrels), such as emissions standards, monitoring requirements, and recordkeeping requirements. Similar efforts have been made in the New Mexico state legislature, including introduction in January 2022 of the Clean Future Act to establish GHG emissions limits; the Clean Future Act was postponed indefinitely in committee.

Many states have also established or begun participating in GHG cap and trade programs. Most of these cap and trade programs work by requiring major sources of emissions, such as electric power plants, or major producers of fuels, such as refineries and natural gas processing plants, to acquire and surrender emission allowances. The number of allowances available for purchase is reduced each year in an effort to achieve the overall GHG emission reduction goal.

In January 2025, the Trump Administration issued executive orders seeking to curb or rollback many of these climate change initiatives and increase support for domestic fossil fuels, including to withdraw the United States from the Paris Agreement, pause regulatory rulemaking, rescind multiple Biden Administration executive orders on climate initiatives, halt funding pursuant to the Inflation Reduction Act and Infrastructure Investment and Jobs Act and revisit prior guidance related to the authority of the EPA.

Endangered Species. The ESA restricts activities that may affect endangered or threatened species or their habitats. Similar protections are offered to migratory birds under the federal MBTA and BGEPA. To the degree that species listed under the ESA or similar state laws, or are protected under the MBTA or BGEPA, live in the areas where we or our oil and gas producing customers operate, our and our customers’ abilities to conduct or expand operations and construct facilities could be limited or 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 operations and the operations of our customers are located in areas that are designated as habitats for protected species. In addition, the USFWS may make determinations on the listing of unlisted species as endangered or

threatened under the ESA. The USFWS declared the southern population of the lesser prairie-chicken as an endangered species on November 25, 2022. We entered into the voluntary Candidate Conservation Agreement (“CCAA”) in January 2023. By voluntarily participating in the CCAA, our ongoing oil and gas activities have greater flexibility in project development in the lesser-prairie chicken range and we avoid a lengthy project consultation on each new project between the BLM and USFWS. The designation of previously unidentified endangered or threatened species could indirectly cause us to incur additional costs, cause our or our oil and gas producing customers’ operations to become subject to operating restrictions or bans and limit future development activity in affected areas. For example, in May 2024, the dunes sagebrush lizard native to southeast New Mexico and west Texas was listed as endangered, a move sparking allegations that the designation occurred to hinder fossil fuel production. This resulted in a federal lawsuit filed in the Western District of Texas aimed at overturning the designation. Further, the USFWS 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.

Chemical Safety. We are subject to a wide array of laws and regulations governing chemicals, including the regulation of chemical substances and inventories, such as TSCA in the U.S. These laws and regulations change frequently and have the potential to limit or ban altogether the types of chemicals we may use in our products, as well as result in increased costs related to testing, storing, and transporting our products prior to providing them to our customers. For example, in 2016, President Obama signed into law the Frank R. Lautenberg Chemical Safety for the 21st Century Act (the “Lautenberg Act”), which substantially revised TSCA. Among other items, the Lautenberg Act eliminated the cost-benefit approach to analyzing chemical safety concerns with a health-based safety standard and requires all chemicals in commerce, including those “grandfathered” under TSCA, to undergo a safety review. The Lautenberg Act also requires safety findings before a new chemical can enter the market. The EPA, charged with implementing the Lautenberg Act, has the ability to interpret new provisions of the Lautenberg Act in ways that cannot be predicted, and it is always possible that new legislation or new regulations may be adopted pursuant to these regulatory and legislative efforts, which could impact our business, such as: any new restrictions on the development of new products; increases in regulation; and disclosure of confidential, competitive information.

Furthermore, governmental, regulatory and societal demands for increasing levels of product safety and environmental protection could result in increased pressure for more stringent regulatory control with respect to the chemical industry. These concerns could influence public perceptions regarding our products and operations, the viability of certain products, our reputation, the cost to comply with regulations, and the ability to attract and retain employees. Moreover, changes in environmental, health and safety regulations could inhibit or interrupt our operations, or require us to modify our facilities or operations. Accordingly, environmental or regulatory matters may cause us to incur significant unanticipated losses, costs or liabilities, which could reduce our profitability.

Occupational Safety and Health and other legal requirements. We are subject to the requirements of the federal Occupational Safety and Health Act and comparable state statutes whose purpose is to protect the health and safety of workers. In addition, the OSHA’s hazard communication standard, the EPA’s Emergency Planning and Community Right-to-Know Act and comparable state regulations and any implementing regulations require that we organize and/or disclose information about hazardous materials used or produced in our operations and that this information be provided to employees, state and local governmental authorities and citizens. We have an internal program of inspection designed to monitor and enforce compliance with worker safety requirements.

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 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 common stock could be materially adversely affected.

Risks Related to Our Business

Our business depends on capital spending by the oil and gas industry in the Permian Basin and reductions in capital spending could have a material adverse effect on our liquidity, results of operations and financial condition.

Demand for our services is directly affected by capital spending by our customers to explore for, develop and produce oil and gas in the Permian Basin. Our produced water handling revenues are substantially dependent upon oil, natural gas and NGL production from our customers’ upstream activity. Our Water Solutions revenues are substantially dependent upon the number of wells drilled and completed by our customers and the amount of water used in completing each well. In addition, there is a natural decline in production from existing wells that are connected to our gathering systems. We have no control over the amount of resources that our customers devote to the development of oil and gas reserves.

Industry conditions that affect capital spending are influenced by numerous factors over which we have no control, including, among other things:

Prior adverse changes in the global economic environment and capital markets and declines in prices for crude oil and natural gas have caused many customers to reduce capital budgets for future periods and have caused decreased demand for crude oil and natural gas. Limitations on the availability of capital, or higher costs of capital, for financing expenditures have caused and may continue to cause customers to make additional reductions to capital budgets in the future even if commodity prices increase from current levels. If oil and gas prices decline, our customers may further reduce their exploration, development and production activities and demand lower rates for our services or delay, modify, or terminate their use of our services. If our customers fail to maintain or increase their capital spending and demand for our services, it could have a material adverse effect on our liquidity, results of operations and financial condition.

If oil prices or natural gas prices remain volatile or were to decline, the demand for our services could be adversely affected.

The volume of water we process is driven in large part by the level of crude oil production, which is primarily determined by current and anticipated oil and natural gas prices and demand and the related levels of capital spending and drilling activity in the areas in which we have operations. Volatility or weakness in oil prices or natural gas prices (or the perception that oil prices or natural gas prices will decrease), oil and gas investor expectations and other factors beyond our control affect the spending patterns of our customers and may result in the drilling or completion of fewer new wells or lower production spending on existing wells. This, in turn, could lead to lower demand for our services and may cause lower rates and lower utilization of our assets. Prices for oil and natural gas historically have been extremely volatile and are expected to continue to be volatile. During the year ended December 31, 2024, the average WTI spot price was $76.63 versus an average price of $77.58 for the year ended December 31, 2023. If oil prices or natural gas prices decline, or if completions activity is reduced, the demand for our services and our results of operations could be materially and adversely affected. Even in an environment of stronger oil and gas prices, fewer oil and gas completions in our market areas as a result of decreased capital spending may have a negative long-term impact on our business. In addition, certain of our contracts, including a contract with one of our significant customers, provide for rates that periodically fluctuate within a defined range in response to changes in the WTI price; therefore, a portion of our revenue is directly exposed to fluctuations in the price of crude oil.

Additionally, as part of our water processing activities, we aggregate and sell recovered crude oil, also known as skim oil. A portion of our cash flow from operations is dependent on skim oil sales revenue, which is

directly exposed to fluctuations in the price of crude oil. Fluctuations and decreases in production volume or the price that we receive for skim oil could impact our liquidity, results of operations or financial condition.

The fees charged to customers under our agreements for the gathering, transportation or handling of produced water may not escalate sufficiently to cover increases in costs and the agreements may be suspended in some circumstances, which would affect our profitability.

Our costs may increase more rapidly than the fees that we charge to customers pursuant to our contracts with them. If inflation and other cost increases, such as the cost for labor, chemical treatment, rental equipment and fuel expenses, outpace the fees we charge to customers, as they have from time to time during recent periods, our profit margins will be reduced. Additionally, some customers’ obligations under their agreements with us may be permanently or temporarily reduced upon the occurrence of certain events, some of which are beyond our control, including force majeure events wherein the supply of produced water is curtailed or cut off. Force majeure events generally include (but are not limited to) revolutions, wars, acts of enemies, embargoes, import or export restrictions, strikes, lockouts, fires, storms, floods, acts of God, explosions, mechanical or physical failures of our equipment or facilities of our customers. If the escalation of fees is insufficient to cover increased costs, or if any customer suspends or terminates its contracts with us, our profitability could be materially affected.

We operate in a highly competitive industry, which may intensify if our competitors expand their water supply, produced water recycling, and produced water handling operations or customers elect to operate their water-management services in-house or enter into arrangements with other oil and gas producers for water-management services rather than outsource these services to companies like us, thereby causing us to lose market share, which could, in turn, negatively affect our ability to expand our operations.

The Produced Water Handling and Water Solutions businesses are highly competitive and include numerous companies capable of competing effectively in our markets on a local basis. In our Water Solutions business, we compete with landowners, water supply and transfer companies, and companies who engage in the sale or treatment of produced water. Our Produced Water Handling business is in direct and indirect competition with other businesses, including water handling and other produced water treatment businesses. Some of our larger diversified competitors have a broad geographic scope, as well as greater financial and other resources than us, while others focus on specific basins only and may have locally competitive cost efficiencies as a result.

Additionally, there may be new companies that enter the water solutions business, or our existing and potential customers may develop their own water management solutions. Our ability to maintain current revenue and cash flows, and our ability to expand our operations, could be adversely affected by the activities of our competitors and our customers. If our competitors substantially increase the resources they devote to the development and marketing of competitive services or substantially decrease the prices at which they offer their services, we may be unable to effectively compete. If our existing and potential customers choose to operate their water-management services in-house or enter into arrangements with other oil and gas producers for water-management services rather than outsource these services to companies like us, including by developing their own water handling or solutions businesses, we may not be able to effectively replace that revenue. In addition, several of our long-term contracts for our Produced Water Handling business are up for renewal in the next few years. Our inability to renew these contracts at or above current pricing, or at all, could negatively impact our business. All of these competitive pressures could have a material adverse effect on our business, results of operations and financial condition.

Our Produced Water Handling business depends upon available pore space in subsurface geologic formations by which we can dispose of produced water through underground injection wells. Our inability to acquire new pore space or our loss of existing pore space may negatively impact our ability to service new and existing customers.

We dispose of produced water generated by our customers during oil and gas operations by drilling disposal wells and injecting such produced water into porous subsurface geologic formations. The amount of subsurface pore space that is capable of permanently storing injected produced water is finite and requires constant replenishment. As we continue to inject produced water into our existing produced water disposal wells, we may exhaust the geologic or technical limits of the subsurface strata for produced water injection. Furthermore, state regulatory bodies in Texas and New Mexico, which have permitting authority over disposal wells, have imposed new requirements in the permitting of produced water disposal wells to assess any relationship between induced seismicity and the use of such wells. State regulators may deny, modify, suspend or terminate permits on grounds that a disposal well is likely to be, or determined to be, causing seismic activity or would be operating at impermissible pressure levels. States have also issued, and may in the future issue, orders to temporarily shut down or to curtail the injection depth, injection capacity or injection rate of existing wells because of concerns over induced seismicity.

Any loss of pore space or injection capacity for technical, geological or regulatory reasons could require us to spend significant time and capital expenditure to locate, apply for, permit, drill, complete and place into service new disposal wells and to build pipeline infrastructure to transport produced water to such new wells. Our customers’ oil and gas production growth plans may also require us to secure additional pore space and disposal wells and build new pipeline infrastructure. Permits for new disposal wells could be challenged for a variety of reasons by our competitors, oil and gas producers, landowners or non-governmental organizations. Such regulatory challenges could be successful and prevent us from being able to secure additional disposal capacity. New disposal wells may also subject us to higher royalty rates. Furthermore, we may not have contractual or real property rights to dispose of produced water at locations that are in geographic proximity to our customers’ existing or new oil and gas production wells or our existing injection wells and pipeline infrastructure. In such cases, we would be required to spend significant amounts of capital to build new pipeline infrastructure to transport produced water to distant disposal locations.

If we are unable to accept all of the produced water delivered to us by our customers because we lack available pore space for underground injection, we could be subject to contractual penalties for alternative disposal solutions, including trucking, and such penalties could be significant. Any curtailment of our customers’ oil and gas production due to a lack of available pore space or injection capacity would result in lost revenue to us and could trigger contractual termination rights. Any of these events, either individually or in aggregate, could result in a material adverse effect on our business, results of operation and financial condition.

Growing or adapting our business by constructing new transportation systems and facilities subjects us to construction risks and risks that supplies for such systems and facilities will not be available upon completion thereof.

One of the ways we intend to grow our business is through the construction of expansions to our existing systems and facilities and/or the construction of new systems and facilities, such as produced water pipelines, produced water injection wells, treatment facilities, water handling facilities and other infrastructure. These projects and any similar projects that we are obligated to undertake to support existing customers’ operations require the expenditure of significant amounts of capital, which may exceed our resources, and involve numerous regulatory, environmental, political and legal uncertainties, including political opposition by landowners, environmental activists and others. There can be no assurance that we will complete these projects on schedule, or at all, or at the budgeted cost. We could also encounter technical difficulties during the drilling of a disposal well leading to a reduction in capacity or a shorter useful life. Our revenues may not increase upon the expenditure of funds on a particular project. Moreover, we may undertake these projects to capture anticipated future growth in production in a region in which anticipated production growth does not

materialize or for which we are unable to acquire new customers. As a result, our new facilities and infrastructure may not be able to attract enough demand for our services to achieve our expected investment return, which could materially and adversely affect our results of operations and financial position. In addition, we may also deem it necessary to construct new wells and related pipelines so as to ensure the desired or required amount of spacing between wells. This can require substantial costs, delays in growth of operations, or risks of entering new areas.

We face opposition to the development or operation of our water pipelines, injection wells and facilities from various individuals and groups.

We have experienced opposition to the development or operation of our water pipelines, injection wells and facilities from our competitors, oil and gas producers, landowners and other third parties and may in the future face opposition from various individuals or groups such as government officials, environmental groups, tribal 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 operations, intervention in regulatory or administrative proceedings related to our permitting efforts or otherwise involving our assets, or lawsuits or other actions designed to prevent, disrupt or delay the operation of our assets and business. For example, repairing our pipelines often involves securing consent from individual landowners to access their property and provide us with sufficient temporary space to allow us to conduct repairs. One or more landowners may resist our efforts to make needed repairs, which could lead to an interruption in the operation of the affected pipeline or facility for a period of time that is significantly longer than would have otherwise been the case. 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 our 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 we require to conduct our operations to be withheld, delayed or burdened by requirements that restrict our ability to profitably conduct our business. Any such event that delays or otherwise interrupts the revenues generated by our operations, or which causes us to make significant expenditures not covered by insurance, could adversely affect our results of operations and financial condition.

There is uncertainty related to the future of the oil and natural gas industry broadly.

Although we are not directly engaged in the extraction of oil and natural gas, produced water is a natural byproduct of crude oil and natural gas production so efforts in recent years in the investment community to reduce access to capital markets and pressure lenders to limit funding or increase the cost of lending to companies engaged in the extraction of oil and natural gas may adversely affect our business and limit our access to capital. The negative sentiment toward the oil and natural gas industry compared to other industries has led to lower oil and gas representation in certain key equity market indices. Some investors, including certain pension funds, university endowments and family foundations, have stated policies to reduce or eliminate their investments in the oil and gas sector based on social and environmental considerations. Many political and regulatory authorities, along with certain financing sources and well-funded environmental activist groups, are devoting substantial resources and efforts to minimize or eliminate the use of oil and natural gas as a source of energy, domestically and internationally, which could reduce the demand and pricing for ancillary services, including our services, interfere with our customers’ business activities and operations, and potentially materially and adversely impact our future financial results, liquidity, ability to raise capital and growth prospects.

Concerns about the environmental impacts of the oil and natural gas industry, including impacts on global climate, have resulted in certain increased regulation and standards aimed at reducing GHG emissions, unfavorable lending policies toward the financing of oil and natural gas operations and divestment efforts affecting the industry and the investment community, and any such event in the future could adversely affect demand for our services. Certain members of the investment community increased their focus on ESG practices and disclosures, including practices and disclosures related to GHGs and climate change in the

energy industry in particular. As a result, we may face pressure regarding our ESG practices and disclosures from these and other stakeholders (who may or may not agree with our practices or disclosures). We have announced, and may announce in the future, various sustainability or other ESG related commitments, goals or targets that are ambitious and we may be unable to meet such commitments, goals or targets in the manner or on the timeline as initially contemplated, which could expose us to investor scrutiny, government enforcement actions and private litigation. Regardless of our reporting regime or content, certain investors and organizations may publish ratings or views on our sustainability or other ESG efforts or disclosures that are not favorable. This could limit our access to capital, impair our ability to attract talent, and have an adverse impact on our business.

In addition, increasing attention to the risks of climate change has resulted in an increased possibility of lawsuits brought by public and private entities against oil and natural gas operators. If any of our customers are targeted by any such litigation and incur liability, which, to the extent that societal pressures or political or other factors are involved, could be imposed without regard to our causation of or contribution to the asserted damage or to other mitigating factors, demand for our services could be adversely affected.

The ability to attract and retain key members of management, other key personnel and qualified Board members is critical to the success of our business.

Our success depends to a large extent upon the efforts and abilities of our senior management team and other key personnel and the experience and knowledge of our Board members. The ability to attract and retain these key personnel may be difficult in light of the volatility of our business. Acquiring and keeping personnel could prove more difficult or cost substantially more than estimated. These factors could cause us to incur greater costs or prevent us from pursuing our business strategy as quickly as we would otherwise wish to do. If executives or other key personnel resign, retire or are terminated, or their service is otherwise interrupted, we may not be able to replace them adequately or in a timely manner and we could experience significant declines in productivity.

We may have difficulty securing sufficient labor to meet our needs.

We are dependent upon the available labor pool of skilled employees and may not be able to find enough labor to meet our needs, which could have a negative effect on our growth. We are also subject to the Fair Labor Standards Act, which governs such matters as minimum wage, overtime and other working conditions. Our services require skilled workers who can perform physically demanding work. As a result of our industry volatility, pronounced declines in drilling and completions activity, as well as the demanding nature of the work, many workers have left the oilfield services sector to pursue employment in different fields. If we are unable to retain or meet the growing demand for skilled technical personnel, our operating results and our ability to execute our growth strategies may be adversely affected.

The growth of our business through acquisitions may expose us to various risks, including those relating to difficulties in identifying suitable, accretive acquisition opportunities and integrating businesses, assets and personnel, as well as difficulties in obtaining financing for targeted acquisitions and the potential for increased leverage or debt service requirements.

As a component of our business strategy, we pursue acquisitions of assets, businesses and technologies. Acquisitions involve numerous risks, including:

In evaluating acquisitions, we generally prepare one or more financial cases based on a number of business, industry, economic, legal, regulatory and other assumptions applicable to the proposed transaction. Although we expect a reasonable basis will exist for those assumptions, the assumptions will generally involve current estimates of future conditions. Realization of many of the assumptions will be beyond our control. Future commercial opportunities may need to develop with respect to an acquisition in order for us to realize the expected benefits from such acquisition. Moreover, the uncertainty and risk of inaccuracy associated with any financial projection will increase with the length of the forecasted period. Some acquisitions may not be accretive in the near term and will be accretive in the long-term only if we are able to timely and effectively integrate the underlying assets and such assets perform at or near the levels anticipated in our acquisition projections.

The process of integrating an acquired business may involve unforeseen costs and delays or other operational, technical, regulatory, legal and financial difficulties and may require a significant amount of time and resources. Our failure to successfully incorporate the acquired business and assets into our existing operations or to minimize any unforeseen operational, technical, regulatory, legal or financial difficulties could have a material adverse effect on our financial condition and results of operations. Furthermore, there is intense competition for acquisition opportunities in our industry. Competition for acquisitions may increase the cost of, or cause us to refrain from, completing acquisitions.

In addition, we may not have sufficient capital resources to complete acquisitions. We may incur substantial indebtedness to finance future acquisitions and also may issue equity, debt or convertible securities in connection with such acquisitions. Debt service requirements could represent a significant burden on our results of operations and financial condition and the issuance of additional equity or convertible securities could be dilutive to our existing equity holders. Furthermore, we may not be able to obtain additional financing on satisfactory terms. Even if we have access to the necessary capital, we may be unable to continue to identify suitable acquisition opportunities, negotiate acceptable terms or successfully acquire identified targets.

Our operations are subject to inherent risks in the oil and gas industry, some of which are beyond our control. These risks may be self-insured, or may not be fully covered under our insurance policies.

Our operations are subject to hazards inherent in the oil and gas industry, such as, but not limited to, accidents and releases of produced water into the environment. These conditions can cause:

The occurrence of a significant event or adverse claim in excess of the insurance coverage that we maintain or that is not covered by insurance could have a material adverse effect on our liquidity, results of operations and financial condition. Any interruption in our services due to pipeline breakdowns or necessary maintenance, workovers or repairs to our wells or other facilities could reduce our revenues and earnings. Variability of maintenance, workover or repair expense could have a significant negative impact on our gross margin and earnings. In addition, the hazards and risks associated with the transport, storage, handling, treatment and disposal of produced water has and may continue to expose us to claims from our employees, customers, and third parties, including, but not limited to, personal injury claims, property damage claims (including claims related to reservoir damage or subsurface trespass) and/or environmental liability claims. Litigation arising from a significant or catastrophic occurrence at a location where our equipment and services are being used may result in our being named as a defendant in lawsuits asserting large claims for which we may not be adequately indemnified or for which we have agreed to indemnify a customer or other third-party. Due to the unpredictable nature of such events and litigation, it is not possible to predict their impact on our results or the ultimate outcome of any current or future claims or lawsuits with certainty, and we may be held liable for significant losses.

We do not have insurance against all foreseeable risks, either because insurance is not available or because of the high premium costs. The occurrence of an event not fully insured against or the failure of an insurer to meet its insurance obligations could result in substantial losses. In addition, we may not be able to maintain adequate insurance in the future at rates we consider reasonable. Insurance may not be available to cover any or all of the risks to which we are subject, or, even if available, it may be inadequate, or insurance premiums or other costs could rise significantly in the future so as to make such insurance prohibitively expensive. Insurance may be inadequate in circumstances where, among others, we are unable to enforce the contractual allocation of potential liability and risks in our agreements with third-parties, where we incur an unforeseen liability falling outside the scope of such allocation or where we are required to enter into agreements in which such allocation is otherwise unfavorable to us. As a result, we may incur substantial losses which could materially and adversely affect our financial condition and results of operations.

A loss of one or more significant customers could materially or adversely affect our results of operations.

We expect to continue to depend on a limited number of key customers to support our revenues for the foreseeable future. Any development that materially and adversely affects these customers could result in a reduction in our customers’ spending for our services. Our two largest customers for the year ended December 31, 2024 represented approximately 53% of our revenues. The loss of key customers, failure to renew contracts upon expiration, or a sustained decrease in demand by one or more key customers could result in a substantial loss of revenues and could have a material and adverse effect on our results of operations.

Because a significant portion of our revenues is derived from ConocoPhillips and Chevron U.S.A. Inc., any development that materially and adversely affects ConocoPhillips’ and Chevron U.S.A. Inc.’s operations, financial condition or market reputation could have a material adverse impact on us.

ConocoPhillips is our largest customer, is a significant shareholder in us and is expected to play a significant role in our success. Accordingly, we are indirectly subject to the business risks of ConocoPhillips. Because a significant portion of our revenues is derived from ConocoPhillips and Chevron U.S.A. Inc., any development that materially and adversely affects ConocoPhillips’ and Chevron U.S.A. Inc.’s operations, financial condition or market reputation could have a material adverse impact on us. For the year ended December 31, 2024,

ConocoPhillips and its affiliates and Chevron U.S.A. Inc. accounted for approximately 32% and 21% of our total consolidated revenues, respectively. As of December 31, 2024, ConocoPhillips and its affiliates and Chevron U.S.A. Inc. accounted for approximately 16% and 34% of our accounts receivable.

Our lack of diversification increases the risk of an investment in us and we are vulnerable to risks associated with operating primarily in one geographic area.

All of our operations are in the Permian Basin in Texas and New Mexico, making us vulnerable to risks associated with operating in one geographic area. Due to the concentrated nature of our business activities, a number of our properties could experience any of the same conditions at the same time, resulting in a relatively greater impact on our results of operations than they might have on other companies that are more diversified. In particular, we may be disproportionately exposed to the impact of regional supply and demand factors, availability of equipment, facilities, personnel or services, significant governmental regulation, natural disasters, adverse weather conditions, water shortages or other drought related conditions. Such delays or interruptions could have a material adverse effect on our financial condition, results of operations and cash flows.

Seasonal weather conditions and natural or man-made disasters could severely disrupt normal operations and have an adverse effect on our business, financial position and results of operations.

We operate in the Permian Basin which may be adversely affected by seasonal weather conditions and natural or man-made disasters. During periods of heavy snow, ice, rain or extreme weather conditions such as high winds and tornados or after other natural disasters such as earthquakes or wildfires, we may be unable to access our assets and our facilities may be damaged or our customers may choose to curtail volumes, thereby reducing our ability to provide services and generate revenues. For example, numerous earthquakes have been recorded recently in West Texas and Southeastern New Mexico. In addition, hurricanes or other severe weather in areas where we do not operate, such as the Gulf Coast region (including those weather-related events which may be caused or exacerbated by climate change), could seriously disrupt the supply of products and cause serious shortages in various areas, including the areas in which we do operate. Such disruptions could potentially have a material adverse impact on our business, consolidated financial position, results of operations and cash flows.

We engage in transactions with related parties and such transactions present possible conflicts of interest that could have an adverse effect on us.

We have historically entered into a number of transactions with related parties. In particular, we have entered into a water gathering and handling agreement with ConocoPhillips, which owned approximately 47% of our Class B common stock and a 22% interest in Solaris LLC (representing approximately 22% of our combined economic interest and voting power), as of December 31, 2024. In addition, a member of our Board of Directors is affiliated with ConocoPhillips. Related party transactions create the possibility of conflicts of interest with regard to our management. Such a conflict could cause an individual in our management to seek to advance his or her economic interests above ours. Further, the appearance of conflicts of interest created by related party transactions could impair the confidence of our investors. It is possible that a conflict of interest could have a material adverse effect on our liquidity, results of operations and financial condition.

Defaults by customers and counterparties could adversely affect our business, financial condition, and results of operations. 

The deterioration in the financial condition of one or more of our significant customers or counterparties could result in their failure to perform under the terms of their agreement with us or default in the payment owed to us. Our customers and counterparties include crude oil and natural gas producers, equipment suppliers and groundwater suppliers whose creditworthiness may be suddenly and disparately impacted by, among other factors, commodity price volatility, deteriorating energy market conditions, and public and regulatory opposition to energy producing activities. While we have credit approval procedures and policies in place, we

are unable to completely eliminate the performance and credit risk to us associated with doing business with these parties. In a low commodity price environment, certain of our customers have been or could be negatively impacted, causing them significant economic stress resulting, in some cases, in a customer bankruptcy filing or an effort to renegotiate our contracts. The deterioration in the creditworthiness of our customers and the resulting increase in nonpayment and/or nonperformance by them could cause us to write down or write off accounts receivables or tangible and intangible assets. Such write-downs or write-offs could negatively affect our operating results in the periods in which they occur, and, if significant, could have a material adverse effect on our business, financial condition, results of operations, and cash flows.

We may not be able to keep pace with technological developments in our industry.

The oil and gas industry is characterized by rapid and significant technological advancements and introductions of new products and services using new technologies. As others use or develop new technologies, we may be placed at a competitive disadvantage, and competitive pressures may force us to implement those new technologies at substantial cost. In addition, other companies in our industry may have greater financial, technical and personnel resources that allow them to enjoy technological advantages and may allow them to implement new technologies before we can. We may not be able to respond to these competitive pressures and implement new technologies on a timely basis or at an acceptable cost. If one or more of the technologies we use now or in the future were to become obsolete or if we are unable to use the most advanced commercially available technology, our business, financial condition, results of operations and cash flows could be adversely affected.

Our initiatives related to the development of technologies for the beneficial reuse of produced water require a substantial investment by us in research and development expenses and may not be successful or achieve market acceptance.

We have incurred significant expenditures to fund our research and development efforts related to the development of technologies for the beneficial reuse of produced water, and we intend to continue those expenditures in the future. However, research and development is by its nature speculative, and there can be no assurances that these expenditures will result in the development of new technology or that any new technology we develop will be commercially marketable or profitable to us. Many of our competitors in the development of such technology are large multinational companies that have significantly greater financial and personnel resources than we have, and they may be able to devote greater resources to research and development of technologies than us. In addition, our ability to compete effectively in the beneficial reuse space may also depend on our ability to obtain patents on proprietary technology. The inability to protect any innovations through patents could adversely affect our business, financial condition and results of operations.

We may be required to take write-downs of the carrying values of our long-lived assets and finite-lived intangible assets.

We evaluate our long-lived assets, such as property and equipment, and finite-lived intangible assets for impairment whenever events or changes in circumstances indicate that their carrying value may not be recoverable. Recoverability is measured by a comparison of their carrying amount to the estimated undiscounted cash flows to be generated by those assets. Based on specific market factors and circumstances at the time of prospective impairment reviews and the continuing evaluation of development plans, economics and other factors, we may be required to write down the carrying value of our long-lived and finite-lived intangible assets. For the years ended December 31, 2024 and 2023, we recognized abandoned well costs of $0.5 million and $1.3 million, respectively, and no long-lived asset impairment expense.

We may be required to take a write-down of the carrying value of goodwill.

We conduct our annual goodwill impairment assessment during the fourth quarter of each year, or more frequently if an event or circumstance indicates that the carrying value of a reporting unit may exceed the fair value. When possible impairment is indicated, we value the implied goodwill to compare it with the carrying

amount of goodwill. If the carrying amount of goodwill exceeds its implied fair value, an impairment charge is recorded. We may use a combination of the income approach and the market approach to determine the fair value of a reporting unit. The fair value of goodwill may be based on estimates and assumptions applied by us such as revenue growth rates, gross margins, weighted average costs of capital, market multiples, and future market conditions and is affected by numerous factors, including the general economic environment and levels of exploration and production activity of oil and gas companies, our financial performance and trends, and our strategies and business plans, among others. As a result of this annual impairment assessment, we may be required to write down the carrying value of goodwill.

Deficiencies in our internal control over financial reporting could prevent us from accurately and timely reporting our financial results.

We may identify deficiencies in our internal control over financial reporting in the future, including significant deficiencies and material weaknesses. A significant deficiency is a deficiency or a combination of deficiencies in internal control over financial reporting that is less severe than a material weakness, yet important enough to merit attention by those responsible for oversight of a company’s financial reporting. A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting such that there is a reasonable possibility that a material misstatement of a company’s annual or interim financial statements will not be prevented or detected on a timely basis. A deficiency in internal control exists when the design or operation of a control does not allow management or employees, in the normal course of performing their assigned functions, to prevent or detect misstatements on a timely basis.

Failure to identify deficiencies in our internal control over financial reporting in a timely manner or to remediate any deficiencies, or the identification of material weaknesses or significant deficiencies in the future could prevent us from accurately and timely reporting our financial results. Although our management is required to assess the effectiveness of our internal control over financial reporting annually, we are not required to have, or to engage our independent audit firm to perform, an audit of the effectiveness of our internal control over financial reporting for as long as we are an “emerging growth company” pursuant to the provisions of the JOBS Act. An independent assessment of the effectiveness of our internal control over financial reporting could detect problems that our management’s assessment might not. Undetected material weaknesses in our internal control over financial reporting could require us to incur the expense of remediation or lead to restatements of our financial statements, which could, in turn, cause stockholders to lose confidence in our financial reporting.

Our debt instruments have restrictive covenants that could limit our financial flexibility.

Our Credit Facility and the indenture that governs our Notes (as described under Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Debt Agreements) contain financial and other restrictive covenants that limit our ability to engage in activities that may be in our long-term best interests. Our ability to borrow under our Credit Facility is subject to compliance with certain financial covenants, including leverage and interest coverage ratios. Our Credit Facility and the indenture that governs our Notes include other restrictions that, among other things, limit our ability to:

Our business plan and our compliance with these covenants are based on a number of assumptions, including our customers’ planned development and production activity remaining consistent with their communications with us, relatively predictable costs for our capital improvements, a materially consistent legal and regulatory environment, and increased demand for recycled water along with margin improvements. The significant deterioration of oil and gas production or our customers’ development activity from current levels, higher capital expenditures or reduced recycling and higher operating costs could lead to lower revenues, cash flows and earnings, which in turn could lead to a default under certain financial covenants contained in the Credit Facility. Our failure to comply with these covenants could result in an event of default that, if not cured or waived, could result in the acceleration of all of our debts. We may not have sufficient working capital to satisfy our debt obligations in the event of an acceleration of all or a significant portion of our outstanding indebtedness. Any of these events could have a material adverse effect on our business, financial condition and results of operations. See Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Debt Agreements.

Our leverage may limit our ability to borrow additional funds, comply with the terms of our indebtedness, compete in our industry or capitalize on business opportunities.

Our leverage may adversely affect our ability to fund future working capital, capital expenditures and other general corporate requirements, future acquisitions, construction or development activities, or to otherwise fully realize the value of our assets and opportunities because of the need to dedicate a substantial portion of our cash flow from operations to payments on our indebtedness or to comply with any restrictive terms of our indebtedness. Our leverage may also make us less competitive. Other companies with which we compete may have greater liquidity, more unencumbered assets, less indebtedness, greater access to credit and other financial resources, lower cost structures, more effective risk management policies and procedures, greater ability to incur losses, longer-standing relationships with customers, or greater potential for profitability than we do.

Constructing and maintaining water infrastructure used in the oil and gas industry requires significant capital. We may require additional capital in the future to develop and construct water handling, sourcing, transfer and other related infrastructure to execute our growth strategy. For the years ended December 31, 2024 and 2023, our cash capital expenditures were $100.0 million and $169.7 million, respectively. Historically, we have financed these investments through cash flows from operations, external borrowings and equity capital contributions. These sources of capital may not be available to us in the future. The inability to obtain additional financing to operate our business or capitalize on business opportunities, whether because of the restrictions set forth above or otherwise, could have a material adverse effect on our business, financial condition and results of operations.

Increases in interest rates could adversely impact the price of our shares, our ability to issue equity or incur debt for acquisitions or other purposes.

Interest rates rose in recent years as a result of government actions taken in response to the data related to labor market and economic growth, government debt levels and outlook for inflation. Although the Federal Reserve lowered the target federal funds interest rate in recent months, it remains elevated relative to historical levels. In a higher interest rate environment, interest rates on borrowings, credit facilities and debt offerings could remain elevated, causing our financing costs to increase relative to existing costs. Changes in interest rates, either positive or negative, may also affect the yield requirements of investors who invest in our shares, and the higher interest rate environment could have an adverse impact on the price of our shares, or our ability to issue equity or incur debt for acquisitions or other purposes.

A terrorist attack, armed conflict or unrest could harm our business.

The occurrence or threat of terrorist attacks in the U.S. or any of the major energy producing regions of the world or elsewhere, anti-terrorist efforts and other armed conflicts involving the U.S. or other countries, including continued hostilities in the Middle East, may adversely affect the U.S. and global economies and could have a material impact on both availability and price of oil and natural gas, which could prevent us from meeting our financial and other obligations. Additionally, destructive forms of protest and opposition by extremists and other disruptions, including acts of sabotage or eco-terrorism, against oil and natural gas development and production activities could potentially result in personal injury to persons, damages to property, natural resources or the environment, or lead to extended interruptions of our or our customers’ operations. If any of these events occur, the resulting political instability and societal disruption could reduce overall demand for oil and gas, potentially putting downward pressure on demand for our services and causing a reduction in our revenues. Oil and gas related facilities could be direct targets of terrorist attacks, and our operations could be adversely impacted if infrastructure integral to our or our customers’ operations is destroyed or damaged. Expenses related to security and costs for insurance may increase as a result of these threats, and some insurance coverage may become more difficult to obtain, if available at all.

We are subject to cybersecurity risks which could adversely affect our business.

The oil and gas industry has become increasingly dependent on digital technologies to conduct certain processing activities. We depend on digital technologies to perform many of our services and to process and record financial and operating data. Our technologies, systems and networks, and those of our vendors, suppliers and other business partners, are subject to growing risks associated with cybersecurity threats and technical disruptions, which include but are not limited to human error, power outages, computer and telecommunication failures, natural disasters, fraud or malice, social engineering attacks, viruses or malware, and other cyberattacks, such as denial-of-service or ransomware attacks. Such risks could result in the unauthorized release, gathering, monitoring, misuse, loss or destruction of proprietary and other information, or other disruption of business operations. The U.S. government has issued public warnings that energy assets might be the subject of targeted cybersecurity attacks, including by sophisticated nation state actors. Due to evolving cybersecurity threats, it has and will continue to be difficult to prevent, detect, mitigate and remediate cybersecurity incidents. While we have a cybersecurity program designed to assess, identify and manage risks from cybersecurity threats, there is no guarantee such efforts will be successful in preventing or detecting such threats. As cybersecurity threats 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. A cybersecurity incident could result in liability under applicable law, regulatory penalties, damage to our reputation or loss of confidence in us, all of which could have a material and adverse effect on our business, financial condition or results of operations. Moreover, our insurance coverage for cybersecurity incidents may not be sufficient to cover all the losses we may experience as a result of such cybersecurity incident.

Risks Related to Our Legal and Regulatory Environment

Restrictions on the ability to procure water or changes in water sourcing requirements could decrease the demand for our services.

Our business includes water transfer for use in our customers’ oil and gas E&P activities. Our access to the water we supply may be limited due to reasons such as prolonged drought or our inability to acquire or maintain water sourcing permits or other rights. In addition, some state and local governmental authorities have begun to monitor or restrict the use of water subject to their jurisdiction for hydraulic fracturing to ensure adequate local water supply. For instance, some states require E&P companies to report certain information regarding the water they use for hydraulic fracturing and to monitor the quality of groundwater surrounding some wells stimulated by hydraulic fracturing. Any such decrease in the availability of water, or demand for water services, could adversely affect our business and results of operations.

In the future we may face increased obligations relating to the closing of our produced water handling facilities and may be required to provide an increased level of financial assurance to guarantee the appropriate closure activities occur for a produced water handling facility. 

Obtaining a permit to own or operate produced water handling facilities generally requires us to establish performance bonds, letters of credit or other forms of financial assurance to address clean-up and closure obligations. As we acquire additional produced water handling facilities or construct additional produced water handling facilities, these obligations will increase. Additionally, in the future, regulatory agencies may require us to increase the amount of our closure bonds at existing produced water handling facilities. Asset retirement obligations related to future closure obligations of our produced water handling facilities totaled $22.1 million as of December 31, 2024. Moreover, actual costs could exceed our current expectations, as a result of, among other things, federal, state or local government regulatory action, increased costs charged by service providers that assist in closing produced water handling facilities and additional environmental remediation requirements. The obligation to satisfy increased regulatory requirements associated with our produced water handling facilities could result in an increase of our operating costs and have a material adverse effect on our business, financial position and results of operations.

Our sales of groundwater and our gathering, handling and recycling of produced water expose us to potential regulatory risks.

There are unique risks associated with recycling and/or handling produced water and the legal requirements related to handling produced water, or the disposal of produced water into a non-producing geologic formation by means of underground injection wells, are subject to change based on concerns of the public or governmental authorities. There remains substantial uncertainty regarding the disposal of produced water by means of underground injection wells, which could result in substantial additional liabilities or costs to us 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 received from our oil and natural gas producer customers, 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 restart of any facility after unplanned or planned outages. New or amended safety requirements and regulatory laws may give rise to additional operation and maintenance costs and capital expenditures. Additionally, aging equipment may require more capital expenditures to keep each of these produced water handling facilities operating efficiently or in compliance with applicable laws and regulations. This equipment is also likely to require periodic upgrading and improvement in order to maintain compliance. Accidents and other unforeseen problems have occurred in the past with our produced water handling, and 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 exceed our resources, including insurance coverage.

Unsatisfactory safety performance may negatively affect our customer relationships and, to the extent we fail to retain existing customers or attract new customers, adversely impact our revenues.

Our ability to retain existing customers and attract new business is dependent on many factors, including our ability to demonstrate that we can reliably and safely operate our business and stay current on constantly changing rules, regulations, training and laws. If one or more accidents were to occur at one of our operating sites, the affected customer might seek to terminate or cancel its use of our facilities or services, which could cause us to lose substantial revenues. A deterioration of our safety record could also negatively impact our ability to attract and retain other customers.

Fuel conservation measures could reduce demand for oil and natural gas which would, in turn, reduce the demand for our services.

Fuel conservation measures, alternative fuel requirements and increasing consumer demand for alternatives to oil and natural gas could reduce demand for oil and natural gas. The impact of the changing demand for oil and natural gas may have a material adverse effect on our business, financial condition, prospects, results of operations and cash flows. Additionally, the increased competitiveness of alternative energy sources (such as wind, solar, geothermal, tidal, fuel cells and biofuels) could reduce demand for hydrocarbons and therefore for our services, which would lead to a reduction in our revenues.

We are subject to environmental and occupational health and safety laws and regulations that may expose us to significant liabilities for penalties, damages or costs of remediation or compliance.

Our operations and the operations of our customers are subject to federal, state and local laws and regulations in the U.S. relating to protection of natural resources and the environment, health and safety aspects of our operations and waste management, including the disposal of waste and other materials. These laws and regulations may impose numerous obligations on our operations and the operations of our customers, including the acquisition of permits to take fresh water from surface and underground sources, construct pipelines or containment facilities, drill wells or conduct other regulated activities, the incurrence of capital expenditures to mitigate or prevent releases of materials from our facilities or from customer locations where we are providing services, the imposition of substantial liabilities for pollution resulting from our operations, and the application of specific health and safety criteria addressing worker protection. Any failure on our part or the part of our customers to comply with these laws and regulations could result in the impairment or cancellation of operations, assessment of sanctions, including administrative, civil and criminal penalties, injunctions, reputational damage, 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 of our activities in a particular area.

Our business activities present risks of incurring significant environmental regulatory compliance costs and liabilities, including costs and liabilities resulting from our handling of byproducts of the oil and natural gas production process, because of air emissions and produced water discharges related to our operations. Our business includes the operation of recycling facilities and oilfield waste disposal injection wells that pose risks of environmental liability, including leakage or accidental spills from the wells to surface or subsurface soils, surface water or groundwater. In addition, private parties, including the owners of properties upon which we perform services and facilities where our wastes are taken for recycling or disposal, also may have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property or natural resource damages. Some environmental laws and regulations may impose strict and/or joint and several liability, which means that in some situations we could be exposed to liability as a result of our conduct that was lawful at the time it occurred or the conduct of, or conditions (such as environmental contamination) caused by, prior operators or other third parties. Remedial costs and other damages arising as a result of environmental laws and costs associated with changes in environmental laws and regulations could be substantial and could have a material adverse effect on our liquidity, results of operations and financial condition.

Over time, laws and regulations protecting the environment generally have the tendency to become more stringent, potentially leading to material increases in costs for future environmental compliance and remediation. The adoption of any new laws or regulations, amendment of existing laws and regulations, changes in interpretation of legal requirements or increased enforcement could restrict, delay or cancel exploratory or developmental drilling for oil and gas and could limit well servicing opportunities. We may not be able to recover some or any of our costs of compliance with these laws and regulations from insurance.

Legislation or regulatory initiatives intended to address seismic activity could restrict our ability to recycle or handle produced water gathered from our E&P customers and, accordingly, could have a material adverse effect on our business.

Recent seismic events in the U.S. near underground disposal wells used for the disposal by injection of produced water resulting from oil and gas activities, including recent seismic events occurring in the Permian Basin near Midland, Texas, have led to concerns of the public or governmental authorities regarding disposal activities. In response to concerns regarding induced seismicity, regulators in some states have imposed, or are considering imposing, additional requirements in the permitting of produced water disposal wells to assess any relationship between seismicity and the use of such wells. Among other things, these rules require companies seeking permits for disposal wells to provide seismic activity data in permit applications, provide for more frequent monitoring and reporting for certain wells and allow the state to modify, suspend or terminate permits on grounds that a disposal well is likely to be, or determined to be, causing seismic activity. States have also issued, and may in the future issue, orders to temporarily shut down or to curtail the injection depth of existing wells in the vicinity of seismic events.

We currently operate in the states of New Mexico and Texas, where the NMOCD and TRC have recently addressed seismic activity in their respective states by curtailing injected volumes and/or suspending certain permits for disposal wells injecting into deep strata. See Items 1. and 2. Business and Properties – Regulation – Environmental and Occupational Safety and Health Matters – Water handling facilities and seismicity for recent changes in regulations.

We currently operate wells in the SRAs in Texas and New Mexico. Should the TRC or NMOCD take additional action in the existing SRAs or establish new SRAs near our operations, it could have a significant adverse effect on our business. Additionally, the adoption and implementation of any new laws, regulations or directives that restrict our ability to dispose of produced water gathered from our customers by limiting volumes, disposal rates, disposal well locations or otherwise, or requiring us to shut down disposal wells, could have a material adverse effect on our business, financial condition, and results of operations. See Part II, Item 7. Management’s Discussion and Analysis of Results of Operations – General Trends and Outlook – Seismicity for a discussion of the impact on our business.

Additional potential consequences of seismic activity are lawsuits alleging that disposal well operations have caused damage to neighboring properties or otherwise violated state and federal rules regulating waste disposal. These developments could result in additional regulation and restrictions on the use of injection wells. Increased regulation and attention given to induced seismicity could lead to greater opposition to oil and gas activities utilizing injection wells for waste disposal. The adoption and implementation of any new laws, regulations or directives that restrict our ability to recycle or handle produced water gathered from our customers by limiting volumes, disposal rates, disposal well locations or otherwise, or requiring us to shut down disposal wells, or our inability to serve our customers as required by our contracts, could result in asset impairment and could have a material adverse effect on our business, financial condition and results of operations.

Climate change legislation, laws and regulations restricting GHG emissions, promoting the development of alternative sources of energy, prohibiting, restricting, or delaying oil and gas development on public lands, or legal or other action taken by public or private entities related to climate change could force our customers to incur increased capital and operating costs and could have a material adverse effect on our financial condition, results of operations and cash flows, as well as our reputation.

As discussed above in Items 1. and 2. Business and Properties – Regulation – Environmental and Occupational Safety and Health Matters, international, federal, state and local governments have taken steps to reduce GHG emissions. Given the long-term trend toward increasing regulation, future federal GHG regulations of the oil and gas industry remain a possibility, and states in the US have taken measures to

reduce GHG emissions primarily through the development of GHG emission inventories and/or regional GHG cap-and-trade programs, as well as reporting obligations.

The adoption of legislation or regulatory programs or other government action to reduce emissions of GHGs or restrict, delay or prohibit oil and gas development on public lands could further require our customers and us to incur increased operating costs, such as costs to purchase and operate emissions control systems, to acquire emissions allowances or to comply with new regulatory or reporting requirements, or prevent us from conducting operations in certain areas. Any such legislation or regulatory programs could also increase the cost of consuming, and thereby reduce demand for, the oil and gas our customers produce. Additionally, political, financial and litigation risks may result in our customers restricting, delaying or canceling production activities or impairing the ability to continue to operate in an economic manner. Consequently, legislation and regulatory programs to reduce emissions of GHGs could have an adverse effect on our business, financial condition, results of operations and cash flows.

In addition, some scientists have concluded that increasing concentrations of GHGs in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts, floods, wildfires and other climatic events. If such climatic events were to occur more frequently or with greater intensity, our operations and our customers’ exploration and development activities could be adversely affected, as these events could cause a loss of production from temporary cessation of activity or damaged facilities and equipment. If any such events were to occur, they could result in increased costs to repair damaged facilities or maintain or resume operations, increased insurance costs and have an adverse effect on the demand for our services and our financial condition, results of operations and cash flows. For a more complete discussion of environmental laws and regulations intended to address climate change and their impact on our business and operations, see Items 1. and 2. Business and Properties ─ Regulation ─ Environmental and Occupational Safety and Health Matters.

For a discussion of the influence of environmental laws and regulations intended to address climate change on the investment community, see Risk Factor titled “There is uncertainty related to the future of the oil and natural gas industry broadly.”

A portion of our customers’ oil and gas leases are granted by the federal government. To the extent such leases are suspended or terminated, or we or our customers are unable to obtain permits or right-of-way grants required for operations on such leases, our operations could be materially affected.

A portion of our customers’ leases in New Mexico are granted by the federal government and administered by the BLM, a federal agency. Operations conducted by us and our customers on federal oil and gas leases must comply with numerous additional statutory and regulatory restrictions, including permitting obligations. In addition, the U.S. Department of the Interior (via various of its agencies, including the BLM and the Office of Natural Resources Revenue) has certain authority over our activities on federal and tribal lands. These leases contain relatively standardized terms requiring compliance with detailed regulations. Under certain circumstances, the BLM may require operations on federal leases to be suspended or terminated or may deny permits or right-of-way grants required for operations on such leases. Any such suspension or termination, or inability to obtain required permits or right-of-way grants, could materially and adversely affect our interests.

The Biden Administration, for example, took several actions to curtail oil and gas activities on federal lands, including, for example, taking a pause on new oil and natural gas leases on public lands or in offshore waters. Although the Department of the Interior has resumed processing oil and gas drilling permits, and the incoming Trump administration has begun taking steps to promote domestic oil and natural gas production, we cannot guarantee that further action will not be taken that could curtail or limit oil and gas development on federal land.

Further, environmental incidents such as the Macondo well incident could result in similar drilling moratoria, and could result in increased federal, state, and international regulation of our and our customers’ operations that could negatively impact our earnings, prospects and the availability and cost of insurance coverage. Any additional regulation of the exploration and production industry as a whole could result in fewer companies being financially qualified to operate offshore or onshore in the U.S. or in non-U.S. jurisdictions, resulting in higher operating costs for our customers and reduced demand for our products and services.

Federal, state and local legislation and regulatory initiatives relating to hydraulic fracturing, as well as governmental reviews of such activities, could result in increased costs and additional operating restrictions, delays or cancellations in the drilling and completion of oil and gas wells that may reduce demand for our services and could have a material adverse effect on our liquidity, results of operations and financial condition.

We do not conduct hydraulic fracturing operations, but many of our customers’ oil and natural gas production operations require hydraulic fracturing as part of the well completion process. Although certain aspects of hydraulic fracturing operations are subject to current guidance or regulation, Congress has not adopted legislation to provide for federal regulation of hydraulic fracturing, and we cannot predict if such legislation will be enacted, when, or the scope of any such legislation at this time.

In addition, a number of states and local regulatory authorities and federal politicians are considering or have implemented more stringent regulatory requirements applicable to hydraulic fracturing, including bans/moratoria on drilling that effectively prohibit further production of oil and gas through the use of hydraulic fracturing or similar operations.

The adoption of new laws or regulations imposing reporting or operational obligations on, or otherwise limiting or prohibiting, the hydraulic fracturing process could make it more difficult for our customers to complete oil and gas wells in unconventional plays. In addition, if hydraulic fracturing becomes regulated at the federal level as a result of federal legislation or regulatory initiatives by the EPA, hydraulic fracturing activities could become subject to additional permitting requirements, and also to attendant permitting delays and potential increases in cost, which could adversely affect the demand for our services and results of operations.

Restrictions on drilling and related activities intended to protect certain species of wildlife or their habitat may adversely affect our customers’ ability to conduct drilling and related activities in some of the areas where we operate.

Various federal and state statutes prohibit certain actions that harm endangered or threatened species and their habitats, migratory birds, wetlands and natural resources. These statutes include the ESA, the MBTA, the BGEPA, the CWA, CERCLA and the OPA. The U.S. Fish and Wildlife Service may designate critical habitat and suitable habitat areas that it believes are necessary for survival of threatened or endangered species. A critical habitat or suitable habitat designation could result in further material restrictions to federal land use and private land use and could delay or prohibit our customers’ land access or oil and gas development. If adverse impact to species or damages to wetlands, habitat or natural resources occur or may occur as result of our or our customers’ activities, government entities or, at times, private parties may act to prevent such activities or seek damages for harm to species, habitat or natural resources resulting from our activities or our customers’ drilling, construction or releases of oil, wastes, hazardous substances or other regulated materials, which could reduce the demand for our services.

For example, the dunes sagebrush lizard, which is found in areas where we operate, was listed as endangered under the ESA in 2024, and the lesser prairie-chicken, which can also be found in areas where we operate, was listed under the ESA in 2023.

To the extent species are listed under the ESA or similar state laws, or previously unprotected species are designated as threatened or endangered in areas where our assets and operations are located, operations in

those areas could incur increased costs arising from species protection measures and face delays or limitations with respect to production activities thereon.

Delays or restrictions in obtaining or renewing permits by us for our operations or by our customers for their operations could impair our business.

Our operations and the operations of our oil and gas producing customers typically require that we and our customers obtain and maintain a number of permits from one or more governmental agencies in order to perform drilling and completion activities, secure water rights, construct impoundments tanks, and construct and operate pipelines, produced water injection wells, handling facilities and recycling facilities. Many of these permits require a significant amount of monitoring, record keeping and reporting in order to demonstrate compliance with the underlying permit. Noncompliance or incomplete documentation of our compliance status may result in the imposition of fines, penalties and injunctive relief. Such permits are typically issued by state agencies, but federal and local governmental permits may also be required. As of December 31, 2024, we had permits for (i) approximately 195 miles of pipelines, (ii) 23 produced water handling facilities and (iii) 4 recycling facilities that, in each case, have not been constructed. We may not be able to achieve commercial operations on any particular permitted site. A decision by a governmental agency to deny or delay the renewal of any of these permits or other approval, or to revoke or substantially modify an existing permit or other approval, could adversely affect our ability to initiate or complete construction of any of these pipelines or facilities and we can provide no assurance that we will complete these projects on schedule, or at all. Additionally, these permits were issued pursuant to existing laws and regulations that are subject to change, which could result in the imposition of more stringent requirements and impair our ability to initiate or complete the construction of these pipelines and facilities.

In addition, some of our customers’ drilling and completion activities in the U.S. may take place on federal land or Native American lands, requiring leases and other approvals from the federal government or Native American tribes to conduct such drilling and completion activities. Under certain circumstances, federal agencies may cancel proposed leases for federal lands and refuse to grant or delay required approvals. Therefore, our customers’ operations in certain areas of the U.S. may be interrupted or suspended for varying lengths of time, causing a loss of revenue to us and adversely affecting our results of operations in support of those customers.

Risks Related to the Ownership of Our Class A Common Stock

We are a holding company. Our sole material asset is our equity interest in Solaris LLC and we are accordingly dependent upon distributions from Solaris LLC to pay taxes, make payments under the Tax Receivable Agreement and cover our corporate and other overhead expenses.

We are a holding company and have no material assets other than our equity interest in Solaris LLC. We have no independent means of generating revenue. To the extent Solaris LLC has available cash, we intend to cause Solaris LLC to make (i) generally pro rata advance distributions to Aris Inc. in an amount at least sufficient to allow us to pay our taxes, (ii) non-pro rata advance distributions to allow us to make payments under the Tax Receivable Agreement we have entered into with the TRA Holders and any subsequent tax receivable agreements that we may enter into in connection with future acquisitions and (iii) non-pro rata payments to us to reimburse us for our corporate and other overhead expenses. To the extent that we need funds and Solaris LLC or its subsidiaries are restricted from making such distributions or payments under applicable law or regulation or under the terms of the Credit Facility, the indenture governing the Notes or any future financing arrangements, or are otherwise unable to provide such funds, our liquidity and financial condition could be materially adversely affected.

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Moreover, because we have no independent means of generating revenue, our ability to make payments under the Tax Receivable Agreement is dependent on the ability of Solaris LLC to make distributions to us in an amount sufficient to cover our obligations under the Tax Receivable Agreement. This ability, in turn, may depend on the ability of Solaris LLC’s subsidiaries to make distributions to it. The ability of Solaris LLC, its

subsidiaries and other entities in which it directly or indirectly holds an equity interest to make such distributions will be subject to, among other things, (i) the applicable provisions of Delaware law (or other applicable jurisdiction) that may limit the amount of funds available for distribution and (ii) restrictions in relevant debt instruments issued by Solaris LLC or its subsidiaries and/other entities in which it directly or indirectly holds an equity interest. To the extent that we are unable to make payments under the Tax Receivable Agreement for any reason, such payments will be deferred and will accrue interest until paid.

For as long as we are an emerging growth company, we will not be required to comply with certain reporting requirements, including those relating to accounting standards and disclosure about our executive compensation, that apply to other public companies.

We are classified as an “emerging growth company” under the JOBS Act. For as long as we are an emerging growth company, we will not be required to, among other things: (i) provide an auditor’s attestation report on management’s assessment of the effectiveness of our system of internal control over financial reporting pursuant to Section 404(b) of the Sarbanes-Oxley Act; (ii) comply with any new requirements if adopted by the PCAOB requiring mandatory audit firm rotation or a supplement to the auditor’s report in which the auditor would be required to provide additional information about the audit and the financial statements of the issuer; (iii) provide certain disclosures regarding executive compensation required of larger public companies; or (iv) hold nonbinding advisory votes on executive compensation. We will remain an emerging growth company up until the last day of the fiscal year following the fifth anniversary of our IPO, or such earlier time that we have more than $1.235 billion of revenues in a fiscal year, have more than $700.0 million in market value of our common stock held by non-affiliates (and have been a public company for at least 12 months), or issue more than $1.0 billion of non-convertible debt over a three-year period.

To the extent that we rely on any of the exemptions available to emerging growth companies, there will be less information available about our executive compensation and internal control over financial reporting than issuers that are not emerging growth companies. If some investors find our Class A common stock to be less attractive as a result, there may be a less active trading market for our Class A common stock and our stock price may be more volatile.

In addition, once we are no longer an emerging growth company, compliance with rules and regulations that do not currently apply to us as an emerging growth company may increase our compliance costs, may make some activities more difficult or time-consuming, and may otherwise strain our systems and resources and distract management.

Our principal stockholders collectively hold a substantial portion of the voting power of our common stock.

Holders of Class A common stock and Class B common stock will vote together as a single class on all matters presented to our stockholders for their vote or approval, except as otherwise required by applicable law or our amended and restated certificate of incorporation. As of December 31, 2024, the Legacy Owners of Solaris LLC own 100% of our Class B common stock equating to a 47% economic and voting power interest in Solaris LLC of which, (i) ConocoPhillips owns approximately 47% of our Class B common stock and an approximate 22% economic interest and voting power and (ii) Yorktown Energy Partners XI, L.P. (“Yorktown”) owns approximately 37% of our Class B common stock and an approximate 18% economic interest and voting power.

Although the owners of our Class B common stock are entitled to act separately in their own respective interests with respect to their ownership in us, if they choose to act in concert, they will together have the ability to strongly influence all matters requiring stockholder approval, including mergers and other material transactions, as well as the composition of our Board or a change in control of our company that could deprive our stockholders of an opportunity to receive a premium for their Class A common stock as part of a sale of our company. The existence of significant stockholders may also have the effect of deterring hostile

takeovers, delaying or preventing changes in control or changes in management, or limiting the ability of our other stockholders to approve transactions that they may deem to be in the best interests of our company.

In addition, we entered into a director nomination agreement with affiliates of ConocoPhillips and Yorktown in connection with the closing of the IPO. The director nomination agreement provided such holders with the right, but not the obligation, to nominate directors for election to our Board as follows: (i) ConocoPhillips has the right to nominate one nominee for election to our Board for so long as ConocoPhillips and its affiliates beneficially own at least 12.5% of the voting power of our common stock and such nominee will be a Class III director and (ii) Yorktown has the right to nominate one nominee for election to our Board for so long as Yorktown and its affiliates beneficially own at least 12.5% of the voting power of our common stock and such nominee will be a Class I director. In addition, each of ConocoPhillips and Yorktown are entitled to designate the successor for its respective Board designee whose Board service terminates prior to the end of the director’s term. The rights of each of ConocoPhillips and Yorktown will terminate on the date when such holder ceases to beneficially own at least 12.5% of the voting power of our common stock (or earlier upon written notice by such holder agreeing to terminate its rights under the agreement).

So long as the owners of our Class B common stock continue to control a significant amount of our common stock, each will continue to be able to strongly influence all matters requiring stockholder approval, regardless of whether or not other stockholders believe that a potential transaction is in their own best interests. In any of these matters, the interests of the owners of our Class B common stock may differ or conflict with the interests of our other stockholders. In addition, certain of the owners of our Class B common stock and their respective affiliates may, from time to time, acquire interests in businesses that directly or indirectly compete with our business, as well as businesses that are significant existing or potential customers. Such owners of our Class B common stock and their respective affiliates may acquire or seek to acquire assets that we seek to acquire and, as a result, those acquisition opportunities may not be available to us or may be more expensive for us to pursue. Moreover, this concentration of stock ownership may also adversely affect the trading price of our Class A common stock to the extent investors perceive a disadvantage in owning stock of a company with significant stockholders.

Certain of our directors have significant duties with, and spend significant time serving, 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 hold positions of responsibility with other entities (including affiliated entities) that are in the oil and natural gas industry. These directors 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, they 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 favor.

Certain Designated Parties are not limited in their ability to compete with us, and the corporate opportunity provisions in our amended and restated certificate of incorporation could enable such Designated Parties and their respective affiliates to benefit from corporate opportunities that might otherwise be available to us.

Our governing documents provide that Yorktown and COG Operating LLC, a wholly-owned subsidiary of ConocoPhillips, and their respective interests in other entities and affiliates (collectively, the “Designated Parties”) are not restricted from owning assets or engaging in businesses that compete directly or indirectly with us.

In particular, subject to the limitations of applicable law, our amended and restated certificate of incorporation, among other things:

The Designated Parties 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 opportunity. 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. 

Our amended and restated certificate of incorporation and amended and restated bylaws, as well as Delaware law, contain provisions that could discourage acquisition bids or merger proposals, which may adversely affect the market price of our Class A common stock and could deprive our investors of the opportunity to receive a premium for their shares.

Our amended and restated certificate of incorporation authorizes our Board to issue preferred stock without stockholder 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 price or prices and liquidation preferences of such series. If our Board elects to issue preferred stock, it could be more difficult for a third party to acquire us. In addition, some provisions of our amended and restated certificate of incorporation and amended and restated bylaws 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 stockholders. These provisions include:

In addition, we are a Delaware corporation and governed by the DGCL. In general, Section 203 of the DGCL, an anti-takeover law, prohibits a publicly held Delaware corporation from engaging in a business combination, such as a merger, with a person or group owning 15% or more of the corporation’s voting stock, which person or group is considered an interested stockholder under the DGCL, for a period of three years following the date the person became an interested stockholder, unless (with certain exceptions) the business combination or the transaction in which the person became an interested stockholder is approved in a prescribed manner. We elected in our certificate of incorporation not to be subject to Section 203. However, our certificate of incorporation contains provisions that have the same effect as Section 203, except that they provide that the Designated Parties, their affiliates, and their respective successors (other than our company), as well as their direct and indirect transferees, are not deemed to be “interested stockholders,” regardless of the percentage of our voting stock owned by them, and accordingly are not subject to such restrictions. In addition, certain change of control events have the effect of accelerating the payment due under the Tax Receivable Agreement, which could be substantial and accordingly serve as a disincentive to a potential acquirer of our company. See – In certain cases, payments under the Tax Receivable Agreement may be accelerated and/or significantly exceed the actual benefits, if any, we realize in respect of the tax attributes subject to the Tax Receivable Agreement.

Our amended and restated certificate of incorporation 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 stockholders, and the federal district courts as the exclusive forum for Securities Act claims, which could limit our stockholders’ ability to obtain what such stockholders believe to be a favorable judicial forum for disputes with us or our directors, officers, employees or agents.

Our amended and restated certificate of incorporation provides that, unless we select or consent in writing to the selection of an alternative forum, all complaints asserting any internal corporate claims (defined as claims, including claims in the right of our Company: (i) that are based upon a violation of a duty by a current or former director, officer, employee, or stockholder in such capacity; or (ii) as to which the DGCL confers jurisdiction upon the Court of Chancery), to the fullest extent permitted by law, and subject to applicable jurisdictional requirements, shall be the Court of Chancery of the State of Delaware (or, if the Court of Chancery does not have, or declines to accept, subject matter jurisdiction, another state court or a federal court located within the State of Delaware). Further, unless we select or consent to the selection of an alternative forum, the federal district courts of the United States shall be the exclusive forum for the resolution of any complaint asserting a cause of action arising under the Securities Act. Our choice of forum provision does not apply to suits brought to enforce any liability or duty created by the Exchange Act and investors cannot waive compliance with the federal securities laws and the rules and regulations thereunder. Any person or entity purchasing or otherwise acquiring any interest in shares of our capital stock will be deemed to have notice of, and consented to, the provisions of our amended and restated certificate of incorporation described in the preceding sentence. This choice of forum provision may limit a stockholder’s ability to bring a claim in a judicial forum that it finds favorable for disputes with us or our directors, officers, employees or agents, which may discourage such lawsuits against us and such persons. Alternatively, if a court were to find these provisions of our amended and restated certificate of incorporation 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 business, financial condition or results of operations.

We cannot assure that we will pay any future dividends on our Class A common stock. Our indebtedness could limit our ability to pay future dividends on our Class A common stock.

Any payment of any future dividends will be at the discretion of our Board, which comprises a majority of independent directors. We have not adopted and do not expect to adopt a written dividend policy. Although our Board declared quarterly dividends on our Class A common stock for each quarter of 2023 and 2024, our Board may determine not to declare any cash dividends in the future. Such decision will depend on, among other things, our financial condition, results of operations, projections, liquidity, earnings, legal requirements, and restrictions in our debt. In addition, our ability to pay dividends depends on our receipt of distributions from our operating subsidiaries, which may further restrict our ability to pay dividends as a result of the laws of their jurisdiction of organization, agreements of our subsidiaries or covenants under any indebtedness we or our subsidiaries incur, including the Credit Agreement (as defined in Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Debt Agreements) and the indenture that governs our Notes. For more information about these restrictions, see Part II, Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters and Issuer Purchases of Equity Securities – Our Dividend and Distribution Policy.

Future sales of our Class A common stock in the public market, or the perception that such sales may occur, could reduce our stock price, and any additional capital raised by us through the sale of equity or convertible securities may dilute ownership in us.

We may sell additional shares of our Class A common stock in future offerings. In addition, subject to certain limitations and exceptions, the Legacy Owners of Solaris LLC units may redeem their Solaris LLC units (together with a corresponding number of shares of Class B common stock) for shares of Class A common stock (on a one-for-one basis, subject to conversion rate adjustments for stock splits, stock dividends and reclassification and other similar transactions) and then sell those shares of Class A common stock. As of December 31, 2024 we had 30,857,526 outstanding shares of Class A common stock and 27,493,565 outstanding shares of Class B common stock. Shares of Class B common stock represented approximately 47% of our total outstanding common stock. These shares may be sold into the market in the future. Certain of the owners of our Class B shares are party to a registration rights agreement with us that requires us to effect the registration of their shares and assist with sales.

We have also filed a registration statement with the SEC on Form S-8 providing for the registration of 11,100,000 shares of our Class A common stock issued or reserved for issuance under our 2021 Equity Incentive Plan. Subject to the satisfaction of vesting conditions and the requirements of Rule 144, shares registered under the registration statement on Form S-8 may be made available for resale immediately in the public market without restriction.

We cannot predict the size of future issuances of our Class A common stock or securities convertible into Class A common stock or the effect, if any, that future issuances and sales of shares of our Class A common stock will have on the market price of our Class A common stock. Any such issuance could result in substantial dilution to our existing stockholders. Accordingly, sales of substantial amounts of our Class A common stock (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 common stock. This impact could be increased to the extent there is a less active trading market for our shares.

Aris Inc. will be required to make payments under the Tax Receivable Agreement for certain tax benefits that it may claim, and the amounts of such payments could be significant.

In connection with the closing of the IPO, Aris Inc. entered into a Tax Receivable Agreement with the TRA Holders. This agreement generally provides for the payment by Aris Inc. to each TRA Holder of 85% of the net cash savings, if any, in U.S. federal, state and local income tax and franchise tax that Aris Inc. actually realizes (computed using simplifying assumptions to address the impact of state and local taxes) or is deemed to realize in certain circumstances in periods after the IPO as a result of certain increases in tax

basis and deemed interest deductions arising from these payments. Aris Inc. will retain the remaining 15% of these cash savings.

The term of the Tax Receivable Agreement commenced on October 26, 2021 and will continue until all tax benefits that are subject to the Tax Receivable Agreement have been utilized or expired, unless we exercise our right to terminate the Tax Receivable Agreement (or the Tax Receivable Agreement is terminated due to other circumstances, including our breach of a material obligation thereunder or certain mergers, asset sales, other forms of business combination or other changes of control), and we make the termination payment specified in the Tax Receivable Agreement.

The payment obligations under the Tax Receivable Agreement are Aris Inc.’s obligations and not obligations of Solaris LLC. For the year ended December 31, 2024, we made no payments under the Tax Receivable Agreement. However, we expect that the payments we will be required to make under the Tax Receivable Agreement in the future will be substantial over the life of the agreement. We could also be required to make a lump-sum payment as discussed in the following risk factor. Estimating the amount and timing of payments that may become due under the Tax Receivable Agreement is by its nature imprecise. For purposes of the Tax Receivable Agreement, cash savings in tax generally are calculated by comparing our actual tax liability (determined by using the actual applicable U.S. federal income tax rate and an assumed combined state and local income and franchise tax rate) to the amount we would have been required to pay had we not been able to utilize any of the tax benefits subject to the Tax Receivable Agreement. The actual increase in tax basis that may result in cash tax savings to Aris Inc. under the Tax Receivable Agreement, as well as the amount and timing of any payments under the Tax Receivable Agreement, will vary depending upon a number of factors, including the timing of any acquisition or redemption of Solaris LLC units, the price of our Class A common stock at the time of each acquisition or redemption, the extent to which such acquisition or redemption is a taxable transaction, the amount and timing of the taxable income we generate in the future, the U.S. federal income tax rates then applicable, and the portion of our payments under the Tax Receivable Agreement that give rise to depreciable or amortizable tax basis.

The payments under the Tax Receivable Agreement will not be conditioned upon a holder of rights under the Tax Receivable Agreement having a continued ownership interest in us. See Items 1. and 2. – Business and Properties – Organizational Structure and Corporate Information – Tax Receivable Agreement.

In certain cases, payments under the Tax Receivable Agreement may be accelerated and/or significantly exceed the actual benefits, if any, we realize in respect of the tax attributes subject to the Tax Receivable Agreement.

If we experience a change of control (as defined under the Tax Receivable Agreement, which includes certain mergers, asset sales and other forms of business combinations and change of control events) or the Tax Receivable Agreement terminates early (at our election or as a result of our breach), we could be required to make an immediate lump-sum payment (or “early termination payment”). This payment would equal the present value of hypothetical future payments that could be required to be paid under the Tax Receivable Agreement (determined by applying a discount rate of one-year Term SOFR plus the related Benchmark Replacement Adjustment, as defined under the Tax Receivable Agreement, plus 200 basis points). The calculation of hypothetical future payments will be based upon certain assumptions and deemed events set forth in the Tax Receivable Agreement, including that (i) we have sufficient taxable income to fully utilize the tax benefits covered by the Tax Receivable Agreement (including having sufficient taxable income to utilize any accumulated net operating loss carryforwards in the manner described in the Tax Receivable Agreement) and (ii) any Solaris LLC units (other than those held by Aris Inc.) outstanding on the termination date are deemed to be redeemed on the termination date. Any early termination payment may be made significantly in advance of, and may materially exceed, the actual realization, if any, of the future tax benefits to which the termination payment relates. We currently do not anticipate experiencing a change of control or an early termination of the TRA.

If we experience a change of control (as defined under the Tax Receivable Agreement) or the Tax Receivable Agreement otherwise terminates early, our obligations under the Tax Receivable Agreement could have a substantial negative impact on our liquidity and could have the effect of delaying, deferring or preventing certain mergers, asset sales or other forms of business combinations or changes of control.

See Items 1. and 2. – Business and Properties – Organizational Structure and Corporate Information – Tax Receivable Agreement.

We will not be reimbursed for any payments made under the Tax Receivable Agreement in the event that any tax benefits are subsequently disallowed.

Payments under the Tax Receivable Agreement will be based on the tax reporting positions that we will determine. The TRA Holders will not reimburse us for any payments previously made under the Tax Receivable Agreement if any tax benefits that have given rise to payments under the Tax Receivable Agreement are subsequently disallowed, except that excess payments made to any TRA Holder will be netted against payments that would otherwise be made to such TRA Holder, if any, after our determination of such excess. As a result, in such circumstances, we could make payments that are greater than our actual cash tax savings, if any, and may not be able to recoup those payments, which could adversely affect our liquidity.

We may be required to pay additional taxes because of the U.S. federal partnership audit rules and potentially also state and local tax rules.

Under the rules applicable to U.S. federal income tax audits of entities such as limited liability companies that are taxed as partnerships (which generally are effective for taxable years beginning after December 31, 2017), subject to certain exceptions, audit adjustments to items of income, gain, loss, deduction, or credit of an entity (and any holder’s share thereof) are determined, and taxes, interest, and penalties attributable thereto, are assessed and collected, at the entity level. It is possible that these rules could result in Solaris LLC (or any of its applicable subsidiaries or other entities in which Solaris LLC directly or indirectly invests that are treated as partnerships for U.S. federal income tax purposes) being required to pay additional taxes, interest and penalties as a result of an audit adjustment, and we, as a member of Solaris LLC (or such other entities), could be required to indirectly bear the economic burden of those taxes, interest, and penalties even though we may not otherwise have been required to pay additional corporate-level taxes as a result of the related audit adjustment. Audit adjustments for state or local tax purposes could similarly result in Solaris LLC (or any of its applicable subsidiaries or other entities in which Solaris LLC directly or indirectly invests) being required to pay or indirectly bear the economic burden of state or local taxes and associated interest, and penalties.

Under certain circumstances, Solaris LLC or an entity in which Solaris LLC directly or indirectly invests may be eligible to make an election to cause members of Solaris LLC (or such other entity) to take into account the amount of any tax understatement, including any interest and penalties, in accordance with such member’s share in Solaris LLC in the year under audit. We will decide whether or not to cause Solaris LLC to make this election; however, there are circumstances in which the election may not be available and, in the case of an entity in which Solaris LLC directly or indirectly invests, such decision may be outside of our control. If Solaris LLC or an entity in which Solaris LLC directly or indirectly invests does not make this election, the then-current members of Solaris LLC (including Aris Inc.) could economically bear the burden of the understatement.

If Solaris LLC were to become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes, Aris Inc. and Solaris LLC might be subject to potentially significant tax inefficiencies. 

We intend to operate such that Solaris LLC does not become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes. A “publicly traded partnership” is an entity like a limited

liability company treated as a partnership for tax purposes and the interests of which are traded on an established securities market or readily tradable on a secondary market or the substantial equivalent thereof. Under certain circumstances, exchanges of Solaris LLC units pursuant to certain transfers of Solaris LLC units could cause Solaris LLC to be treated like a publicly traded partnership. From time to time the U.S. Congress has considered legislation to change the tax treatment of partnerships and there can be no assurance that any such legislation will not be enacted or if enacted will not be adverse to us. If Solaris LLC were to become a publicly traded partnership taxable as a corporation for U.S. federal income tax purposes, significant tax inefficiencies might result for Aris Inc. and Solaris LLC, including as a result of Aris Inc.’s inability to file a consolidated U.S. federal income tax return with Solaris LLC.

Aris Inc. depends on distributions from Solaris LLC to pay any dividends, if declared, taxes and other expenses.

We are a holding company and our only business is to act as the managing member of Solaris LLC. We do not have any independent means of generating revenue. We anticipate that Solaris LLC will continue to be treated as a partnership for U.S. federal income tax purposes and, as such, generally will not be subject to any entity-level U.S. federal income tax, except as otherwise described above regarding partnership audit rules. Instead, taxable income will be allocated to the members of Solaris LLC. Accordingly, Aris Inc. will be required to pay income taxes on its allocable share of any net taxable income of Solaris LLC. Subject to funds being available for distribution, we intend to cause Solaris LLC to make tax distributions to Aris Inc. in an amount intended to enable Aris Inc. to pay certain applicable taxes. In addition, Solaris LLC will reimburse Aris Inc. for corporate and other overhead expenses. If the amount of tax distributions to be made exceeds the amount of funds available for distribution, Aris Inc. shall receive the full amount of its tax distribution before the other members receive any distribution and the balance, if any, of funds available for distribution shall be distributed to the other members. To the extent that Aris Inc. needs funds, and Solaris LLC is restricted from making such distributions under applicable laws or regulations, or is otherwise unable to provide such funds, it could materially and adversely affect Aris Inc.’s ability to pay dividends and taxes and other expenses and affect our liquidity and financial condition.

In certain circumstances, Solaris LLC will be required to make distributions to us and the other members of Solaris LLC, and the distributions that Solaris LLC will be required to make may be substantial.

Solaris LLC is expected to continue 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 will be allocated to members, including Aris Inc. Pursuant to the Solaris LLC operating agreement and subject to funds being available for distribution, Solaris LLC will make tax distributions to Aris Inc. to help Aris Inc. pay taxes on its allocable share of Solaris LLC’s net taxable income. If an advance is made to Aris Inc. to enable it to pay certain applicable taxes, Aris Inc. will use commercially reasonable efforts to cause Solaris LLC to make advance distributions to each of the members of Solaris LLC. The advance distributions, if any, made to the members of Solaris LLC generally will be pro rata based on each member’s ownership of Solaris LLC units, calculated based on the amount distributed to Aris Inc.

Funds used by Solaris LLC to satisfy its tax distribution obligations will not be available for reinvestment in our business. Moreover, the tax distributions Solaris LLC will be required to make may be substantial, and may significantly exceed (as a percentage of Solaris LLC’s income) the overall effective tax rate applicable to a similarly situated corporate taxpayer. In addition, because these payments will be calculated based on the anticipated tax liability of Aris Inc. at the time of each distribution, these payments may significantly exceed the actual tax liability for many of the members of Solaris LLC (including Aris Inc.).

We may receive distributions significantly in excess of our tax liabilities. We may choose to manage these excess distributions through a number of different approaches, including through the payment of dividends to our Class A common stockholders or by applying them to other corporate purposes.

We may issue preferred stock whose terms could adversely affect the voting power or value of our Class A common stock.

Our amended and restated certificate of incorporation authorizes us to issue, without the approval of our stockholders, one or more classes or series of preferred stock having such designations, preferences, limitations and relative rights, including preferences over our Class A common stock respecting dividends and distributions, as our Board may determine. The terms of one or more classes or series of preferred stock could adversely impact the voting power or value of our Class A common stock. For example, we might grant holders of preferred stock the right to elect some number of our directors in all events or on the happening of specified events or the right to veto specified transactions. Similarly, the repurchase or redemption rights or liquidation preferences we might assign to holders of preferred stock could affect the residual value of the Class A common stock.

Unanticipated changes in effective tax rates or adverse outcomes resulting from examination of our income or other tax returns could adversely affect our results of operations and financial condition.

We are subject to taxes by the U.S. federal, state, and local tax authorities. Our future effective tax rates could be subject to volatility or adversely affected by a number of factors, including:

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In addition, we may be subject to audits of our income, sales and other taxes by U.S. federal, state, and local, taxing authorities. Outcomes from these audits could have an adverse effect on our operating results and financial condition.

General Risk Factors

We may be adversely affected by uncertainty in the global financial markets and a worldwide economic downturn.

Our future results may be impacted by uncertainty caused by a worldwide economic downturn, continued volatility or deterioration in the debt and equity capital markets, changes in interest rates, continued high inflation, deflation or other adverse economic conditions that may negatively affect us or parties with whom we do business resulting in a reduction in our customers’ spending and their non-payment or inability to perform obligations owed to us, such as the failure of customers to honor their commitments. Additionally, credit market conditions may change, slowing our collection efforts as customers may experience increased difficulty in obtaining requisite financing, potentially leading to lost revenue and higher than normal accounts receivable. In the event of the financial distress or bankruptcy of a customer, we could lose all or a portion of such outstanding accounts receivable associated with that customer. Further, if a customer were to enter into bankruptcy, it could also result in the cancellation of all or a portion of our service contracts with such customer at significant expense to us.

The current global economic environment may adversely impact our ability to issue debt. Any economic uncertainty may cause institutional investors to respond to their borrowers by increasing interest rates, enacting tighter lending standards or refusing to refinance existing debt upon its maturity or on terms similar to the expiring debt. Due to the above-listed factors, we cannot be certain that additional funding will be available if needed and, to the extent required, on acceptable terms.

The widespread outbreak of an illness or any other communicable disease, or any other public health crisis, could adversely affect our business, results of operations and financial condition.

The COVID-19 pandemic caused, and any resurgence of the pandemic or other public health crisis could again cause, disruptions to our business and operational plans, which included, and may in the future include (i) shortages of qualified employees in a given area, (ii) unavailability of contractors and subcontractors, (iii) interruption of supplies from third parties upon which we rely, (iv) recommendations of, or restrictions imposed by, government and health authorities, including quarantines, (v) restrictions that we and our contractors and subcontractors impose, including facility shutdowns or access restrictions, to ensure the safety of employees, and (vi) reductions, delays or cancellations of planned operations by our customers. These disruptions could adversely affect our business, results of operations and financial condition.

Further, COVID-19 pandemic caused, and any resurgence of the pandemic or other public health crisis could again cause, economic volatility, including reduced global oil demand, disrupted global supply chains and significant volatility and disruption of financial and commodities markets.

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

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 Part I, Item 1A. Risk Factors – We are subject to cybersecurity risks which could adversely affect our business, which should be read in conjunction with the foregoing information.

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, other than the following.

Stateline Operating, LLC and Stateline Royalties, LP vs. Devon Energy Corporation, Stateline Water, LLC, Solaris Water Midstream, LLC and Aris Water Solutions, Inc., Cause No. 23-05-1085, 143rd District Court, Loving County, Texas

In May 2023, Stateline Operating, LLC and Stateline Royalties, LP (collectively “Stateline”) filed suit against Solaris Water Midstream, LLC and certain affiliates (collectively “Aris”) and Devon Energy Corporation and certain affiliates (collectively “Devon”) in Loving County, Texas, District Court. Stateline alleges that Aris and Devon’s (collectively “Defendants”) operations have harmed Stateline’s oil and gas leasehold interests through the injection of disposed saltwater. Stateline is seeking monetary damages, asserting claims for negligence, waste, trespass and nuisance. Following a ruling on dispositive motions, the trial court stayed the lawsuit while the Defendants pursue an interlocutory appeal. The trial date and all other deadlines have been vacated during this appellate process.

See Part II, Item 8. Financial Statements and Supplementary Data – Note 13. Commitments and Contingencies.

Item 4. Mine Safety Disclosures

Not applicable.

PART II

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

Common Stock

Our Class A common stock is listed on the NYSE under the symbol “ARIS.” As of February 24, 2025, 30,971,735 shares of Class A common stock were outstanding. As of February 24, 2025, 27,493,565 shares of Class B common stock were outstanding. There is no established public trading market for the Class B common stock.

Holders

As of February 24, 2025, the number of holders of record of our Class A common stock was 62. This number does not include the number of persons or entities whose shares are held in “street” name through brokerage firms or other nominee holders. As of February 24, 2025, the number of holders of record of our Class B common stock was 18.

Recent Sales of Unregistered Equity Securities

None.

Stock Repurchases

The following table summarizes repurchases of our common stock occurring in the fourth quarter of 2024.

Our Dividend and Distribution Policy

Our Board declared a dividend of $0.09 per share for the first quarter of 2024 and a dividend of $0.105 per share for each of the second, third and fourth quarters of 2024 on our Class A common stock. Our Board declared a dividend of $0.14 per share on our Class A common stock for the first quarter of 2025.

Depending on factors deemed relevant by our Board, our Board may elect to declare future cash dividends on our Class A common stock, subject to our compliance with applicable law, and depending on, among other things, our financial condition, results of operations, projections, liquidity, earnings, legal requirements and restrictions in our debt. The payment of any future dividends will be at the discretion of our Board. We have not adopted a written dividend policy. Our Board may determine not to declare any cash dividends in the future. See Part I, Item 1A. Risk Factors – We cannot assure that we will pay any future dividends on our Class A common stock. Our indebtedness could limit our ability to pay dividends on our Class A common stock. To the extent we pay any cash dividends on our Class A common stock, under the terms of our organizational documents, Solaris LLC will pay an equivalent cash distribution on the Solaris LLC units, and each share of Class A common stock and each Solaris LLC unit will receive the same cash amount.

Our ability to pay any dividends depends on our receipt of cash dividends from our operating subsidiaries, which may further restrict our ability to pay dividends as a result of the laws of their jurisdiction of organization, agreements of our subsidiaries or covenants under any existing and future outstanding indebtedness we or our subsidiaries incur. Our Credit Agreement generally permits Solaris LLC to pay distributions to us if (i) such distributions are funded using only Available Cash (as defined in the Credit Agreement) and (ii) no Default or Event of Default exists or would result therefrom.

The indenture that governs our Notes generally permits Solaris LLC to pay distributions to us if Solaris LLC’s Consolidated Leverage Ratio (as defined in such indenture) is less than or equal to 3.50 to 1.00 on a pro forma basis after giving effect to such distribution. In addition, as long as Solaris LLC’s Fixed Charge Coverage Ratio (as defined in the indenture) for the prior four fiscal quarters is not less than 2.00 to 1.00, the

indenture permits Solaris LLC to make distributions to us so long as such distribution, together with other distributions, does not exceed a basket amount determined by adding (i) 50% of Solaris LLC’s Consolidated Net Income (as defined in the indenture) taken as one period from January 1, 2022 to the most recently completed fiscal quarter, plus (ii) cash contributions to the equity of Solaris LLC and the fair market value of property acquired with Solaris LLC’s equity interests or contributed to its common equity capital, plus (iii) certain other others items, which basket amount is reduced by distributions made pursuant to the Consolidated Leverage Ratio test described in the immediately prior sentence. Solaris LLC also has the ability under the indenture to make distributions in an amount not in excess of $15.0 million since the date of the indenture. See Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Debt Agreements.

As the managing member of Solaris LLC, and subject to funds being legally available, we intend to cause Solaris LLC to make (i) generally pro rata advance distributions to us in an amount at least sufficient to allow us to pay taxes, and (ii) non-pro rata advance distributions to allow us to make payments under the Tax Receivable Agreement and any subsequent tax receivable agreements that we may enter into in connection with future acquisitions, and (iii) non-pro rata payments to us to reimburse us for corporate and other overhead expenses. If an advance is made to us to enable us to pay certain applicable taxes, we will use commercially reasonable efforts to cause Solaris LLC to make advance distributions to each of the members of Solaris LLC. The advance distributions, if any, made to the members of Solaris LLC generally will be pro rata based on each member’s ownership of Solaris LLC units, calculated based on the amount distributed to us. If the amount of tax distributions to be made exceeds the amount of funds available for distribution, we will receive a portion of our tax distribution (such portion determined based on the tax rate applicable to us rather than the assumed tax rate on which tax distributions are generally based) before the other members receive any distribution and the balance, if any, of funds available for tax distributions will be distributed to the other members. Holders of our Class B common stock will not be entitled to dividends distributed by us but will share in the distributions made by Solaris LLC on a pro rata basis.

Stock Performance Graph

The graph below compares the cumulative return to holders of our Class A common stock, the Russell 2000 and the Alerian MLP Index during the period beginning on October 22, 2021, and ending on December 31, 2024. The performance graph was prepared based on the following assumptions: (i) $100 was invested in our Class A common stock and in each of the indices at the beginning of the period, and (ii) dividends were reinvested on the relevant payment dates. The stock price performance included in this graph is historical and not necessarily indicative of future stock price performance.

Pursuant to Instruction 7 to Item 201(e) of Regulation S-K, the above stock performance graph and related information is being furnished and shall not be deemed “filed” for purposes of Section 18 of the Exchange Act, with the SEC, and as such shall not be deemed to be incorporated by reference into any of our filings under the Exchange Act or the Securities Act.

Item 6. [Reserved]

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

You should read the following discussion of our historical performance, financial condition and prospects in conjunction with our consolidated financial statements as of and for the three years ended December 31, 2024 included in Item 8. Financial Statements and Supplementary Data of this Annual Report. The information provided below supplements, but does not form part of, our historical financial statements. This discussion includes forward-looking statements that are based on the views and beliefs of our management, as well as assumptions and estimates made by our management. Actual results could differ materially from such forward-looking statements because of various risk factors, including those that may not be in the control of management. For further information on items that could impact our future operating performance or financial condition, see Part I, Item 1A. Risk Factors and the section entitled “Cautionary Statement

Regarding Forward-Looking Statements” elsewhere in this Annual Report. We assume no obligation to update any of these forward-looking statements, except as required by law.

We have applied provisions of the SEC’s FAST Act Modernization and Simplification of Regulation S-K, which limits the discussion to the two most recent fiscal years. This discussion and analysis deals with comparisons of material changes in the consolidated financial statements for the years ended December 31, 2024 and 2023. For the comparison of the years ended December 31, 2023 and 2022, see Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations in our Annual Report on Form 10-K for the year ended December 31, 2023 filed with the SEC on February 29, 2024.

Overview

For an overview of our business and our holding company structure, see Part I, Items 1. and 2. Business and Properties – Our Company.

Year-end Results

Significant financial and operating highlights for the year ended December 31, 2024 include:

For additional information regarding our non-GAAP financial measures, see Non-GAAP Financial Measures below.

Recent Developments

Crosstek Acquisition

In February 2025, we acquired intellectual property rights and assets from Crosstek Membrane Technology LLC to help us accelerate our entry into broader industrial markets, including industrial water and wastewater treatment. We paid the seller $2.0 million in cash and included sales-based contingent consideration with a cap of $1.0 million to be paid over a four-year contractual period. See Part II, Item 8. Financial Statements and Supplementary Data – Note 4. Acquisitions.

Surface Acreage Acquisition

In November 2024, we purchased approximately 45,000 surface acres and site improvements in New Mexico and Texas for total cash consideration of $46.1 million, inclusive of transaction costs, to secure potential disposal capacity for long-term growth. See Part II, Item 8. Financial Statements and Supplementary Data – Note 4. Acquisitions.

Beneficial Reuse Joint Industry Project

In July 2024, Coterra joined our beneficial reuse strategic agreement (the “Joint Industry Project” or “JIP”) with Chevron U.S.A. Inc., ConocoPhillips and Exxon Mobil Corporation (collectively with us, the “alliance members”) to develop and pilot technologies and processes to treat produced water for potential beneficial reuse opportunities. For more information regarding the JIP, see Part I, Items 1. and 2. Business Properties – Innovation in Recycling and Sustainable Water Management – Beneficial Reuse Joint Industry Project and Part II, Item 8. Financial Statements and Supplementary Data – Note 2. Summary of Significant Accounting Policies.

Mineral Extraction Agreement

In the second quarter of 2024, we signed a letter of intent with a development partner to construct an iodine extraction facility at one of our Permian Basin produced water management facilities. For more information, see Part I, Items 1. and 2. Business Properties – Innovation in Recycling and Sustainable Water Management – Mineral Extraction Agreement.

NAWI

In April 2024, we signed an agreement with the National Alliance for Water Innovation (“NAWI”) to further investigate treatment of produced water using one of the pilot technologies, working with alliance members and Texas A&M University, New Mexico State University, OLI Systems, Inc. and SLAC National Accelerator Laboratory. For more information, see Part I, Items 1. and 2. Business Properties – Innovation in Recycling and Sustainable Water Management – NAWI.

General Trends and Outlook

Market Dynamics

The ongoing Russia-Ukraine and Middle Eastern conflicts have had significant global economic implications and impacts on financial markets and the energy industry. The extent of these impacts will depend on the severity and duration of these conflicts and whether the conflicts spread to other countries or regions.

In addition, commodity prices have been and are continuing to be impacted by multiple factors such as supply disruptions and recessionary concerns and responses by the members of OPEC+ and other oil exporting nations to market conditions. During the year ended December 31, 2024, the average WTI crude oil spot price was $76.63 as compared with $77.58 for the year ended December 31, 2023.

We believe there are several industry trends that continue to provide meaningful support for our future growth. Our key customers’ capital allocation to the Permian Basin and New Mexico, in particular, remains consistent and significant, including on acreage where the water sourcing and production is dedicated to us. Permian Basin oil and associated water production growth continues to outpace production growth in other parts of the United States.

Many industry trends such as simultaneous multi-well operations and reuse applications of produced water, particularly in the areas of the Permian Basin where we operate, are improving efficiencies and returns and

provide us with significant opportunities for both our Produced Water Handling and Water Solutions businesses.

Cost Inflation

Since 2021, the U.S. has experienced increased wage and price inflation, as evidenced by increases in the CPI. Although the current rate of consumer inflation has eased, core inflation remains elevated above the Federal Reserve’s 2% target rate. The rate of inflation is expected to continue to be impacted by any further steps taken by the U.S. Federal Reserve Bank, such as adjustments to interest rates.

Our long-term, fee-based produced water handling contracts are generally subject to annual CPI-based adjustments. However, many of our contractual CPI-based adjustments are capped at a maximum annual increase and, therefore, our costs may increase more rapidly than the fees that we charge to customers pursuant to our contracts with them. If inflation is higher than our contractually allowed fee increases, we could experience negative impacts to our operating margins.

Seismicity

In New Mexico, we operate four wells located within the Hat Mesa SRA that are subject to the associated Seismic Response Protocol, and we have continued to partially curtail injection in one of those wells as of December 31, 2024. There has been no further seismic activity within the Hat Mesa SRA in 2023 or 2024.

In Texas, we owned one well within the Gardendale SRA, which well was plugged and abandoned during 2023.

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Due to the integrated nature of our pipeline network and our system-wide redundancy, we have been able to adapt to regulator responses to seismic activity, while continuing to provide service to our customers without material disruption in our operations. In addition, although we cannot anticipate with any certainty future regulatory actions and the effect such actions could have on our business, our compliance with state regulator seismic response actions to date has not resulted in any material volumetric, revenue or cash flow decreases.

How We Generate Revenue

We manage our business through a single operating segment comprising two primary revenue streams, Produced Water Handling and Water Solutions. Our Produced Water Handling revenue is driven by the volumes of produced water we gather from our customers, and our Water Solutions revenue is driven by the quantities of recycled produced water and groundwater delivered to our customers to support their well completion activities. See Part I, Items 1. and 2. Business Properties – Our Customers and Contracts –Contracts – Produced Water Handling and Contracts and Our Customers and Contracts – Water Solutions for a description of our contracts.

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Under our contracts with our customers, which are generally subject to periodic and limited index-based adjustments such as CPI, we receive a fixed fee per barrel of produced water received from our customers, which water is either handled or recycled, and a fixed fee per barrel of recycled water or groundwater sold to our customers. In addition, one of our significant customer contracts provides for rates that periodically fluctuate within a defined range in response to changes in WTI. See Part II, Item 7A. Quantitative and Qualitative Disclosures About Market Risk.

Costs of Conducting Our Business

Direct Operating Costs

We incur direct operating costs primarily as a function of the number of barrels of water received, handled and treated. The major categories of direct operating costs are landowner royalties, power expenses for handling and treatment facilities, direct labor, chemicals for water treatment, water filtration expenses, workover expense and repair and maintenance of facilities. We seek to minimize, to the extent appropriate for safe and reliable operations, expenses directly tied to operating and maintaining our assets. Certain expenses, such as workover and repair and maintenance expense, may occur on an irregular basis, resulting in volatility in our operating margin.

General and Administrative Expenses

General and administrative expenses are costs incurred for overhead, including payroll and benefits for our corporate staff, stock-based compensation, costs of maintaining our offices, costs of managing our permitting operations, information technology expenses, insurance, audit and other fees for professional services and other costs incurred as a result of our being a public company.

How We Evaluate Our Results of Operations

We use a variety of financial and operational metrics to evaluate our performance. These metrics help us identify factors and trends that impact our operating results, cash flows and financial condition. The key metrics we use to evaluate our business are provided below.

Produced Water Handling Volumes

We continually seek to bring additional produced water volumes onto our system to maintain or increase throughput on our systems. These volumes are a primary revenue driver and serve as a water source for our Water Solutions business. Changes in Produced Water Handling throughput are driven primarily by the level of production and pace of completions activity on our contracted acreage. We define Produced Water Handling Volumes as all produced water barrels received from customers and any barrels that are deficient under minimum volume commitment agreements.

Water Solutions Barrels Sold

Our recycled water and groundwater sales are driven primarily by our customers’ oil and gas well completion activities. We continually seek to gain market share and expand our customer base for recycled water in the Permian Basin, as well as shifting towards providing more recycled produced water as a proportion of total water solutions volumes. We believe our access to abundant produced water volumes and the scale of our systems allows us to distribute recycled water for our customers’ completion activities in an efficient, cost effective and environmentally conscious manner. We define Water Solutions barrels sold as the total of all recycled water and groundwater barrels sold.

Revenue

We analyze our revenue and assess our performance by comparing actual revenue to our internal projections and across periods. We examine revenue per barrel of water handled or sold to evaluate pricing trends and customer mix impacts. We also assess incremental changes in revenue compared to incremental changes in direct operating costs and selling, general and administrative expenses to identify potential areas for improvement and to determine whether our performance is meeting our expectations.

We generate revenue primarily by providing fee-based services related to our Produced Water Handling and Water Solutions businesses.

The services related to produced water are fee-based arrangements which are based on the volume of water that flows through our systems and facilities. Revenue from Produced Water Handling consists primarily of per barrel fees charged to our customers for the use of our transportation and water handling services. For our Produced Water Handling contracts, revenue is recognized over time utilizing the output method based on the volume of produced water accepted from the customer. As part of our water processing activities, we aggregate and sell recovered crude oil, also known as skim oil. Included in our Produced Water Handling revenues is skim oil sales revenue, which is recognized when custody is transferred to the purchaser and sold at market rates, net of marketing costs.

The sale of recycled produced water and groundwater are priced based on negotiated rates with our customers. For contracts that involve recycled produced water and groundwater, revenue is recognized at a point in time when control of the product is transferred to the customer.

Adjusted EBITDA

We use Adjusted EBITDA as a performance measure to assess the ability of our assets to generate sufficient cash to pay interest costs, support indebtedness and, at the discretion of our Board of Directors, return capital to equity holders. We also use Adjusted EBITDA as a performance measure under our short-term incentive plan. We define Adjusted EBITDA as net income (loss) plus: interest expense; income taxes; depreciation, amortization and accretion expense; abandoned well costs, asset impairment and abandoned project charges; losses on the sale of assets; transaction costs; research and development expense; change in payables related to the Tax Receivable Agreement liability as a result of state tax rate changes; loss on debt modification; stock-based compensation expense; and other non-recurring or unusual expenses or charges (such as litigation expenses, severance costs and amortization expense related to the implementation costs of our new enterprise resource planning system), less any gains on the sale of assets. Adjusted EBITDA is a non-GAAP financial measure. See Non-GAAP Financial Measures below for more information regarding this financial measure, including a reconciliation to its most directly comparable GAAP measure.

Adjusted Operating Margin and Adjusted Operating Margin per Barrel

Our Adjusted Operating Margin and Adjusted Operating Margin per Barrel are dependent upon the volume of produced water we gather and handle, the volume of recycled water and groundwater we sell and transfer, the fees we charge for such services, and the recurring operating expenses we incur to perform such services. We define Adjusted Operating Margin as Gross Margin (Total Revenue less Total Cost of Revenue) plus Depreciation, Amortization and Accretion. We define Adjusted Operating Margin per Barrel as Adjusted Operating Margin divided by total volumes handled, sold or transferred. Adjusted Operating Margin and Adjusted Operating Margin per Barrel are non-GAAP financial measures. See Non-GAAP Financial Measures below for more information regarding these financial measures, including a reconciliation to their most directly comparable GAAP measures for each measure.

We seek to maximize our Adjusted Operating Margin in part by minimizing, to the extent appropriate, expenses directly tied to operating our assets. Landowner royalties, power expenses for handling and treatment facilities, direct labor costs, chemical costs, water filtration expenses, workover expenses and repair and maintenance costs comprise the most significant portion of our expenses. Our operating expenses are largely variable and as such, generally fluctuate in correlation with throughput volumes.

Our Adjusted Operating Margin incrementally benefits from increased Water Solutions recycled water sales. When produced water is recycled, we recognize cost savings from reduced landowner royalties, reduced pumping costs, lower chemical treatment and filtration costs and reduced power consumption.

Results of Operations

Results of operations were as follows for the periods indicated: