EDGAR 10-K Filing

Company CIK: 844965
Filing Year: 2025
Filename: 844965_10-K_2025_0000844965-25-000013.json

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ITEM 1. BUSINESS
Item 1. Business.
The financial statements presented in this Annual Report are the consolidated financial statements of TETRA Technologies, Inc., a Delaware corporation and its subsidiaries. When the terms “TETRA,” “the Company,” “we,” “us,” or “our” are used in this document, those terms refer to TETRA Technologies, Inc. and its consolidated subsidiaries.
TETRA is a Delaware corporation incorporated in 1981. Our corporate headquarters are located at 24955 Interstate 45 North, The Woodlands, Texas, 77380. Our phone number is 281-367-1983 and our website is www.onetetra.com. Our common stock is traded on the New York Stock Exchange (the “NYSE”) under the symbol “TTI.”
Our Corporate Governance Guidelines, Code of Business Conduct, Code of Ethics for Senior Financial Officers, Policy on Trading in Company Securities, Audit Committee Charter, Human Capital Management and Compensation Committee Charter, and Nominating, Governance and Sustainability Committee Charter, as well as our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, and Current Reports on Form 8-K, and all amendments to those reports are all available, free of charge, on our website at www.onetetra.com as soon as practicable after we file the reports with the SEC. Information contained on or connected to our website is not, and shall not be deemed to be, a part of this Annual Report on Form 10-K or incorporated into any other filings with the SEC. The documents referenced above are available in print at no cost to any stockholder who requests them from our Corporate Secretary.
About TETRA
TETRA Technologies, Inc., together with its consolidated subsidiaries, is an energy services and solutions company with operations on six continents focused on developing environmentally conscious services and solutions that help make people’s lives better. In addition to providing products and services to the oil and gas industry and calcium chloride for diverse applications, TETRA is expanding into the low-carbon energy market with chemistry expertise, key mineral acreage, and global infrastructure, helping to meet the demand for sustainable energy in the twenty-first century. We have two reportable segments - Completion Fluids & Products Division and Water & Flowback Services Division.
Our Completion Fluids & Products Division manufactures and markets clear brine fluids (“CBFs”), additives, and associated products and services to the oil and gas industry for use in well drilling, completion, and workover operations in the United States and in certain countries in Latin America, Europe, Asia, the Middle East, and Africa. The Division also markets liquid and dry calcium chloride products manufactured at its production facilities or purchased from third-party suppliers to a variety of markets outside the energy industry, and markets TETRA PureFlow, an ultra-pure zinc bromide as well as TETRA PureFlow Plus, an ultra-pure zinc bromide/zinc chloride blend, to several battery technology companies.
Our Water & Flowback Services Division provides onshore oil and gas operators with comprehensive water management services. The Division also provides frac flowback, production well testing, and other associated services in many of the major oil and gas producing regions in the United States, as well as in oil and gas basins in certain countries in Latin America, Europe, and the Middle East.
We continue to pursue a long-term growth strategy that includes expanding our core businesses, domestically and internationally, through the introduction of new technology, organic growth, and accretive acquisitions.
Products and Services
Completion Fluids & Products Division
Liquid calcium chloride, calcium bromide, zinc bromide, zinc calcium bromide, sodium bromide, and blends of such products manufactured by our Completion Fluids & Products Division are referred to as CBFs in the oil and gas industry. CBFs are salt solutions that have variable densities and are used to control bottom-hole pressures during oil and gas completion and workover operations. The Division sells CBFs and various CBF additives to
United States and international oil and gas exploration and production companies and to other companies that service customers in the oil and gas industry.
The Completion Fluids & Products Division provides both stock and custom-blended CBFs based on each customer’s specific needs and the proposed application. It provides a broad range of associated CBF services, including on-site fluids filtration, handling and recycling, wellbore cleanup, custom fluids blending, and fluid management services. The Division’s flagship CBF technology, TETRA CS Neptune are high-density monovalent and divalent fluids that are free of undissolved solids, zinc, priority pollutants, and formate ions. They were developed by TETRA to be environmentally friendly alternatives to traditional zinc bromide high-density completion fluids and environmentally friendly and cost-effective alternatives to cesium formate high-density completion fluids, all of which are used in well completion and workover operations, as well as low-solids reservoir drilling fluids.
The Completion Fluids & Products Division offers to repurchase, or “buy-back”, certain used CBFs from customers, which can be reconditioned and recycled. Selling used CBFs back to us reduces the net cost of the CBFs to customers and minimizes our customers’ need to dispose of used fluids. We recondition used CBFs through filtration, blending and the use of proprietary chemical processes, and then market the reconditioned CBFs.
By blending different CBFs and using various additives, we are able to modify the specific density, crystallization temperature, and chemical composition of the CBFs as required to meet our customers’ specific needs. The Division’s fluid engineering personnel determine the optimal CBF blend for a customer’s particular application to maximize its effectiveness and lifespan. Our filtration services use a variety of techniques and equipment to remove particulates from CBFs at the customer’s site so the CBFs can be reused. Filtration also enables recovery of a greater percentage of used CBFs for reconditioning.
The Completion Fluids & Products Division manufactures liquid and dry calcium chloride and liquid calcium bromide, zinc bromide, zinc calcium bromide, and sodium bromide for distribution, primarily into energy markets. Liquid and dry calcium chloride are also sold into water treatment, industrial, cement, food processing, road maintenance, ice melt, agricultural, and consumer products markets. Sodium bromide is also sold into industrial water treatment markets, where it is used as a biocide in recirculated cooling tower waters and in other applications.
Our calcium chloride manufacturing facilities are located in the United States and Finland. In the United States, we manufacture liquid calcium chloride products at four manufacturing plant facilities. Liquid and flake calcium chloride are also produced at our Kokkola, Finland plant. We operate our European calcium chloride operations under the names TETRA Chemicals Europe AB and TETRA Chemicals Europe Oy. In the United States, we also manufacture liquid calcium chloride at our facilities in Parkersburg, West Virginia and Lake Charles, Louisiana, and we have two solar evaporation facilities located in San Bernardino County, California, that produce liquid calcium chloride and sodium chloride from underground brine reserves, which are replenished naturally. Our calcium chloride production facilities have a combined production capacity of approximately 1.0 million equivalent liquid tons per year. We also acquire calcium chloride inventory from other producers.
Our Completion Fluids & Products Division manufactures liquid calcium bromide, zinc bromide, zinc calcium bromide, and sodium bromide at our West Memphis, Arkansas facility. A proprietary process applied at this facility uses bromine and zinc to manufacture zinc bromide. This facility also uses proprietary processes to manufacture calcium bromide and sodium bromide and to recondition and upgrade used CBFs that we have repurchased from our customers.
We are also pursuing low-carbon energy initiatives that leverage our fluids and aqueous chemistry core competencies, our significant bromine and lithium resources (including our approximately 40,000 gross acres of brine leases in Arkansas) and technologies (see our disclosures titled “Bromine and Lithium Resources” set forth in Part I, “Item 2. Properties” of this Annual Report), and our leading calcium chloride production capabilities. The Completion Fluids & Products Division manufactures and sells zinc bromide battery electrolyte for the long-duration energy battery storage market.
In August 2021, we announced completion of a preliminary technical assessment by an independent geological consulting firm to assess lithium and bromine exploration targets in our Southwest Arkansas brine leases. Bromine is a key mineral component in zinc-bromide energy storage systems and our TETRA PureFlow is an ultra-pure zinc bromide, which has been qualified by several battery technology companies. The lithium battery market is a rapidly growing market, affording us the potential opportunity to participate in a meaningful way. In December, 2021, we announced a strategic agreement with Eos Energy Enterprises, Inc. ("Eos") (NASDAQ: EOSE) involving a
long-term supply and collaboration agreement to supply our ultra-pure zinc bromide TETRA PureFlow to Eos. TETRA and Eos expect to collaborate for improved battery performance, cost and system life including a solution for the end of a battery’s life using TETRA's extensive experience with reclaiming and recycling zinc bromide. In January 2024, we entered into a preferred supply agreement through December 31, 2027 in which Eos has agreed to purchase 100% of its requirement of zinc bromide products, including TETRA PureFlow zinc bromide, and 75% of its requirement of Eos’ proprietary electrolyte solution from TETRA, and has provided TETRA a right of first refusal prior to entering into a supply agreement for such products from a third-party. In connection with the supply agreement, TETRA was granted a non-exclusive, non-sub-licensable, non-transferable license to Eos’s proprietary electrolyte formula, solely in connection with manufacturing and provision of Eos’ proprietary electrolyte solution to Eos.
We are committed to pursuing low-carbon energy initiatives that leverage our fluids and aqueous chemistry core competencies, our significant bromine and lithium assets and technologies, and our leading calcium chloride production capabilities. During 2022, we completed the maiden inferred bromine and lithium brine resource estimation report for our leased acreage in the Smackover Formation in Southwest Arkansas, as well as a front end engineering and design (“FEED”) study for the design of a brine to bromine processing plant, pipeline and related assets. Completion of this FEED study and reservoir analysis were incremental steps for TETRA to complete an initial and preliminary economic analysis. During 2023, we completed a Technical Report Summary (the “Resources Report”) for our 6,138 acre “Evergreen Brine Unit” in Arkansas. The Resources Report included both “measured” and “indicated” resources in addition to the “inferred” category. Further steps are required before making a decision to develop the bromine assets, which may include drilling an additional well or wells, further studies to mature the resource and completion of a pre-feasibility and/or feasibility study.
Water & Flowback Services Division
Our Water & Flowback Services Division provides a wide variety of water management services that support hydraulic fracturing in unconventional well completions for domestic onshore oil and gas operators. These services include fresh and produced water analysis, treatment, and recycling, blending and distribution, storage and pit lining, transfer, engineering, and environmental risk mitigation. The Water & Flowback Services Division’s patented and patent-pending equipment and processes include advanced hydrocyclones for sand management, certain produced- and fresh-water blending technologies, and the TETRA Steel 1200, a lay-flat hose rapid deployment water transfer system. The Water & Flowback Services Division seeks to design sustainable solutions that meet the unique needs of each customer in order to maximize operational performance and efficiency and minimize the use of fresh water. These solutions include tailored “last mile” infrastructure to transfer water around well pads in a safe, efficient, and environmentally responsible manner - which consists of water storage ponds, movable storage tanks, a network of water transfer lines including poly pipe and TETRA Steel lay-flat hose, automated transfer and blending of produced water, and water treatment and recycling systems. These systems include the TETRA SwiftWater Automated Treatment (“SWAT”) system that chemically treats produced water through a clarification process and the TETRA Oil Recovery After Production Technology (ORAPT) mobile oil separation system that recovers oil from produced water. Automation has also been deployed across the TETRA water management portfolio, and across TETRA flowback services, to reduce health, safety and environmental risks and enhance reliability and cost-effectiveness. In December 2024, we announced the commercial launch of TETRA Oasis TDS, an end-to-end water treatment and desalination technology for beneficial re-use and mineral extraction applications for oil and gas well produced water. During the fourth quarter of 2024, the Water & Flowback Services Division completed a commercial pilot project for the desalination of Delaware Basin produced water for a major North America oil and gas operator. The desalinated water was tested against published Texas Railroad Commission standards for beneficial re-use water at both TETRA's laboratory and an independent third-party laboratory. Subsequently, the treated water was sent to a third party for Whole Effluent Toxicity testing where it successfully passed all test parameters.
Our Water & Flowback Services Division also provides frac flowback services, early production facilities and services, production well testing services, and other associated services, including well flow management and evaluation services that enable operators to quantify oil and gas reserves, optimize oil and gas production and minimize oil and gas reservoir damage. In certain basins, water, sand, and other abrasive materials commonly accompany the initial production of natural gas or oil, often under high-pressure and high-temperature conditions and, in some cases, from reservoirs containing high levels of hydrogen sulfide gas. The Water & Flowback Services Division provides the specialized equipment and qualified personnel to address these impediments to production. Early production services typically include sophisticated evaluation techniques for reservoir management, including unconventional shale reservoir exploitation and optimization of well workover programs. Frac flowback and
production well testing services may include well control, well cleanup and laboratory analysis. These services are used in the completion process after hydraulic fracturing and in the production phase of oil and gas wells.
This Division maintains one of the largest fleets of high-pressure production testing equipment in the United States, including equipment designed to work in environments where high levels of hydrogen sulfide gas are present. The Division has domestic operating locations in Louisiana, New Mexico, Oklahoma, Pennsylvania, and Texas. The Division also has locations in certain countries in Latin America and the Middle East.
Sources of Raw Materials
Our Completion Fluids & Products Division manufactures calcium chloride, calcium bromide, zinc bromide, zinc calcium bromide, and sodium bromide for sale to its customers. The Division also recycles used calcium bromide and zinc bromide CBFs repurchased from its oil and gas customers.
The Completion Fluids & Products Division manufactures liquid calcium chloride, either from underground brine or by reacting hydrochloric acid with limestone. We produce calcium chloride and sodium chloride at our two facilities in San Bernardino County, California, by solar evaporation of pumped underground brine reserves that contain calcium chloride. The underground reserves of this brine are deemed adequate to supply our foreseeable need for calcium chloride at those plants. The Division also purchases liquid and dry calcium chloride from a number of United States and foreign chemical manufacturers.
The Completion Fluids & Products Division’s primary sources of hydrochloric acid are co-product streams obtained from chemical manufacturers. Substantial quantities of limestone are also consumed when converting hydrochloric acid into calcium chloride. Currently, hydrochloric acid and limestone are generally available from multiple sources.
To produce calcium bromide, zinc bromide, zinc calcium bromide, and sodium bromide at our West Memphis, Arkansas facility, we use bromine, hydrobromic acid, zinc, ammonia water and lime as raw materials. There are multiple sources of zinc that we can use in the production of zinc bromide and zinc calcium bromide. We have a long-term supply agreement with LANXESS, AG (“LANXESS”) under which the Completion Fluids & Products Division purchases its requirements of raw material bromine from LANXESS’ Arkansas bromine production facilities. On May 25, 2023, we entered into the Third Amendment to Bromine Requirements Sales Agreement (the “Amendment”) with LANXESS, which provides for, among other things, revised volume requirements, pricing, and related terms. The Amendment was effective April 1, 2023 and was entered into in connection with the entry into a settlement agreement in the Company’s arbitration with LANXESS. See Note 11 - “Commitments and Contingencies” in the Notes to Consolidated Financial Statements in this Annual Report for further information.
We have not historically directly purchased any significant volumes of raw materials from Russia, Ukraine, Israel, or the Gaza region. Additionally, we have not historically sold any significant volumes of product to Russia, Ukraine, Israel or, the Gaza region and have discontinued all transactions with customers and suppliers in Russia and Ukraine. However, one of our raw material providers sourced one of their raw materials from Russia or Ukraine. Because of the ongoing conflict between Russia and Ukraine, during early 2022, we experienced supply constraints with our primary European supplier of certain raw materials. Although this constraint has since resolved, we experienced decreased production volumes of calcium chloride in the first half of 2022. Should we experience similar supply constraints in the future, we may experience future financial impact, the magnitude of which is uncertain.
We currently lease over 40,000 gross acres of brine leases near Magnolia, Arkansas, which contain bromine and lithium. See our disclosures titled “Bromine and Lithium Resources” set forth in Part I, “Item 2. Properties” of this Annual Report. The long-term LANXESS bromine supply agreement discussed above provides a secure supply of bromine to support a majority of the Division’s current manufacturing levels. We do, however, continue to evaluate our strategy related to the Arkansas assets and their future development. In addition, we are party to agreements with Standard Lithium Ltd. (“Standard Lithium”) (NYSE: SLI), under which Standard Lithium has the right to explore, produce and extract lithium and lithium derivatives in a portion of our Arkansas leases located outside of the Evergreen Brine Unit as well as additional potential resources in the Mojave region (San Bernardino County) of California. Standard Lithium delivered a notice to exercise this option to acquire those lithium rights in a portion of our Arkansas leases located outside of the Evergreen Brine Unit on October 6, 2023. See Note 2 - “Basis of Presentation and Significant Accounting Policies” and Note 14 - “Fair Value Measurements” in the Notes to Consolidated Financial Statements for further information.
The Water & Flowback Services Division purchases water management and production testing equipment and components from third-party manufacturers.
Market Overview and Competition
Our operations are highly dependent upon the demand for, and production of, natural gas and oil in the various domestic and international locations in which we operate. Demand for products and services of our Completion Fluids & Products Division remained resilient despite pandemic impacts on commodity prices in 2020. Following a period of depressed commodity prices during 2020, prices experienced significant recoveries beginning in the second half of 2021 and continued through 2022, but declined slightly during 2023 and remained consistent during 2024.
Completion Fluids & Products Division
Our Completion Fluids & Products Division provides its products and services to oil and gas exploration and production companies in the United States and certain foreign markets, and to other customers that service such companies. Current areas of market presence include the onshore U.S., the U.S. Gulf of America, the North Sea, Mexico and certain countries in South America, Europe, Asia, the Middle East, and Africa. Customers with deepwater operations frequently use high volumes of CBFs, which can be subject to harsh downhole conditions, such as high pressure and high temperatures. Demand for CBF products is generally driven by offshore completion and workover activity.
The Completion Fluids & Products Division’s principal competitors in the sale of CBFs to the oil and gas industry are other major international drilling fluids and energy services companies, to many of which we provide products and services. This market is highly competitive and competition is based primarily on service, availability, and price. Customers of the Completion Fluids & Products Division include significant oilfield service companies, major and independent U.S. and international oil and gas producers, and U.S. and international chemical providers. The Division also sells its CBF products through various distributors.
The Completion Fluids & Products Division’s liquid and dry calcium chloride products have a wide range of uses outside the energy industry. Non-energy market segments where these products are used include water treatment, industrial, food processing, road maintenance, ice melt, agricultural, and consumer products. As part of our low carbon solutions, we produce and provide end users with zinc bromide, used in zinc-bromine batteries and energy storage. We also sell sodium bromide into industrial water treatment markets as a biocide. Most of these markets are highly competitive. In Europe, our Completion Fluids & Products Division’s calcium chloride operations market, distribute, sell or offer to sell calcium chloride products in certain European industries. Our principal competitors in the non-energy related calcium chloride markets include Occidental Chemical Corporation and Vitro Corporation in North America and Nedmag B.V. in Europe.
Water & Flowback Services Division
The Water & Flowback Services Division provides comprehensive water management and frac flowback services to a wide-range of onshore oil and gas operators located in all active North America unconventional oil and gas basins.
The Division also provides frac flowback services, early production facilities and services, production well testing services, sand filtration, and other associated services in various domestic and international locations, including well flow management and evaluation services that enable operators to quantify oil and gas reserves, optimize oil and gas production, and minimize oil and gas reservoir production damage.
The water management, flowback, and production testing markets are highly competitive, and competition is based on availability of appropriate equipment and qualified personnel, as well as price, quality of service, and safety record. The Division’s skilled personnel, operating procedures, integrated closed-loop water management solution, automation systems, and safety record give us a competitive advantage. Competition in the U.S. water management markets includes Select Energy Services, Inc. and various regional companies, while competition in onshore U.S. production testing markets is primarily dominated by numerous small, privately owned operators. Halliburton and Schlumberger are competitors in the international production testing markets we serve although we provide these services to their customers on a subcontract basis from time to time. Customers for the Water &
Flowback Services Division include major integrated and independent U.S. and international oil and gas producers that are active in the areas in which we operate.
No single customer provided 10% or more of our total consolidated revenues during the years ended December 31, 2024, 2023, or 2022.
Other Business Matters
Human Capital Management
We collaborate as a team to execute for each other, our customers, and our shareholders. As of December 31, 2024, we employed approximately 1,400 people worldwide. None of our U.S. employees are presently covered by a collective bargaining agreement. Our employees outside the U.S. are generally members of labor unions and associations in the countries in which they are employed. We use engagement surveys and exit interviews to, among other things, gauge our employees’ perspective on the company. We ask questions around company culture, if employees would consider working for the company again, or if they recommend working for the company. Based on results, we believe that our relations with our employees are good.
Equal Employment Opportunity
We value equal employment opportunity to stimulate creativity and innovation in our workforce as we use our collective talents to develop unique solutions to address the world's energy challenges. Our executive management sponsored Corporate Social Responsibility Committee focuses on sharing information and promoting key initiatives across the company to educate and create awareness about the importance of a multi-faceted and welcoming culture. The committee also assists the talent management group to attract, retain, develop, and reward a high-performing workforce, provide forums and sponsor training activities to share best practices concerning employment practices education, and develop communication platforms to share information about and promote the committee’s activities.
Career Development
The board of directors, the chief executive officer, and the vice president of Human Resources, evaluate, from time to time each year, executive development and succession planning to prepare us for future success. The succession planning process covers all senior management positions and certain other key positions. This review of executive talent determines readiness to take on additional leadership roles and identifies developmental opportunities needed to prepare our executives for greater responsibilities. Our short and long-term business strategy is considered when evaluating candidates and their skills.
Compensation and Benefits
The Company’s compensation programs are designed to incentivize performance, maximize returns, and build shareholder value. We work with consultants to perform market-based assessments of our compensation and benefits programs to help us offer competitive compensation packages to attract and retain high-performing talent. We also offer competitive benefits to attract and retain exceptional talent.
Safety
Recognizing that safety, service quality, and environmental protection are conditions of employment, all employees and contractors are responsible for their safety, the safety of those around them, the quality of their work, and protection of the environment. As part of our safety-focused culture, it is customary that each meeting starts with an employee-led safety moment.
To ensure our work remains safe and of the highest quality, the Company has a comprehensive health, safety, environment, and quality (“HSEQ”) Management System and program designed to improve the capacity of the organization by controlling worksite risks, developing proper work practices and procedures, and empowering employees with stop-work authority if they observe unsafe conditions, omissions, errors, or actions that could result in safety or environmental incidents, or product and service quality issues. If an incident takes place, we investigate all serious occurrences to determine root causes and implement corrective actions to ensure we expand our capacity to operate safely.
Driving is one of the highest exposure activities that we undertake in our day-to-day operations. We maintain a fleet of DOT and non-DOT vehicles and provide real-time behavior feedback to our drivers via near real-time monitors. Coupled with Journey Management, vehicle selection guidelines, and driver training, we have a comprehensive approach to reducing our driving exposure and incidents.
Proprietary Technology and Trademarks
We own a variety of intellectual property rights, such as patents, trademarks and trade secrets. While we believe that our patents and trade secrets are important to our competitive positions in our businesses, we do not believe any one patent or trade secret is essential to our success.
It is our practice to enter into confidentiality agreements with key employees, consultants and third parties to whom we disclose our confidential and proprietary information, and we have typical policies and procedures designed to maintain the confidentiality of such information. There can be no assurance, however, that these measures will prevent the unauthorized disclosure or use of our trade secrets and expertise, or that others may not independently develop similar trade secrets or expertise.
We sell various products and services under a variety of trademarks and service marks, some of which are registered in the United States or other countries.
Health, Safety, and Environmental Affairs Regulations
Our service and sales operations and manufacturing plants are subject to stringent and complex U.S. and foreign health, safety, and environmental laws and regulations. Although we are committed to conducting all of our operations under the highest standards of safety and respect for the environment, risks of substantial costs and liabilities pursuant to such laws and regulations are inherent in certain of our operations and in the development and handling of certain products and equipment produced or used at our plants, well locations, and worksites. Because of these risks, there can be no assurance that significant costs and liabilities will not be incurred now or in the future. While from time to time there have been periods of deregulation under certain U.S. presidential administrations, the general trend has been towards more stringent changes in environmental laws and regulations. Changes in environmental and health and safety laws and regulations could subject us to more rigorous standards and could affect demand for our customers’ products which in turn would impact demand for our products. We cannot predict the extent to which our operations may be affected by any changes to existing laws, regulations and enforcement policies, new interpretations of existing laws, regulations and policies, or any new laws, regulations, or policies promulgated in the future.
We are subject to numerous federal, state, local, and foreign laws and regulations relating to health, safety, and the environment, including regulations regarding air emissions, wastewater and storm water discharges, and the disposal of certain hazardous and nonhazardous wastes. Compliance with such laws and regulations may expose us to significant costs and liabilities, and cause us to incur significant capital expenditures in our operations. Failure to comply with these laws and regulations or associated permits may result in the assessment of administrative, civil or criminal fines and penalties, the imposition of other corrective action obligations or other injunctive relief, or both.
Our operations in the United States are subject to various evolving environmental laws and regulations that are enforced by the U.S. Environmental Protection Agency (“EPA”); the Bureau of Safety and Environmental Enforcement (“BSEE”) of the U.S. Department of the Interior; the U.S. Coast Guard; and various other federal, state, and local environmental authorities. Similar laws and regulations, designed to protect the health and safety of our employees and visitors to our facilities, are enforced by the U.S. Occupational Safety and Health Administration, and other state and local agencies and authorities. Some of the primary environmental laws and regulations applicable to our operations include: (i) the Federal Water Pollution Control Act of 1972 (the “Clean Water Act”); (ii) the Resource Conservation and Recovery Act of 1976; (iii) the Clean Air Act of 1977 (“CAA”); (iv) the Comprehensive Environmental Response, Compensation, and Liability Act of 1980 (“CERCLA”); (v) the Superfund Amendments and Reauthorization Act of 1986; (vi) the Toxic Substances Control Act of 1976; (vii) the Hazardous Materials Transportation Act of 1975; (viii) the Pollution Prevention Act of 1990; and (ix) the Endangered Species Act of 1973 (“ESA”). Our operations outside the United States are subject to various foreign governmental laws and regulations relating to the environment, health and safety, and other regulated activities in the countries in which we operate, which may in some cases impose more stringent requirements than applicable laws in the United States.
Our operations routinely involve the handling of hydrocarbons and produced water. Hydrocarbons or hazardous and nonhazardous wastes may have been released during our operations, by third parties on wellhead sites where we provide services or store our equipment, or on or under other locations where wastes have been taken for disposal. Although most wastes associated with the exploration, development and production of oil and natural gas are currently exempt from the more stringent hazardous waste regulations under the Resource Conservation and Recovery Act (“RCRA’) and its state analogs, it is possible that some of the material we handle now or may handle in the future may be subject to regulation under RCRA as a hazardous waste. Additionally, we cannot assure you that such materials will not be subject to more stringent requirements or characterized as hazardous wastes in the future. Separately, properties where such hydrocarbons and/or wastes are released or disposed of may be subject to investigatory, remediation, and monitoring requirements under foreign, federal, state, and local environmental laws and regulations. CERCLA and comparable state laws and regulations impose strict, joint, and several liabilities without regard to fault or the legality of the original conduct on certain classes of persons that contributed to the release of a hazardous substance into the environment. These persons include the owner or operator of a disposal site where a hazardous substance release occurred and any person that transported, disposed of, or arranged for the transport or disposal of such hazardous substances released at a site. Under CERCLA, such persons may be liable for the costs of remediating the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies.
The CAA and its implementing regulations, and comparable state laws and regulations, regulate the emissions of air pollutants from various industrial sources and impose monitoring and reporting requirements. These laws and regulations impose limits on the levels of various substances that may be emitted into the atmosphere. For example, from time to time the EPA has taken certain steps to regulate methane emissions from the oil gas sector. Most recently, in December 2023, EPA finalized a rule that, established more stringent OOOO(b) new source and OOOO(c) first-time existing source standards of performance for methane and volatile organic compound emissions for oil and gas facilities. Fines and penalties for violations of these rules can be substantial. The rules have been subject to legal challenge and, most recently, the D.C. Circuit Court granted the EPA’s motion to hold the cases in abeyance while the agency reviews the final rule. The final rule may be repealed or modified by the Trump administration, though we cannot predict the substance or timing of such changes, if any.
In accordance with Section 402 of the Clean Water Act, the EPA is authorized to issue National Pollutant Discharge Elimination System (“NPDES”) General Permits to regulate offshore discharges in the Gulf of America which includes Treatment, Completion and Workover (“TCW”) fluids. Our operations include providing services and materials to oil and gas operators for the use of TCW fluids in the Gulf of America. The EPA’s most recent NPDES permits for Region 6 for oil and gas operations in the federal waters of the western and central Gulf of America went into effect on May 11, 2023. The Region 4 permit for the eastern Gulf of America went into effect on April 3, 2024. Delays in issuing these permits or otherwise obtaining coverage under them could adversely impact our customers’ operations and reduce demand for our services. The Clean Water Act, and comparable state laws and regulations thereunder, also prohibit the discharge of pollutants into regulated waters without a permit, including industrial wastewater discharges and storm water runoff, and establish limits on the levels of pollutants contained in such discharges.
The modification or reinterpretation of existing environmental laws or regulations, the more vigorous enforcement of existing environmental laws or regulations, or the adoption of new environmental laws or regulations could adversely affect oil and natural gas exploration and production operations, which in turn could have an adverse effect on us. For example, the federal government regularly evaluates new species for listing under the ESA. The ESA provides broad protection for species of fish, wildlife and plants that are listed as threatened or endangered, as well as certain “critical habitat” for such species. Similar protections are offered to migratory birds under the Migratory Bird Treaty Act. The listing of any new species, the relisting of a species from threatened to endangered, or the designation of critical habitat for any such species may cause us or our customers to incur additional costs or become subject to operating restrictions or bans at certain times or in certain areas. Separately, regulators at both the federal and state levels have placed increasing attention on matters related to oil and gas operations, particularly hydraulic fracturing and the emission of greenhouse gases (“GHGs”). For more information, see our risk factors titled “Our operations, and those of our suppliers and customers, are subject to a series of risks arising from climate change” and “Regulatory initiatives related to hydraulic fracturing in the countries where we and our customers operate could result in operating restrictions or delays in the completion of oil and gas wells that may reduce demand for our services.”
We maintain various types of insurance intended to reimburse us for certain costs in the event of an accident, including an explosion or similar event, involving our onshore and offshore operations. Our insurance
program is reviewed not less than annually with our insurance brokers and underwriters. Such insurance policies may not cover, or may only partially cover, certain losses or claims, which could result in a material adverse effect on our business and operations.
Executive Officers and Directors
The following table sets forth certain information with respect to our executive officers and directors:
Executive Officers:
Brady M. Murphy President, Chief Executive Officer, and board member
Elijio V. Serrano Senior Vice President and Chief Financial Officer
Matthew J. Sanderson Executive Vice President and Chief Commercial Officer
Timothy C. Moeller Senior Vice President - Global Supply Chain and Chemicals
Roy E. McNiven Senior Vice President - Energy Services Operations
Alicia P. Boston General Counsel and Chief Compliance Officer
Jacek M. Mucha Vice President - Finance, Treasurer, and Assistant Secretary
Directors:
Mark E. Baldwin Former executive vice president and chief financial officer of Dresser-Rand Group, Inc.
Thomas R. Bates, Jr. Adjunct professor in the Finance Department at Texas Christian University
Christian A. Garcia Former executive vice president and chief financial officer of BrandSafway
John F. Glick Former chief executive officer of Lufkin Industries, Inc.
Angela D. John Former director of innovation and strategy for New Energy Ventures with the Williams Companies, Inc.
Sharon B. McGee Founder SDBM Executive and Strategic Advisory, LLC and former vice president at Albemarle Corporation
Shawn D. Williams Former chief executive officer of Nexeo Plastics Holdings, Inc.

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ITEM 1A. RISK FACTORS
Item 1A. Risk Factors.
Although it is not possible to identify all of the risks we encounter, we have identified the following significant risk factors that could affect our actual results and cause actual results to differ materially from any such results that might be projected, forecasted, or estimated by us in this Annual Report.
Market Risks
The demand and prices for our products and services are affected by several factors, including the supply, demand, and prices for oil and natural gas.
Demand for our services and products is particularly sensitive to the level of exploration, development, and production activity of, and the corresponding capital spending by, oil and natural gas companies. The level of exploration, development, and production activity is directly affected by oil and natural gas prices, which historically have been volatile and are likely to continue to be volatile. Prices for oil and natural gas are subject to large fluctuations in response to relatively minor changes in the supply of and demand for oil and natural gas, market uncertainty, and a variety of other economic factors that are beyond our control.
For example, West Texas Intermediate oil prices averaged $94.90, $77.58, and $76.63 per barrel during 2022, 2023, and 2024, respectively. Over this same period, U.S. natural gas prices have also been volatile, with the Henry Hub price averaging $6.45, $2.53, and $2.15 per MMBtu during 2022, 2023, and 2024, respectively.
Prolonged volatility and low levels of oil and natural gas prices and supply and demand imbalances generate depressed levels of exploration, development, and production activity. If oil and natural gas prices decline significantly and supply and demand imbalances persist, there would be a material adverse effect on our business, consolidated results of operations, and consolidated financial condition. Should current market conditions worsen for an extended period of time, we may be required to record additional asset impairments. Such potential impairment charges could have a material adverse impact on our operating results.
Factors affecting the prices of oil and natural gas include: the level of supply and demand for oil and natural gas, worldwide; governmental regulations, including the policies of governments regarding the exploration for and production and development of their oil and natural gas reserves; weather conditions, natural disasters, and health or similar issues, such as pandemics or epidemics; worldwide political, military, and economic conditions such as the Russia-Ukraine conflict, the conflict in the Israel-Gaza region and continued hostilities in the Middle East; the ability or willingness of the Organization of Petroleum Exporting Countries (“OPEC”) and non-OPEC countries, such as Russia, to set and maintain oil production levels; the levels of oil production in the U.S.; oil refining capacity and shifts in end-customer preferences toward fuel efficiency and the use of natural gas; the cost of producing and delivering oil and natural gas; and acceleration of the development of, and demand for, alternative energy sources.
We encounter, and expect to continue to encounter, intense competition in the sale of our products and services.
We compete with numerous companies in each of our operating segments, many of which have substantially greater financial and other resources than us. Certain of our competitors have lower standards of quality, and offer equipment and services at lower prices than we do. Other competitors have newer equipment that is better suited to our customers’ needs. If we experience another period of low oil and natural gas pricing, to the extent competitors offer products or services at lower prices or higher quality, or more cost-effective products or services, our business could be materially and adversely affected. In addition, certain of our customers may elect to perform services internally in lieu of using our services, which could also materially and adversely affect our operations.
The profitability of our operations is dependent on other numerous factors beyond our control.
Our operating results in general, and gross profit in particular, are determined by market conditions and the products and services we sell in any period. Other factors, such as heightened competition, changes in sales and distribution channels, availability of skilled labor and contract services, shortages in raw materials, or inability to obtain supplies at reasonable prices, may also affect the cost of sales and the fluctuation of gross margin in future periods. Although equipment and materials used in providing our products and services to our customers are normally readily available, market conditions could trigger constraints in the supply chain of certain equipment and raw materials used in providing products and services to our customers. If we experience future supply chain disruptions, or if we experience significant increases in the costs of equipment and materials used in providing our products and services, it could have a material adverse effect on our revenues and profitability.
Other factors affecting our operating results and activity levels include oil and natural gas industry spending levels for exploration, completion, production, development, and acquisition activities, and impairments of long-lived assets. Customer consolidation may also lead to reductions in capital spending that could have an adverse effect on our business. In addition, Completion Fluids & Products Division profitability in future periods will continue to be affected by the mix of its products and services, including the timing of TETRA CS Neptune completion fluid projects, which are also dependent upon the success of customer offshore exploration and drilling efforts. If our customers reduce capital expenditures, such reductions may have a negative effect on the demand for many of our products and services and on our revenues and results of operations. A large concentration of our operating activities is located in the Permian Basin region of Texas and New Mexico. Our revenues and profitability are particularly dependent upon oil and natural gas industry activity and spending levels in this region. Our operations may also be affected by technological advances, cost of capital, and tax policies. Adverse changes in any of these other factors may have a material adverse effect on our revenues and profitability.
In addition, the United States has experienced higher inflation in recent years which has resulted and may in the future result in increases to the costs of our goods, services and labor, and in turn has caused and may cause our capital expenditures and operating costs to rise. To the extent elevated inflation remains, we may experience additional cost increases for our operations, including services, labor costs and equipment if our operating activity increases. If we can’t recover higher costs through higher prices for our services, it would negatively impact our business, financial condition and results of operations.
We hold minority investments in both publicly-traded and privately-held companies. Over time, the fair value of these investments may fluctuate significantly causing volatility in our financial results.
As of December 31, 2024, we held investments in Kodiak Gas Services, Inc. (“Kodiak”) and Standard Lithium, which had fair values of $18.4 million and $1.2 million, respectively. Our operating results could be
significantly affected by fluctuations in the market value of these investments. In January 2025, we sold our Kodiak shares for proceeds of $19.0 million, net of transaction and broker fees. The value of our remaining investments may be adversely affected by negative changes in Standard Lithium’s results of operations, cash flows and financial position.
As of December 31, 2024, we also held investments valued at approximately $8.6 million in a convertible note, common units and preferred units issued by two privately-held companies. These convertible notes, common units and preferred units are not publicly traded and may not be offered, sold, transferred or pledged until such units are registered pursuant to an effective registration statement or pursuant to an exemption from registration. These investments will be subject to fair value measurement adjustments which will affect our financial results and there can be no assurance that the convertible notes will ultimately be repaid or converted in equity of the issuers.
Changes in the economic environment have resulted, and could further result, in significant impairments of certain of our long-lived assets.
Under U.S. generally accepted accounting principles (“U.S. GAAP”), we review the carrying value of our long-lived assets when events or changes in circumstances indicate that the carrying value of these assets may not be recoverable, based on their expected future cash flows. The impact of reduced expected future cash flow could require the write-down of all or a portion of the carrying value for these assets, which would result in additional impairments, resulting in decreased earnings. During the three-year period ending December 31, 2024, we recorded a total of $5.9 million of impairments and other charges for certain right-of-use lease assets, inventory and long-lived assets other than goodwill. See Note 6 - “Impairments and other charges” in the Notes to Consolidated Financial Statements for further discussion of impairments. Depressed commodity prices and/or adverse changes in the economic environment could result in a greater decrease in the demand for many of our products and services, which could impact the expected utilization rates of certain of our long-lived assets, including plant facilities, operating locations, and operating equipment.
We are dependent on third-party suppliers for specific products and equipment necessary to provide certain of our products and services.
We sell a variety of CBFs to the oil and gas industry and non-energy markets, including calcium chloride, calcium bromide, zinc bromide, zinc calcium bromide, sodium bromide, formate-based brines, and our TETRA CS Neptune fluids, some of which we manufacture and some of which are purchased from third parties. Sales of these products contribute significantly to our revenues. In our manufacture of calcium chloride, we use brines, hydrochloric acid, and other raw materials purchased from third parties. In our manufacture of brominated CBF products, we use elemental bromine, hydrobromic acid, and other raw materials that are purchased from third parties. There are several raw materials for which there are only a limited number of suppliers or a single supplier. To mitigate potential supply constraints, we enter into supply agreements with particular suppliers. For example, we are currently required to purchase all of our requirements of elemental bromine, up to a certain specified maximum and subject to a specified annual minimum, from LANXESS under a long-term supply agreement. We also evaluate alternative sources of supply to avoid reliance on limited or sole-source suppliers when possible. Although we have long-term supply agreements with LANXESS, there is no assurance that we will have an adequate supply of elemental bromine or the other raw materials required for all of our CBF opportunities, or that such raw materials will be available at reasonable prices. Economic sanctions and other regulations imposed by the United States and other international countries as a result of the conflict involving Russia and Ukraine, Israel and Gaza region, hostilities in the Middle East, or maritime piracy attacks may disrupt supplies or affect the prices of certain raw materials. Should the conflict in Ukraine or other international locations further escalate, it is difficult to anticipate the extent to which current or future sanctions could increase our costs, disrupt our supplies, reduce our sales or otherwise affect our operations. Additionally, new or increased tariffs could impact raw material prices and the cost of component parts. If we are unable to acquire these raw materials at reasonable prices, or at all, for a prolonged period, our Completion Fluids & Products Division business could be materially and adversely affected.
Operating and Technological Risks
We have technological and age-obsolescence risk, both with our products and services as well as with our equipment assets.
New drilling, completion, and production technologies and equipment are constantly evolving. If we are unable to adapt to new advances in technology or replace older assets with new assets, we are at risk of losing
customers and market share. Certain equipment, such as a portion of our production testing equipment fleet, may be inadequate to meet the needs of our customers in certain markets. The permanent replacement or upgrade of any of our equipment will require significant capital. Due to the unique nature of many of these assets, finding a suitable or acceptable replacement may be difficult and/or cost prohibitive. The replacement or enhancement of these assets over the next several years may be necessary for us to effectively compete in the current marketplace.
Our operations involve significant operating risks and insurance coverage may not be available or cost-effective.
We are subject to operating hazards normally associated with the oilfield service industry, including automobile accidents, fires, explosions, blowouts, formation collapses, mechanical problems, abnormally pressured formations, and environmental accidents. Environmental accidents could include, but are not limited to, oil and produced water spills, gas leaks or ruptures, uncontrollable flows of oil, gas, or well fluids, or discharges of CBFs or toxic gases or other pollutants into the air, soil, water, groundwater, etc. These operating hazards may also include injuries to employees and third parties during the performance of our operations.
We have maintained a policy of insuring our risks of operational hazards that we believe is customary in the industry. We believe that the limits of insurance coverage we have purchased are consistent with the exposures we face and the nature of our products and services. Due to economic conditions in the insurance industry, from time to time, we have increased our self-insured retentions for certain policies in order to minimize the increased costs of coverage, or we have reduced our limits of insurance coverage for, or not procured, certain coverage. In certain areas of our business, we, from time to time, have elected to assume the risk of loss for specific assets. To the extent we suffer losses or claims that are not covered, or are only partially covered by insurance, our results of operations could be adversely affected.
We may not be able to economically extract lithium or bromine from the leased acreage in our Arkansas brine leases.
In addition to proven bromine reserves, our Arkansas brine leases currently contain probable bromine reserves and inferred, indicated and measured resources of lithium and bromine, and we may never convert any of these resources to proven mineral reserves on these properties, or enough of them to justify the decision to engage in the extraction of lithium and/or bromine. There can be no assurance that any future exploration efforts on these properties will be successful.
While we continue to evaluate the next steps regarding the potential development of our brine leases, we have only very recently completed a definitive feasibility study with respect to bromine and an updated technical resources report for our Evergreen Brine Unit, and we are not currently able to determine the economic viability of the extraction of the lithium and bromine from the leased acreage. In addition, the extraction of lithium and bromine from these brine leases will likely require a significant amount of time and capital, which may exceed current estimates and which may not be available to us on acceptable terms or at all. In August 2024, we published a definitive feasibility study for the production of bromine from our Evergreen Unit. Prior to producing lithium and bromine from the Evergreen Brine Unit, we must complete a lithium FEED study and a feasibility study for our lithium acreage, validate the lithium technologies used, coordinate with the local utility co-op for the construction of power infrastructure to supply electricity to our plant site, complete detailed engineering for a processing facility, obtain permits for our extraction activities which could be subject to delays or onerous conditions, as well as finalize any contractual agreements with our potential joint venture partner, Saltwerx. We and Saltwerx continue to evaluate the potential development of and the negotiation of the joint venture for the Evergreen Brine Unit and are continuing to advance the engineering studies required to more precisely define the lithium project economics. Unless and until we finalize any contractual agreements with Saltwerx, including a joint venture agreement, our relationship with Saltwerx will be governed by the MOU and the Brine Unit Operating Agreement approved by the Arkansas Oil and Gas Commission. See “Item 2. Properties-Bromine and Lithium Resources” for more information regarding the MOU. As a result of these uncertainties, no assurance can be given that any future exploration programs will result in the discovery of commercially viable mineral resources or reserves.
Failure to effectively and timely execute any of our low carbon energy initiatives could have an adverse effect on our business and financial condition.
Our future success may depend on our ability to effectively execute on our low carbon energy initiatives. This strategy depends on our ability to effectively identify, develop, and scale new technologies, expand application of our global infrastructure and chemistry expertise and on the economic viability of the extraction of lithium and bromine from our Arkansas brine leases. Furthermore, execution of our low carbon initiatives are subject to a number of permitting, real estate, and project development risks, which could delay, limit, or even prevent the
successful execution of these initiatives. Moreover, we cannot guarantee that the low carbon initiatives we may identify will meet the expectations of our various stakeholders. Even if successful, we could face increased costs from our pursuit of low carbon initiatives. For example, the exploration, development and extraction of brine and lithium from our Arkansas brine leases will likely require significant time and capital, and there is no guarantee of a return from these operations. Our low carbon energy initiatives may also depend in part on successful development of partnerships with other companies, such as our partnership and investments in privately-held companies and our MOU and potential joint venture partnership with Saltwerx, and such partners’ execution of their own respective projects and business strategies. Moreover, successful execution of these initiatives may turn on the timely issuance of permits or other authorizations for activities, which we cannot control. If we, or the projects or partners we invest in, fail to execute our low carbon energy initiatives as planned, or if execution of such initiatives requires more time and capital than expected, demand for our technologies, services and mineral assets and consequently, our business, results of operations and financial condition could be adversely affected.
Weather-Related Risks
Certain of our operations are seasonal and depend, in part, on weather conditions. In addition, severe weather, including named windstorms, and severe winter weather, can cause damage and disruption to our businesses.
In certain markets, the Water & Flowback Services Division’s onshore water management services can be dependent on adequate water supplies being available to our customers. To the extent severe drought or other weather-related conditions prevent our customers from obtaining needed water, frac water operations may not be possible and our Water & Flowback Services Division business may be negatively affected.
Further, a portion of our operations is susceptible to adverse weather conditions in the Gulf of America, including hurricanes and other extreme weather conditions. Even if we do not experience direct damage from storms, we may experience disruptions in our operations, because we are unable to operate or our customers or suppliers may curtail their activities due to damage to their wells, platforms, pipelines, and facilities. From time to time, our onshore operations are also negatively affected by adverse weather conditions, including sustained rain and flooding. Severe weather during the winter may also have a significant impact on natural gas storage levels and reduce drilling activity and other customer activity substantially.
Financial Risks
The market price of our common stock has been and may continue to be volatile.
The market price of our common stock has fluctuated in the past and is subject to significant fluctuations in response to many factors, some of which are beyond our control, including the following:
•our operational performance;
•supply, demand, and prices of oil and natural gas;
•the activity levels of our customers;
•deviations in our earnings from publicly disclosed forward-looking guidance or analysts’ projections;
•recommendations by research analysts that cover us and other companies in our industry;
•risks related to acquisitions, divestitures and our growth strategy;
•uncertainty about current global economic conditions; and
•other general economic conditions.
During 2024, the closing price for our common stock ranged from a high of $4.93 per share to a low of $2.76 per share. In recent years, the stock market in general has experienced extreme price and volume fluctuations that have affected the market price for companies in industries similar to ours. Some of these fluctuations have been unrelated to operating performance and are attributable, in part, to outside factors such as general economic conditions, including the impact of the ongoing Russia-Ukraine conflict, conflict in the Israel-Gaza region, continued hostilities in the Middle East, maritime piracy attacks, and fear of a global recession. The volatility of our common stock may make it difficult to resell shares of our common stock at attractive prices.
Our long-term debt agreements contain covenants and other provisions that restrict our ability to take certain actions and may limit our ability to operate or grow our business in the future.
As of December 31, 2024, our total long-term debt outstanding of $179.7 million consisted of the carrying amount outstanding under our credit facility. Our credit facility matures in January 2030 and consists of a $190.0 million funded term loan and a $75.0 million delayed-draw term loan (collectively the “Term Credit Agreement”). We also have availability under our Asset-Based Credit Agreement (the “ABL Credit Agreement”), and under our revolving credit facility for seasonal working capital needs of subsidiaries in Sweden (“Swedish Credit Facility”).
The Term Credit Agreement contains certain affirmative and negative covenants, including covenants that restrict the ability of the Company and certain of its subsidiaries to take certain actions including, among other things and subject to certain significant exceptions, the incurrence of debt, the granting of liens, engaging in mergers and other fundamental changes, the making of investments, entering into transactions with affiliates, the payment of dividends and other restricted payments, the prepayment of other indebtedness and the sale of assets. The Term Credit Agreement also requires the Company to maintain a Leverage Ratio (as defined in the new term loan credit agreement) of not more than 4.0 to 1.0 as of the end of each fiscal quarter and Liquidity (as defined in the New Term Credit Agreement) of not less than $50.0 million at all times.
The ABL Credit Agreement contains certain affirmative and negative covenants, including covenants that restrict the ability of TETRA and certain of its subsidiaries to take certain actions including, among other things and subject to certain significant exceptions, incurring debt, granting liens, engaging in mergers and other fundamental changes, making investments, entering into, or amending, transactions with affiliates, paying dividends and making other restricted payments, prepaying other indebtedness and selling assets. The ABL Credit Agreement also contains a provision that may require a fixed charge coverage ratio (as defined in the ABL Credit Agreement) of not less than 1.00 to 1.00 in the event that certain conditions associated with outstanding borrowings and cash availability occur.
Our continuing ability to comply with covenants in our Long-Term Debt Agreements depends largely upon our ability to generate adequate earnings and operating cash flow.
We may not be able to utilize all or a portion of our net operating loss carryforwards or other tax benefits to offset future taxable income for U.S. federal, state or foreign tax purposes, which could adversely affect our financial position, results of operations and cash flows. We have adopted a Tax Benefits Preservation Plan (the “Tax Plan”) that is designed to protect our Tax Attributes.
As of December 31, 2024, we had deferred tax assets associated with federal, state, and foreign net operating loss carryforwards/carrybacks (“NOLs”) equal to approximately $72.4 million, $9.0 million, and $7.7 million, respectively. In those countries and states in which NOLs are subject to an expiration period, our NOLs, if not utilized, will expire at various dates beginning in 2025 through 2043.
We may be limited in the portion of our NOLs that we can use in the future to offset taxable income for United States, federal, state, and foreign income tax purposes. Utilization of these NOLs depends on many factors, including our future taxable income, which cannot be assured and our future assessments may be materially different from the current estimate.
Under Section 382 (“Section 382”) of the Internal Revenue Code of 1986, as amended (the “Code”), if a corporation experiences an “ownership change,” any NOLs, losses or deductions attributable to a “net unrealized built-in loss” and other tax attributes (“Tax Attributes”) could be substantially limited, and timing of the usage of such Tax Attributes could be substantially delayed. A corporation generally will experience an ownership change if one or more stockholders (or group of stockholders) who are each deemed to own at least 5% of the corporation’s stock increase their ownership by more than 50 percentage points over their lowest ownership percentage within a testing period (generally, a rolling three-year period). Utilization of our Tax Attributes may be subject to a significant annual limitation as a result of prior or future “ownership changes.” Determining the limitations under Section 382 is technical and highly complex, and no assurance can be given that, upon further analysis, our ability to take advantage of our NOLs or other Tax Attributes will not be limited to a greater extent than we currently anticipate.
The Board of Directors has adopted the Tax Plan to protect the availability of the Company’s Tax Attributes. The Tax Plan is designed to reduce the likelihood that we experience an ownership change by deterring certain
acquisitions of our common stock. There can be no assurances, however, that the deterrent mechanism will be effective, and, therefore, such acquisitions may still occur. In addition, the Tax Plan could adversely affect the marketability of our common stock by discouraging existing or potential investors from acquiring our common stock or additional shares of our common stock. If the Company is unable to use the Tax Attributes in years in which it has taxable income, the Company will pay significantly more in cash tax than if it were able to utilize the Tax Attributes, and those tax costs would negatively impact the Company’s financial position, results of operations and cash flows.
We have continuing exposure to abandonment and decommissioning obligations associated with oil and gas properties previously owned by Maritech.
From 2001 to 2012, our former subsidiary, Maritech Resources, Inc. (“Maritech”), acquired, produced, and operated various oil and gas properties in the Gulf of America and eventually sold the various oil and gas producing properties in numerous transactions to different buyers. In connection with those sales, the buyers generally assumed the decommissioning liabilities associated with the properties sold (the “Legacy Liabilities”) and generally became the successor operator. In some cases, we provided guaranties of certain liabilities retained by Maritech, and we provided guaranties to the entities which originally sold the properties to Maritech. To the extent that a buyer, or subsequent buyer, of these properties fails to perform the decommissioning work required, Maritech or we may be required to perform operations to satisfy the Legacy Liabilities.
In March 2018, pursuant to a series of transactions, Maritech sold the remaining offshore leases held by Maritech to Orinoco Natural Resources, LLC (“Orinoco”) and, immediately thereafter, we sold all equity interest in Maritech to Orinoco. Under the Maritech Asset Purchase Agreement, Orinoco assumed all of Maritech’s decommissioning liabilities related to the leases conveyed to Orinoco (the “Orinoco Lease Liabilities”) and, under the Maritech Membership Interest Purchase Agreement, Orinoco assumed all other liabilities of Maritech, including the Legacy Liabilities and liabilities pertaining to properties still operated by Maritech, subject to limited exceptions unrelated to the decommissioning liabilities. Pursuant to a Bonding Agreement entered into as part of the Orinoco transactions (the “Bonding Agreement”), Orinoco provided non-revocable performance bonds in an aggregate amount of $46.8 million to cover the Orinoco Lease Liabilities (the “Initial Bonds”) and agreed to replace the Initial Bonds with other non-revocable performance bonds in the aggregate sum of $47.0 million (collectively, the “Replacement Bonds”). In the event Orinoco does not provide the Replacement Bonds, Orinoco is required to make certain cash escrow payments to us. However, as of the date of this report, the Replacement Bonds have not been received and no cash escrow payments have been made. In the event that Orinoco fails to perform, our guarantees may still cover these liabilities. Separately, significant decommissioning liabilities that were assumed by the buyers of the Maritech properties in these previous sales remain unperformed. If these buyers, or any successor owners of the Maritech properties, are unable to satisfy and extinguish their decommissioning liabilities due to bankruptcy or other liquidity issues, the U.S. Department of the Interior may seek to impose those obligations on Maritech and on us. The amount of cash necessary to satisfy these obligations could be significant and, if Maritech or Orinoco is unable to cover any deficiency between any bond payment and the decommissioning liability, we may be liable for a portion of the costs and our financial condition and results of operations may be negatively affected. For example, Maritech is liable, with other third parties, for certain decommissioning obligations in the Gulf of America. While the ultimate outcome of this matter cannot be predicted, we could potentially be liable for an estimated amount in the range of $5.8 million to $19.4 million, depending on the outcome of negotiations and whether other partners or property owners in the chain of title fulfill their respective obligations under their agreements. Such estimates are based on information known to us as of the time of this report and are subject to change.
In addition, Maritech and certain other interest owners have received decommissioning orders from BSEE and could receive additional decommissioning orders in the future. Such decommissioning orders received by Maritech and other interest owners relate to asset retirement obligations for certain properties in the Gulf of America. From time to time, we also receive demand notices from third parties related to certain corporate guarantees or other arrangements covering such decommissioning liabilities. While the ultimate outcome of such matters cannot be predicted at this time, if Maritech or other interest owners default, BSEE or third parties may seek to enforce certain corporate guarantees or third party indemnity agreements against us for a portion of such decommissioning obligations, which may be significant. On February 13, 2025, Arena Energy, LLC filed a complaint in U.S. District Court for the Southern District of Texas seeking indemnification from us and Maritech for decommissioning costs related to a Maritech oil and gas platform in the Gulf of America. We are evaluating the allegations included in the complaint and intend to vigorously defend against the claims brought by Arena Energy, LLC but are presently unable to predict the duration, scope or result of this proceeding.
See Note 11 - “Commitments and Contingencies” in the Notes to Consolidated Financial Statements for further discussion of decommissioning liabilities, the Bonding Agreement, and the process for replacement of the Orinoco bonds.
From time to time the U.S. Department of Interior has sought to impose more stringent supplemental bonding and financial assurance requirements, which may increase our risks associated with the decommissioning obligations pertaining to oil and gas properties previously owned by Maritech.
There has been substantial uncertainty relating to the supplemental bonding and financial assurance program managed by the U.S. Department of the Interior over the past several years. Under prior administrations, the U.S. Department of Interior has sought to require certain oil and gas owners and operators with infrastructure in the Gulf of America to provide additional supplemental bonds or other acceptable financial assurance for decommissioning liabilities. These changes have the potential to adversely impact the financial condition of lease owners and operators in the Gulf of America and increase the number of such owners and operators seeking bankruptcy protection.
For example, in April 2024, BOEM finalized a rulemaking which modified its criteria for determining bonds and financial assurance for offshore oil and gas lessees and other operators, generally imposing more stringent requirements for waiving supplemental bonding requirements. These developments, coupled with recent volatility in the surety market with respect to covering OCS obligations, have the potential to increase operating costs for lease owners and operators in the Gulf of America and reduce the availability of surety bonds due to the increased demands for such bonds.
The U.S. Department of the Interior also increased its estimates for decommissioning liabilities in the Gulf of America, causing the potential need for additional supplemental bonding and/or other financial assurances to be dramatically increased. When coupled with any volatility with respect to the prices of oil and gas, it is difficult to predict the impact of BOEM’s 2024 rule and regulatory changes already promulgated, and any other changes as may be forthcoming by the U.S. Department of the Interior relating to financial assurance for decommissioning liabilities. We cannot predict what actions, if any, and on what timing, the new Administration may take with respect to these matters; however, the ultimate impact of BOEM’s 2024 rule, and other rulemaking, is presently unclear given a recent Executive Order issued by the Trump Administration. Still, any further revisions to the U.S. Department of the Interior’s supplemental bonding requirements that increase their stringency could result in demands for the posting of increased financial assurances by owners and operators in the Gulf of America, including Maritech, Orinoco and the other entities to whom Maritech divested its Gulf of America assets, but such demands cannot be directly placed on us due to the fact that we are only a former parent company of Maritech and are only a guarantor as opposed to an actual lease owner or operator. This may force lease owners and operators of leases and other infrastructure in the Gulf of America to obtain additional surety bonds or other forms of financial assurance, the costs of which could be significant. Moreover, the changes to the bonding and financial assurance program for the Gulf of America (to include loss of supplemental bonding waivers, exceedances of the surety bond market’s ability to meet current demands, and resultant bankruptcies) could increase the risk that we may be required to step in and satisfy remaining decommissioning liabilities of Maritech and any buyer of the Maritech properties, including Orinoco, through our third-party indemnity agreements and private guarantees. Such obligations could be significant and could adversely affect our business, results of operations, financial condition and cash flows.
We are exposed to significant credit risks.
We face credit risk associated with the significant amounts of accounts receivable we have with our customers in the energy industry. Many of our customers, particularly those associated with our onshore operations, are small- to medium-sized oil and gas operators that may be more susceptible to declines in oil and gas commodity prices or generally increased operating expenses than larger companies. Our ability to collect from our customers could be impacted by volatility in the oil and natural gas price environment and we may face increased credit risks if the price of oil were to fall and remain low for an extended period of time.
As discussed in the preceding risk factors, we face the risk of having to satisfy decommissioning liabilities on properties presently or formerly owned by Maritech. Consequently, we face credit risk associated with the ability of these companies to satisfy their decommissioning liabilities. If these companies are unable to satisfy their obligations, it will increase the possibility that we will become liable for such decommissioning obligations in the future.
Our operating results and cash flows for certain of our subsidiaries are subject to foreign currency risk.
The operations of certain of our subsidiaries are exposed to fluctuations between the U.S. dollar and certain foreign currencies, particularly the euro, the British pound, the Brazilian Real, the Argentinian peso and the Mexican peso. Our plans to grow our international operations could cause this exposure from fluctuating currencies to increase. Historically, exchange rates of foreign currencies have fluctuated significantly compared to the U.S. dollar, and this exchange rate volatility is expected to continue. Significant fluctuations in foreign currencies against the U.S. dollar could adversely affect our balance sheet and results of operations.
We are exposed to interest rate risks with regard to our credit facility debt and future refinancing thereof.
As of December 31, 2024, we had $190.0 million principal outstanding under our Term Credit Agreement and no balance outstanding under our ABL Credit Agreement. These credit facilities consist of floating rate loans that bear interest at an agreed upon percentage rate spread above the secured overnight financing rate (“SOFR”) or an alternate base rate. Whenever we have amounts outstanding under our long-term debt agreements and credit facilities, our cash flows and results of operations will be subject to interest rate risk exposure associated with the debt balance outstanding. We currently are not a party to an interest rate swap contract or other derivative instrument designed to hedge our exposure to interest rate fluctuation risk.
Our Term Credit Agreement is scheduled to mature on January 1, 2030 and our ABL Credit Agreement is scheduled to mature on May 13, 2029. There can be no assurance that financial market conditions or borrowing terms at the times these existing debt agreements are renegotiated will be as favorable as the current terms and interest rates. We may be unable to obtain financing in the future for working capital, capital expenditures, acquisitions, debt service requirements, or other purposes.
Legal, Regulatory, and Political Risks
We operate in a highly competitive environment. If we are unable to maintain product and technology leadership, this could adversely affect any competitive advantage we hold.
The industries in which we operate are highly competitive and rapidly evolving. Our business may be adversely affected if we fail to continue developing and producing innovative products and services in response to changes in the market, including customer and government requirements, or if we fail to deliver such products and services to our customers in a timely and cost-competitive manner. If we are unable to maintain products and services leadership in our industries, our ability to maintain market share, defend, maintain, or increase prices for our products and services, and negotiate acceptable contract terms with our customers could be adversely affected. Furthermore, competing or new technologies may accelerate the obsolescence of our products or services and reduce the value of our intellectual property.
Limitations on our ability to obtain, maintain, protect, or enforce our intellectual property rights, including our trade secrets, could cause a loss in revenue and any competitive advantage we hold.
There can be no assurance that the steps we take to obtain, maintain, protect, and enforce our intellectual property rights will be adequate. Some of our products or services, and the processes we use to produce or provide them, have been granted patent protection, have patent applications pending, or are trade secrets. Our business may be adversely affected when our patents are unenforceable, the claims allowed under our patents are not sufficient to protect our technology, our patent applications are denied, or our trade secrets are not adequately protected. Our competitors may also be able to develop technology independently that is similar to ours without infringing on our patents or gaining access to our trade secrets.
Our proprietary rights may be violated or compromised, which could damage our operations. In addition, third parties may claim that we have infringed upon or otherwise violated their intellectual property rights.
We own numerous patents, patent applications, and unpatented trade secret technologies in the U.S. and certain foreign countries. There can be no assurance that the steps we have taken to protect our proprietary rights will be adequate to deter misappropriation of these rights. In addition, independent third parties may develop competitive or superior technologies.
Additionally, the tools, techniques, methodologies, programs, and components we use to provide our services and products may infringe upon or otherwise violate the intellectual property rights of others or be challenged on that basis. Regardless of the merits, any such claims generally result in significant legal and other costs, including reputational harm, and may distract management from running our business. Resolving such claims could increase our costs, including through royalty payments to acquire licenses, if available, from third parties and through the development of replacement technologies. If a license to resolve a claim were not available, we might not be able to continue providing a particular service or product.
Our operations are subject to extensive and evolving U.S. and foreign federal, state, and local laws and regulatory requirements that increase our operating costs and expose us to potential fines, penalties, and litigation.
Laws and regulations govern our operations, including those relating to corporate governance, employees, taxation, fees, importation and exportation restrictions, environmental affairs, health and safety, and the manufacture, storage, handling, transportation, use and sale of chemical products. Certain foreign countries impose additional restrictions on our activities, such as currency restrictions and restrictions on various labor practices. These laws and regulations are becoming increasingly complex and stringent, and compliance is becoming increasingly expensive. Governmental authorities have the power to enforce compliance with these regulations, and violators are subject to civil and criminal penalties, including civil fines, and injunctions. Third parties may also have the right to pursue legal actions to enforce compliance with certain laws and regulations. It is possible that increasingly strict environmental, health and safety laws, regulations, and enforcement policies could result in substantial costs and liabilities to us.
For example, the EPA has asserted federal regulatory authority under the Safe Drinking Water Act Underground Injection Control program over certain hydraulic fracturing activities involving the use of diesel fuels and published permitting guidance for such activities and issued a final regulation under the Clean Water Act prohibiting discharges to publicly owned treatment works of wastewater from onshore unconventional oil and gas facilities. Certain environmental and other groups have suggested that additional federal, state, and local laws and regulations may be needed to more closely regulate the hydraulic fracturing process. Several states have adopted regulations that require operators to disclose the chemical constituents in hydraulic fracturing fluids. We cannot predict whether any foreign, federal, state or local laws or regulations will be enacted regarding hydraulic fracturing, and, if so, what actions any such laws or regulations would require or prohibit. If additional levels of regulation or permitting requirements are imposed on oil and gas operators through the adoption of new laws and regulations, the demand for certain of our products and services could be decreased or subject to delays.
We operate in the U.S. Gulf of America. At this time, we cannot predict the full impact that other regulatory actions that may be mandated by the federal government may have on our operations or the operations of our customers. Other governmental or regulatory actions could further reduce our revenues and increase our operating costs, including the cost to insure offshore operations, resulting in reduced cash flows and profitability.
Our onshore and offshore operations, including operations related to energy storage and carbon capture, utilization, and storage, expose us to risks such as the potential for harmful substances escaping into the environment and causing damages or injuries, which could be substantial. We maintain limited environmental liability insurance covering named locations and environmental risks associated with contract services for oil and gas operations. We could be materially and adversely affected by an enforcement proceeding or a claim that is not covered or is only partially covered by insurance.
Because our business depends on the level of activity in the oil and natural gas industry, existing or future laws, regulations, treaties, or international agreements that impose additional restrictions on the industry may adversely affect our financial results. Regulators are becoming more focused on-air emissions from oil and gas operations, including volatile organic compounds, hazardous air pollutants, and GHGs. In particular, the focus on GHGs and climate change, including incentives to conserve energy or use alternative energy sources, such as those contained in laws like the Inflation Reduction Act (“IRA 2022”), unless amended or otherwise superseded, could have a negative impact on our financial results if such laws, regulations, treaties, or international agreements reduce the worldwide demand for oil and natural gas or otherwise result in reduced economic activity generally. In addition, such laws, regulations, treaties, or international agreements could result in increased compliance costs, capital spending requirements, or additional operating restrictions for us, which may have a negative impact on our financial results.
In addition to increasing our risk of environmental liability, the rigorous enforcement of environmental laws and regulations has accelerated demand for our products and services in some of the markets we serve. For more information on the environmental laws and regulations to which we are subject, see our disclosures titled “Health, Safety, and Environmental Affairs Regulation” set forth in Item 1 of this Annual Report.
The Inflation Reduction Act of 2022 could accelerate the transition to a low carbon economy and could impose new costs on our customers’ operations.
In August 2022, President Biden signed the IRA 2022 into law. The IRA 2022 contains hundreds of billions in incentives for the development of renewable energy, clean hydrogen, clean fuels, electric vehicles and supporting infrastructure and carbon capture and sequestration, amongst other provisions. In addition, the IRA 2022 imposes the first ever federal fee on the emission of greenhouse gases through a methane emissions charge. The IRA 2022 amends the federal Clean Air Act to impose a fee on the emission of methane from sources required to report their GHG emissions to the U.S. Environmental Protection Agency (“EPA”), including those sources in the onshore petroleum and natural gas production and gathering and boosting source categories. The methane emissions charge began in calendar year 2024 at $900 per ton of methane, increases to $1,200 in 2025, and will be set at $1,500 for 2026 and each year after. Calculation of the fee is based on certain thresholds established in the IRA 2022. While the tax incentives created by the IRA for carbon capture and sequestration may increase demand for some of the services we provide as part of our low carbon solutions business, the methane charge imposed on our oil and natural gas customers could further accelerate the transition of the economy away from the use of fossil fuels towards lower- or zero-carbon emissions alternatives. We cannot predict whether, how, or when the incoming Trump administration might take action to revise or repeal the methane emissions charge. Additionally, Congress may take actions to repeal or revise the IRA, including with respect to the methane emissions charge, which timing or outcome similarly cannot be predicted. To the extent that the methane emissions charge is implemented as originally promulgated, it could decrease demand for oil and gas and consequently adversely affect the business of our customers, thereby reducing demand for our other services.
Our operations, and those of our suppliers and customers, are subject to a series of risks arising from climate change.
The threat of climate change continues to attract considerable attention in the United States and in foreign countries. As a result, our operations as well as the operations of our oil and natural gas exploration and production customers and our suppliers are subject to a series of regulatory, political, litigation, and financial risks associated with the production and processing of fossil fuels and emission of GHGs.
In the United States, no comprehensive climate change legislation has been implemented at the federal level, though laws such as the IRA 2022 advance numerous climate-related objectives. Following the U.S. Supreme Court finding that GHG emissions constitute a pollutant under the CAA, the EPA adopted regulations that, among other things, established construction and operating permit reviews for GHG emissions from certain large stationary sources, required the monitoring and annual reporting of GHG emissions from certain petroleum and natural gas system sources in the United States, and together with the DOT, implemented GHG emissions limits on vehicles manufactured for operation in the United States. However, from time to time certain administrations have taken actions to repeal or revise such climate-related actions. For example, the regulation of methane from oil and gas facilities has been subject to uncertainty in recent years. For more information, see our disclosures titled “The Inflation Reduction Act of 2022 could accelerate the transition to a low carbon economy and could impose new costs on our customers’ operations.” Given the long-term trend toward increasing regulation, further federal GHG regulations of the oil and gas industry remain a significant possibility. For more information, see our disclosures titled “Health, Safety, and Environmental Affairs Regulation” set forth in Item 1 of this Annual Report. Moreover, certain international jurisdictions continue to impose more stringent regulations with respect to GHGs, and other stakeholders may pressure us or our customers to take additional action beyond any applicable regulatory requirements.
Separately, various states and groups of states have adopted or are considering adopting legislation, regulation or other regulatory initiatives that are focused on such areas as GHG cap and trade programs, carbon taxes, reporting and tracking programs, and restriction of emissions. At the international level, in 2021, the U.S. rejoined the Paris Agreement, which requires member nations to submit non-binding GHG emissions reduction goals every five years. However, on January 20, 2025, President Trump signed an Executive Order withdrawing the United States from the Paris Agreement and from any other commitments made by the United Nations Framework Convention on Climate Change. Additionally, President Trump revoked any purported financial commitment made by the United States pursuant to the same, The full impact of these actions is uncertain at this time.
Governmental, scientific, and public concern over the threat of climate change arising from GHG emissions has resulted in increasing political risks in the United States. Litigation risks are also increasing as a number of parties have sought to bring suit against oil and natural gas companies in state or federal court, alleging among other things, that such companies created public nuisances by producing fuels that contributed to climate change or alleging that the companies have been aware of the adverse effects of climate change for some time but defrauded their investors or customers by failing to adequately disclose those impacts. There is also a growing trend of parties suing public companies for “greenwashing,” which is where a company makes unsubstantiated statements designed to mislead consumers or shareholders into thinking that the company’s products or practices are more environmentally friendly than they are.
There have also recently been increasing financial risks for companies in the fossil fuel sector as certain shareholders currently invested in such companies may elect in the future to shift some or all of their investments into other sectors. Institutional lenders who provide financing to fossil fuel energy companies also have become more attentive to sustainable lending practices and some of them may elect not to provide funding for fossil fuel energy companies or seek to require more aggressive action with respect to climate-related risks, although this trend has waned recently and several high-profile banks and institutional investors have withdrawn from various associations that aim to limit financing of industries that emit significant GHG emissions. Limitation of investments in and financing for fossil fuel energy companies could result in the restriction, delay or cancellation of drilling programs or development or production activities, which could reduce demand for our products and services. Additionally, the Securities and Exchange Commission published a final rule in March 2024 that would require registrants to make certain climate-related disclosures, including any climate targets and goals, and data on Scope 1 and 2 GHG emissions. However, the future of the rule is uncertain at this time given that its implementation has been stayed pending the outcome of legal challenges; moreover, on February 11, 2025, SEC Acting Chairman Mark T. Uyeda requested that the U.S. Court of Appeals for the Eighth Circuit not schedule argument in the case while the Commission reconsiders the final rule. The Commission under the current administration may seek to repeal or otherwise modify the rule, though we cannot predict whether such action will occur or its timings. Several states have also enacted or are considering enhanced climate-related disclosure requirements. While we cannot predict the final form or substance of these various rules, this may result in additional costs to comply with any such disclosure requirements. Additionally, we cannot predict how financial institutions and investors might consider information disclosed under such rules, and as a result it is possible that we could face increases with respect to the costs of, or restrictions imposed on, our access to capital.
The adoption and implementation of new or more stringent international, federal or state legislation, regulations or other regulatory initiatives that impose more stringent standards for GHG emissions from the oil and natural gas sector or otherwise restrict the areas in which this sector may produce oil and natural gas or generate the GHG emissions could result in increased costs of compliance or costs of consuming, and thereby reduce demand for oil and natural gas, which could reduce demand for our products and services. Additionally, political, litigation and financial risks may result in our oil and natural gas operators restricting or cancelling production activities, incurring liability for infrastructure damages as a result of climatic changes, or impairing their ability to continue to operate in an economic manner, which also could reduce the demand for our products and services. Actions taken on the federal, state or local levels to ban, limit, or restrict products that rely on oil or natural gas could also reduce demand for our products and services. One or more of these developments could have a material adverse effect on our business, financial condition and results of operation.
Climate change may also result in various physical risks, such as the increased frequency or intensity of extreme weather events or changes in meteorological and hydrological patterns, that could adversely impact us, our customers’, and our suppliers’ operations. Such physical risks may result in damage to our customers’ facilities or infrastructure, or otherwise adversely impact their operations, such as if they become subject to water use curtailments in response to drought, or demand for their products, such as to the extent warmer winters reduce the demand for energy for heating purposes, which may ultimately reduce demand for the products and services we provide. Such physical risks may also impact our suppliers, which may adversely affect our ability to provide our products and services.
Increased attention to ESG matters and conservation measures may adversely impact our or our customers’ business.
Increasing attention to, and societal expectations on companies to address, climate change and other environmental and social impacts, investor, regulatory and societal expectations regarding voluntary and mandatory ESG-related disclosures, and consumer demand for alternative forms of energy may result in increased costs, reduced demand for our customers’ products, reduced profits, increased investigations and litigation, and negative impacts on our stock price and reduced access to capital markets. Increased attention to climate change and
environmental conservation, for example, may result in demand shifts for oil and natural gas products and additional governmental investigations and private litigation against us or our customers. To the extent that societal pressures, regulatory, political or other factors are involved, it is possible that such liability could be imposed without regard to our causation of or contribution to the asserted damage, or to other mitigating factors. While the extent of these pressures may change from time to time, we cannot predict the ultimate impact they may have in the near, mid or long-term on our operations. For more information, see our risk factor titled “Our operations, and those of our suppliers and customers, are subject to a series of risks arising from climate change.”
Moreover, while we may create and publish voluntary disclosures regarding ESG matters from time to time, certain statements in those voluntary disclosures may be based on expectations and assumptions and hypothetical scenarios that may or may not be representative of current or actual risks or events or forecasts of expected risks or events, including the costs associated therewith. Mandatory ESG-related disclosure is also emerging as an area where we may be, subject to required disclosures in certain jurisdictions, and any such mandatory disclosures may similarly necessitate the use of hypothetical, projected or estimated data, some of which is not controlled by us and is inherently subject to imprecision. Disclosures reliant upon such expectations and assumptions and hypothetical scenarios are necessarily uncertain and may be prone to error or subject to misinterpretation given the long timelines involved and the lack of an established single approach to identifying, measuring and reporting on many ESG matters. Additionally, we may announce various targets or product and service offerings in an attempt to improve our ESG profile, which are often aspirational. However, we cannot guarantee that we will be able to meet any such targets or that such targets or offerings will have the intended results on our ESG profile, including but not limited to any unforeseen costs, consequences, changes to relevant accounting methodologies or technical difficulties associated with such targets or offerings. Also, despite any voluntary actions, we may receive pressure from certain investors, lenders, or other groups to adopt more aggressive climate or other ESG-related goals or policies, but we cannot guarantee that we will be able to pursue or implement such goals because of potential costs or technical or operational obstacles.
Furthermore, our reputation, as well as our stakeholder relationships, could be adversely impacted as a result of, among other things, any failure to meet our ESG plans or goals or stakeholder perceptions of statements made by us, our employees and executives, agents, or other third parties or public pressure from investors or policy groups to change our policies. Certain statements with respect to ESG matters are becoming increasingly subject to heightened scrutiny from public and governmental authorities, as well as other parties, related to the risk of potential “greenwashing.” For example, the SEC has recently taken enforcement action against companies for ESG-related misconduct, including greenwashing. Certain regulators, such as the SEC and various state agencies, as well as non-governmental organizations and other private actors have also filed lawsuits under various securities and consumer protection laws alleging that certain ESG-statements, goals or standards were misleading, false or otherwise deceptive. Additionally, certain employment practices and social initiatives are the subject of scrutiny by both those calling for the continued advancement of such policies, as well as those who believe they should be curbed, including government actors, and the complex regulatory and legal frameworks applicable to such initiatives continue to evolve. We cannot be certain of the impact of such regulatory, legal and other developments on our business. More recent political developments could mean that the Company faces increasing criticism or litigation risks from certain “anti-ESG” parties, including various governmental agencies. Such sentiment may focus on the Company’s environmental commitments (such as reducing GHG emissions) or its pursuit of certain employment practices or social initiatives that are alleged to be political or polarizing in nature or are alleged to violate laws based, in part, on changing priorities of, or interpretations by, federal agencies or state governments. Consideration of ESG-related factors in the Company’s decision-making could be subject to increasing scrutiny and objection from such anti-ESG parties. As a result, we may face increased litigation risks from private parties and governmental authorities related to our ESG efforts. Moreover, any alleged claims of greenwashing against us or others in our industry may lead to negative sentiment towards our company or industry. To the extent that we are unable to respond timely and appropriately to any negative publicity, our reputation could be harmed. Damage to our overall reputation could have a negative impact on our financial results and require additional resources to rebuild our reputation.
In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to ESG matters. Such ratings may be used by some investors to inform their investment and voting decisions. While such ratings do not impact all investors’ investment or voting decisions, unfavorable ESG ratings and recent activism directed at shifting funding away from companies with energy-related assets could lead to increased negative investor sentiment toward us and our industry and to the diversion of investment to other industries, which could have a negative impact on our stock price and our access to and costs of capital. Additionally, to the extent ESG matters negatively impact our
reputation, we may not be able to compete as effectively to recruit or retain employees, which may adversely affect our operations.
Such ESG matters may also impact our customers, which may result in reduced demand for certain of our products and services. We also cannot guarantee that any new product or service offerings we develop in light of ESG matters, including but not limited to the energy transition, will be suitable for our customers’ business operations. To the extent alternative technologies are preferred, whether as a result of regulatory impacts, technological developments, or changes in industry practice, it may adversely impact our business or results of operation.
Our operations in foreign countries expose us to complex regulations and may present us with new obstacles to growth.
We plan to continue to grow both in the United States and in foreign countries. We have established operations in Argentina, Brazil, Finland, Ghana, Norway, Saudi Arabia, Sweden, and the United Kingdom, as well as other foreign countries. Foreign operations carry special risks. Our business in the countries in which we currently operate and those in which we may operate in the future could be limited or disrupted by:
•restrictions on repatriating cash back to the United States;
•the impact of compliance with anti-corruption laws on our operations and competitive position in affected countries and the risk that actions taken by us or our agents may violate those laws;
•government controls and government actions, such as expropriation of assets and changes in legal and regulatory environments;
•import and export license requirements;
•political, social, or economic instability;
•trade restrictions;
•changes in tariffs, which could impact raw material prices and the cost of component parts, and taxes; and
•our limited knowledge of these markets or our inability to protect our interests.
We and our affiliates operate in countries where governmental corruption has been known to exist. While we and our subsidiaries are committed to conducting business in a legal and ethical manner, there is a risk of violating the U.S. Foreign Corrupt Practices Act, the U.K Bribery Act, or laws or legislation promulgated pursuant to the 1997 OECD Convention on Combating Bribery of Foreign Public Officials in International Business Transactions or other applicable anti-corruption regulations that generally prohibit the making of improper payments to foreign officials for the purpose of obtaining or keeping business. Violation of these laws could result in monetary penalties against us or our subsidiaries and could damage our reputation and our ability to do business.
Foreign governments and agencies often establish permit and regulatory standards different from those in the U.S. If we cannot obtain foreign regulatory approvals, or if we cannot obtain them in a timely manner, our growth and profitability from foreign operations could be adversely affected.
Regulatory initiatives related to hydraulic fracturing or operations on public lands in the countries where we and our customers operate could result in operating restrictions or delays in the completion of oil and gas wells that may reduce demand for our services.
Although we do not directly engage in hydraulic fracturing, our operations support many of our exploration and production customers in such activities. 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 and state agencies and local municipalities.
Hydraulic fracturing typically is regulated by state oil and gas commissions or similar state agencies, but several federal agencies have asserted regulatory authority over certain aspects of the process in the U.S. For example, the EPA has issued rulemakings under several laws governing hydraulic fracturing activities and disposal of wastes associated with the process. In addition, from time to time certain administrations have taken steps to limit hydraulic fracturing specifically or oil and gas production more broadly on U.S. federal lands. For example, President Biden previously issued an executive order that effectively paused new leasing activities for oil and gas exploration and production on non-Indian federal lands and offshore waters pending completion of a comprehensive
review and reconsideration of federal oil and gas permitting and leasing practices that take into consideration potential climate and other impacts associated with oil and gas activities on such lands and waters. Although the federal court for the Western District of Louisiana issued a permanent injunction against the leasing pause, in response to the executive order, the Department of Interior issued a report recommending various changes to the federal leasing program, though many such changes would require Congressional action. In April 2024, the Bureau of Land Management finalized a rule that reduces the waste of natural gas from venting, flaring and leaks from well sites on federal lands, as well as allows the delay or denial of permits if the Bureau finds that an operator’s methane waste minimization plan is insufficient. This rule is currently subject to litigation and halted in certain states. Additionally, also in April 2024, the Bureau finalized a rule updating the fiscal terms of federal oil and gas leases, increasing fees, rents, royalties, and bonding requirements. Most recently, in January 2025, President Biden announced executive action under the Outer Continental Shelf Lands Act prohibiting all future oil and natural gas leasing in the U.S. Outer Continental Shelf areas off the East and West coasts, the eastern Gulf of America, and portions of the Northern Bering Sea in Alaska However, President Trump, on his first day in office, revoked the Executive Order regarding withdrawal of leasing in the Northern Bering Sea and signed a new Executive Order promoting the expediting of permitting and leasing in Alaska as well as the development and production of the natural resources located in the state. At this time, it is still unclear the extent to which these actions may impact our operations or the operations of customers.
At the state level, some states, including Texas, Oklahoma and New Mexico, have adopted, and other states are considering adopting legal requirements that could impose new or more stringent permitting, public disclosure, or well construction requirements on hydraulic fracturing activities. States could elect to prohibit high volume hydraulic fracturing altogether. Local governments also may seek to adopt ordinances within their jurisdictions regulating the time, place and manner of drilling activities in general or hydraulic fracturing activities in particular. For example, from time to time states such as Texas and Oklahoma have suspended permitting for disposal wells in certain areas in response to seismic activity. If new or more stringent federal, state, or local legal restrictions relating to the hydraulic fracturing process are adopted, our customers could incur potentially significant added costs to comply with such requirements, experience delays or curtailment in the pursuit of exploration, development or production activities, and perhaps even be precluded from drilling wells.
Increased regulation and attention given to the hydraulic fracturing process or oil and gas operations on federal lands could lead to greater opposition to oil and gas production activities using hydraulic fracturing techniques. Additional legislation or regulation could also lead to operational delays or increased operating costs for our customers in the production of oil and gas, including from the developing shale plays, or could make it more difficult to perform hydraulic fracturing or otherwise operate on federal lands. The adoption of any federal, state or local laws or the implementation of additional regulations regarding hydraulic fracturing or oil and gas operations on federal lands could potentially cause a decrease in the completion of new oil and gas wells and an associated decrease in demand for our services and increased compliance costs and time, which could have a material adverse effect on our liquidity, consolidated results of operations, and consolidated financial condition.
Our operations, reputation, and financial condition may be impaired if our information or operational technology systems fail to perform adequately or if we are the subject of a data breach or cyberattack.
Our information and operational technology systems are critically important to operating our business. We rely on our information and operational technology systems to manage our business data, communications, supply chain, customer invoicing, employee information, and other business processes. We outsource certain business process functions to third-party providers and similarly rely on these third parties to maintain and store confidential information on their systems. The failure of these information technology systems to perform as we anticipate could disrupt our business and could result in transaction errors, processing inefficiencies, and the loss of sales and customers, causing our business and results of operations to suffer.
Although we allocate significant resources to protect our information technology systems, we have experienced varying degrees of cyber-incidents in the normal conduct of our business, including viruses, worms, other destructive software, process breakdowns, phishing and other malicious activities. On January 6, 2020, the Department of Homeland Security issued a public warning that indicated companies in the energy industry might be specific targets of cybersecurity threats. Such breaches have in the past and could again in the future result in unauthorized access to information including customer, supplier, employee, or other company confidential data. We do carry insurance against these risks, although the potential damages we might incur could exceed our available insurance coverage. We also invest in security technology, perform penetration tests from time to time, and design our business processes to attempt to mitigate the risk of such breaches.
However, there can be no assurance that future security breaches will not occur. Our facilities and systems, and those of our third-party service providers, have been and are vulnerable to security breaches, computer viruses, lost or misplaced data, programming errors, scams, burglary, human errors, acts of vandalism, misdirected wire transfers, or other malicious or criminal activities. These threats and incidents may originate from a variety of sources, including hackers, cybercriminals, nation-states, insiders, or other third parties.
Moreover, the development and maintenance of these measures requires continuous monitoring as technologies change and efforts to overcome security measures evolve. Cyberattacks in particular are evolving and have increased in frequency. Cyberattacks are becoming more sophisticated and include, but are not limited to, ransomware attacks, credential stuffing, spear phishing, social engineering, use of deepfakes (i.e., highly realistic synthetic media generated by artificial intelligence) and other attempts to gain unauthorized access to data for purposes of extortion or other malfeasance.
We have experienced and expect to continue to experience, cyber security threats and incidents, though as of the date of this Annual Report, we are not aware of any previous cybersecurity threats that have materially affected or are reasonably likely to materially affect the Company. However, a successful breach or attack could have a material negative impact on our operations or business reputation and subject us to consequences such as litigation costs, regulatory fines, remediation costs, and direct costs associated with incident response. No security measure is infallible.
Changes to applicable tax laws and regulations or exposure to additional income tax liabilities could affect our business and future profitability.
We are subject to various complex and evolving U.S. federal, state, and local and non-U.S. taxes. Our business and future profitability could be affected by numerous factors, including the availability of tax credits, exemptions, refunds and other benefits to reduce our tax liabilities, changes in the relative amount of our earnings subject to tax in the various jurisdictions in which we operate or have subsidiaries, the potential expansion of our business into or otherwise becoming subject to tax in additional jurisdictions, changes to our existing business structure and operations, the extent of our intercompany transactions, and the extent to which taxing authorities in the relevant jurisdictions respect those intercompany transactions.
Further, U.S. federal, state, and local and non-U.S. tax laws, policies, statutes, rules, regulations, or ordinances could be interpreted, changed, modified, or applied adversely to us, in each case, possibly with retroactive effect, and may have an adverse effect on our business and future profitability.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
Item 1B. Unresolved Staff Comments.
Not applicable.

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ITEM 2. PROPERTIES
Item 2. Properties.
Our facilities consist primarily of our corporate headquarters facility, chemical plants, processing plants and distribution facilities. We believe our facilities are adequate for our present needs. We also hold brine leases on acreage which contains bromine and lithium. The following information describes facilities that we (i) leased or owned and (ii) leased acreage as of December 31, 2024.
Facilities
Completion Fluids & Products Division
Our Completion Fluids & Products Division facilities include six operating chemical production plants located in the states of Arkansas, California, Louisiana, and West Virginia, and the country of Finland, having a total production capacity of more than 1.1 million equivalent liquid tons per year. The two California locations consist of 29 square miles of leased mineral acreage and solar evaporation ponds, and related owned production and storage facilities. Our facilities also include a fluids plant in Brazil serving deepwater and ultra-deepwater operations in the South Atlantic. The facility provides engineering, testing, blending, filtration, and storage for the full line of TETRA fluids, including clear-brine and zinc-free/formate-free fluids, as well as chemical additives.
In addition to the production facilities described above, the Completion Fluids & Products Division owns or leases multiple service center facilities in the United States and in other countries. The Completion Fluids & Products Division also leases several offices and numerous terminal locations in the United States and in other countries.
Water & Flowback Services Division
The Water & Flowback Services Division conducts its operations through production testing and water management service centers (most of which are leased) in the United States, located in Louisiana, New Mexico, Oklahoma, Pennsylvania and Texas. In addition, the Water & Flowback Services Division has leased facilities in certain countries in Latin America, Europe, and the Middle East.
Corporate
Our headquarters is located in The Woodlands, Texas, in a 153,000 square foot office building, which is located on 2.6 acres of land, under a lease that expires in 2027. In addition, we own a 28,000 square foot technical facility in The Woodlands, Texas, to service our Completion Fluids & Products and Water & Flowback Services Divisions’ operations.
Bromine and Lithium Resources
Our Completion Fluids & Products Division leases approximately 40,000 gross acres of brine leases in Magnolia, Arkansas, which contain bromine and lithium. This acreage is leased for possible future development and as a source of supply for our bromine and other raw materials. We have rights to the brine, including rights to the bromine and lithium contained in the brine underlying this acreage, pursuant to certain brine leases and brine deeds with various landowners. With respect to approximately 35,000 gross acres of that total acreage, we had previously entered into an agreement granting Standard Lithium an option to acquire the lithium rights in that acreage located outside of the Evergreen Brine Unit. The agreements governing this option contemplate a 2.5% royalty that
Standard Lithium would pay us based on gross lithium revenues. Standard Lithium delivered a notice to exercise this option to acquire lithium rights in the optioned acreage on October 6, 2023.
Since acquiring this acreage, we have engaged in various exploratory activities with respect to our brine leases. In 2024, we continued to follow up on prior exploration work regarding bromine and lithium materials that may be present in our approximately 40,000 gross acres of brine leases in the Smackover Formation in Southwest Arkansas. Building on an earlier maiden inferred bromine and brine resource estimation report from the third quarter of 2022 for this area, we completed a report for our Evergreen Brine Unit in Arkansas in January 2024 that identified proven and probable bromine reserves, and both “measured,” and “indicated” and “inferred” resources of bromine and lithium. Later, in August 2024, we announced the completion of a definitive feasibility study and an updated technical resources report (the “Resources Report”) for our Evergreen Brine Unit. The Resources Report updated the amounts previously reported in our January report issued in 2024 and incorporates the results of the definitive feasibility study, including bromine reserve determinations. The Company is continuing to evaluate these assets and has not made any final decisions about whether to proceed to development stages but is instead still focusing on sampling and analysis and the consideration of the financial implications of proceeding to commence operations to produce these materials.
In June 2023, we entered into the MOU with Saltwerx, LLC, an indirect wholly owned subsidiary of ExxonMobil Corporation, relating to a newly-proposed brine unit in the Smackover Formation in Southwest Arkansas (the “Evergreen Brine Unit”) and potential bromine and lithium production from brine produced from the unit. We filed an amended unit application with the Arkansas Oil and Gas Commission (“AOGC”) covering approximately 6,138 acres, which combines brine acreage that is leased by each of TETRA and Saltwerx. On September 26, 2023, the AOGC held a public hearing and unanimously approved our application to establish the Evergreen Brine Unit. On October 17, 2023, the AOGC issued formal orders establishing the Evergreen Brine Unit and integrating all unleased owners within the Evergreen Brine Unit, subject to a 60-day statutory election period for each unleased party to elect whether or not to participate and share in costs of development of the Evergreen Brine Unit. The 60-day statutory election period expired on December 16, 2023 and such unleased parties were deemed integrated within the Evergreen Brine Unit as described in the formal orders. While bromine can be commercially extracted, among other events that must take place before we can commercially produce lithium from the Evergreen Brine Unit, the AOGC will need to establish an agreeable lithium royalty.
The MOU with Saltwerx includes provisions relating to: (i) initial brine ownership percentages within the Evergreen Brine Unit, including the bromine and lithium contained in the brine, (ii) the transfer of certain leased acres outside the proposed Evergreen Brine Unit from us to Saltwerx, (iii) reimbursement by Saltwerx of certain expenses that we incurred for the development of leased acreage to be included in the Evergreen Brine Unit, and (iv) an allocation of certain future costs for the drilling of a brine production test well and other development operations, including front-end engineering and design studies for bromine and lithium production facilities. Unless and until we finalize any contractual agreements with Saltwerx, including a joint venture agreement, our relationship with Saltwerx will be governed by the MOU and the Unit Operating Agreement and there can be no assurance that we will agree to terms beyond those of the MOU and the Unit Operating Agreement.
The basis for the lithium and bromine resources is that hypersaline formation water, or brine, associated with some of the world’s oilfields and/or geothermal fields contains confined reservoirs, or aquifers, that are known to contain anomalous concentrations of lithium, bromine and other elements of interest. We propose to assess stratigraphically deep (more than 2,250 meters or 7,450 feet below surface) brine from oil and gas aquifers associated with the Late Jurassic Smackover Formation. The brine is currently pumped from the aquifer to the earth’s surface as a wastewater product associated with hydrocarbon production (e.g., oil, gas, and condensate). We expect that we will be able to develop or utilize evolving commercial technologies to economically remove the bromine and lithium from the brine underlying our acreage before the brine is reinjected back down into the
subsurface aquifer but whether we will ultimately be able to economically remove the bromine and lithium materials will depend on the outcome of further studies.
Any effort to pursue the extraction of lithium and bromine from these brine leases would likely require a significant amount of time and capital, which may exceed current estimates. While we have completed a definitive feasibility study with respect to bromine and an updated technical resources report for our Evergreen Brine Unit, we must also complete a lithium FEED study and a feasibility study for our lithium acreage and validate the lithium technologies used in order to be in a position to determine whether to proceed. Should any such decision be made to pursue the development of either one or both of these materials, it would also be necessary to obtain permits for our extraction activities which could be subject to delays or onerous conditions, as well as finalize any contractual agreements with our potential joint venture partner, Saltwerx. Long term, we believe that lithium prices will rebound to levels that support increased investment in supply, especially from the United States, and we and our Evergreen Unit partner remain focused on completing all the engineering studies required to define the lithium project economics. Once these studies are completed, any future investments in our lithium initiatives will be evaluated at that time and subject to reaching agreement with our Evergreen Unit partner.

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ITEM 3. LEGAL PROCEEDINGS
Item 3. Legal Proceedings.
We are named defendants in numerous lawsuits and respondents in certain governmental proceedings arising in the ordinary course of business. While the outcome of lawsuits or other proceedings against us cannot be predicted with certainty, management does not consider it reasonably possible that a loss resulting from such lawsuits or other proceedings in excess of any amounts accrued has been incurred that is expected to have a material adverse effect on our financial condition, results of operations or liquidity. See Note 11 - “Commitments and Contingencies” in the Notes to Consolidated Financial Statements for further information.

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ITEM 4. MINE SAFETY DISCLOSURE
Item 4. Mine Safety Disclosures.
None.
PART II

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ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Repurchases of Equity Securities.
Common Stock
Our common stock is traded on the New York Stock Exchange under the symbol “TTI.” As of February 24, 2025, there were approximately 200 holders of record of the common stock. The actual number of holders of our common stock is greater than this number of record holders and includes common stockholders who are beneficial owners but whose shares are held in street name by banks, brokers, and other nominees.
Market Price of Common Stock
The following graph compares the five-year cumulative total returns of our common stock, the Russell 2000 Index (“Russell 2000”), the Philadelphia Oil Service Sector Index (“PHLX Oil Service”) and a Peer Group Total Stock Return (“Peer Group TSR”), assuming $100 invested in each stock, index or group on December 31, 2019, all dividends reinvested, and a fiscal year ending December 31st. The Peer Group consists of Core Laboratories, Inc., Expro Group Holdings N.V., Flotek Industries, Inc., Forum Energy Technologies, Inc., Hawkins, Inc., KLX Energy Services Holdings, Inc., Mammoth Energy Services, Inc., National Energy Services Reunited Corp, Newpark Resources, Inc., Nine Energy Service, Inc., Oil States International, Inc., Ranger Energy Services, Inc., RPC, Inc., and Select Water Solutions, Inc., with each company equally weighted. The Peer Group includes peer companies selected to measure our relative total shareholder return under our long-term incentive awards and were publicly traded during the entire period of the stock performance graph. This information shall be deemed furnished, and not filed, in this Form 10-K and shall not be deemed incorporated by reference into any filing under the Securities Act of 1933 or the Securities Exchange Act of 1934 as a result of this furnishing, except to the extent we specifically incorporate it by reference.
Securities Authorized for Issuance Under Equity Compensation Plans
For additional information about common stock authorized for issuance under equity compensation plans, see Note 13 - “Equity-Based Compensation and Other” in the Notes to Consolidated Financial Statements.

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ITEM 6. SELECTED FINANCIAL DATA
Item 6. [Reserved]

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ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
The following discussion is intended to analyze major elements of our consolidated financial statements and provide insight into important areas of management’s focus. This section should be read in conjunction with the Consolidated Financial Statements and the accompanying Notes included elsewhere in this Annual Report. Statements in the following discussion may include forward-looking statements. These forward-looking statements involve risks and uncertainties. See “Item 1A. Risk Factors” for additional discussion of these factors and risks. For discussion of 2023 compared to 2022, see disclosures titled “Results of Operations” set forth in Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations of our Annual Report on Form 10-K for the year ended December 31, 2023 filed with the SEC on February 27, 2024.
Business Overview
We are an energy services and solutions company with operations on six continents focused on developing environmentally conscious services and solutions that help make people’s lives better. Calcium chloride is used in the oil and gas industry, and also has broad industrial applications to the agricultural, road, food and beverage, and lithium production markets. We operate through two reporting segments - Completion Fluids & Products Division and Water & Flowback Services Division.
Completion Fluids & Products Division activity for 2024 decreased slightly compared to 2023. We were awarded a three-well TETRA CS Neptune fluids project in the Gulf of America that is expected to begin in the first quarter of 2025. TETRA CS Neptune fluids projects are historically higher revenue and margin projects. We also recently secured a significant multi-well, multi-year deep water completion fluids contract in Brazil.
Our Water & Flowback Services Division activity also decreased compared to 2023 reflecting a slowdown in onshore activity in the Unites States and lower offshore completions fluids activity, as well as lower service revenues following the sale of early production facilities in Latin America. We initiated a series of cost reduction actions in the second half of 2024 to adjust to market levels.
We are committed to pursuing low-carbon energy initiatives that leverage our fluids and aqueous chemistry core competencies, our significant bromine and lithium assets and technologies, and our leading calcium chloride production capabilities. In August 2024, we published a definitive feasibility study and updated technical resources report with respect to bromine from our Evergreen Brine Unit. We have ongoing negotiations with various bromine providers for bridging supply agreements that, if and when finalized, will give us flexibility on the timing of a plant start-up, allowing us to accumulate additional cash from our base business. These initiatives are expected to provide us the volumes necessary for the growing deepwater market plus the growing long-duration battery requirements, while deferring investments in Arkansas or scaling up our bromine production at lower levels than previously anticipated. If and when the bridging supply agreement is finalized, we will announce our revised Arkansas investment and timing plans.
We are prioritizing our strategic investments on projects that can immediately impact our near-term results, with a focus on TETRA CS Neptune fluids in the Gulf of America, TETRA PureFlow+ electrolyte shipments to Eos Energy Enterprises, and further advancing our water desalination commercial pilot units that are expected to subsequently transition into long-term contracts for commercial desalination plants.
Results of Operations
The following data should be read in conjunction with the Consolidated Financial Statements and the associated Notes contained elsewhere in this report.
Consolidated Comparisons
Year Ended
December 31, Period to Period Change
2024 2023 2024 vs. 2023 % Change
(In Thousands, Except Percentages)
Revenues $ 599,111 $ 626,262 $ (27,151) (4.3) %
Gross profit 139,853 153,645 (13,792) (9.0) %
Gross profit as a percentage of revenue
23.3 % 24.5 %
Exploration and pre-development costs - 12,119 (12,119) (100.0) %
General and administrative expense 89,969 96,590 (6,621) (6.9) %
General and administrative expense as a percentage of revenue
15.0 % 15.4 %
Interest expense, net 22,465 22,349 116 0.5 %
Loss on debt extinguishment
5,535 - 5,535 100.0 %
Other income, net (6,858) (9,112) 2,254 (24.7) %
Income before taxes and discontinued operations
28,742 31,699 (2,957) (9.3) %
Income before taxes and discontinued operations as a percentage of revenue
4.8 % 5.1 %
Provision (benefit) for income taxes
(84,878) 6,220 (91,098) NM(1)
Income before discontinued operations
113,620 25,479 88,141 345.9 %
Income (loss) from discontinued operations, net of taxes
(5,340) 278 (5,618) NM(1)
Net income 108,280 25,757 82,523 320.4 %
Loss attributable to noncontrolling interest
4 27 (23) (85.2) %
Net income attributable to TETRA stockholders $ 108,284 $ 25,784 $ 82,500 320.0 %
(1) Percent change is not meaningful
Revenues
Consolidated revenues for 2024 decreased compared to the prior year due to lower activity in both our Completion Fluids & Products and Water & Flowback Services divisions, where revenue decreased by $1.7 million and $25.4 million, respectively. The decrease in our Completion Fluids & Products division is primarily due to lower completion fluid sales volumes from international markets. The decrease in our Water & Flowback Services division is primarily from an overall decline in the US market for our production testing and water management services. See Divisional Comparisons section below for a more detailed discussion of the change in our revenues.
Gross Profit
Consolidated gross profit as a percentage of revenue decreased slightly due to a decrease in revenue, an increase in operating costs and the effect of changes in product mix. See Divisional Comparisons section below for additional discussion.
Exploration and Pre-Development Costs
Exploration and pre-development costs decreased $12.1 million compared to the prior year due to the capitalization of costs beginning in January 2024 following project developments, including the completion of a technical resources report, compared to expensing of costs associated with the front-end engineering and design study and appraisal costs associated with the activity in the prior year.
General and Administrative Expense
Consolidated general and administrative expenses decreased during 2024 compared to the prior year primarily due to a $7.4 million decrease in employee compensation from a reduction in equity-based compensation expense and incentive compensation as a result of lower operational margin performance.
Loss on Early Extinguishment of Debt
Consolidated loss on debt extinguishment increased $5.5 million from non-cash unamortized finance costs expensed in connection with the repayment of our prior Term Credit Agreement in January 2024.
Other Income, net
Consolidated other income, net decreased during 2024 compared to the prior year primarily due to a $9.3 million reimbursement from our partner associated with the collaborative arrangement related to our Arkansas resource development opportunity prior to capitalization of net pre-development costs beginning in January 2024, and a $1.0 million increase in unrealized losses on our convertible note embedded option. These decreases were partially offset by a $8.3 million increase in unrealized gains due to the change in the stock price of the Kodiak Gas Services, Inc. (NYSE: KGS) (“Kodiak”) shares we received in exchange for CSI Compressco LP (“CSI Compressco’) common units we owned in connection with Kodiak’s acquisition of CSI Compressco in April 2024.
Provision for Income Tax
Our consolidated effective tax rate for the year ended December 31, 2024 and December 31, 2023 was (295.3)% and 19.6%, respectively. The increase in our tax benefit compared to the prior year tax provision was primarily due to the reversal of the valuation allowance related to our United States deferred tax assets (federal and state). We establish a valuation allowance to reduce the deferred tax assets when it is more likely than not that some portion or all of the deferred tax assets will not be realized. As of each reporting date, management considers new evidence, both positive and negative, that could affect its view of the future realization of deferred tax assets. As of December 31, 2024, in part because in the current year we achieved three years of cumulative pretax income in the United States tax jurisdiction, management determined that there is sufficient positive evidence to conclude that it is more likely than not that additional deferred taxes of $97.5 million are realizable. We therefore reduced the valuation allowance accordingly.
Divisional Comparisons
Completion Fluids & Products Division
Year Ended
December 31, Period to Period Change
2024 2023 2024 vs. 2023 % Change
(In Thousands, Except Percentages)
Revenues $ 311,301 $ 313,030 $ (1,729) (0.6) %
Gross profit 109,305 107,684 1,621 1.5 %
Gross profit as a percentage of revenue 35.1 % 34.4 %
Exploration and pre-development costs - 12,119 (12,119) (100.0) %
General and administrative expense 25,754 28,003 (2,249) (8.0) %
General and administrative expense as a percentage of revenue 8.3 % 8.9 %
Interest income, net
(713) (646) 67 10.4 %
Other (income) loss, net 1,369 (10,106) 11,475 (113.5) %
Income before taxes and discontinued operations $ 82,895 $ 78,314 $ 4,581 5.8 %
Income before taxes and discontinued operations as a percentage of revenue 26.6 % 25.0 %
The Completion Fluids & Products Division revenues decreased slightly primarily due to a decline of international brominated product sales, particularly in Europe and Latin America, offset by increased volumes and continued favorable pricing for industrial chemicals sales.
The Completion Fluids & Products Division gross profit during 2024 increased compared to the prior year despite slightly lower revenues due to pricing improvements. Completion Fluids & Products Division profitability in future periods will continue to be affected by the mix of its products and services, market demand for our products and services, drilling and completions activity and commodity prices.
The Completion Fluids & Products Division pretax income increased during 2024 compared to the prior year primarily due to the increase in gross profit, along with a decrease in general and administrative expenses primarily due to a $1.9 million decrease in employee compensation and a $0.9 million decrease in professional services as well as a $0.6 million decrease in unrealized losses from our investment in Standard Lithium shares, which is included in other (income) loss, net. These changes were partially offset by a $12.1 million decrease in exploration and pre-development costs and a $9.3 million decrease in other income from reimbursements from our partner due to the capitalization of costs net of reimbursements beginning in January 2024. In addition, the unrealized losses on our convertible notes embedded derivative increased $1.0 million as the notes approach their maturity.
Water & Flowback Services Division
Year Ended
December 31, Period to Period Change
2024 2023 2024 vs. 2023 % Change
(In Thousands, Except Percentages)
Revenues $ 287,810 $ 313,232 $ (25,422) (8.1) %
Gross profit 31,014 47,138 (16,124) (34.2) %
Gross profit as a percentage of revenue 10.8 % 15.0 %
General and administrative expense 19,116 19,452 (336) (1.7) %
General and administrative expense as a percentage of revenue 6.6 % 6.2 %
Interest expense, net
64 205 (141) (68.8) %
Other expense, net
1,134 1,757 (623) (35.5) %
Income before taxes and discontinued operations
$ 10,700 $ 25,724 $ (15,024) (58.4) %
Income before taxes and discontinued operations as a percentage of revenue
3.7 % 8.2 %
The Water & Flowback Services Division revenues decreased during 2024 compared to the prior year primarily due to an overall decline in the United States market from both our production testing and water management services. This was partially offset by improved international market conditions in Latin America including an early production facility expansion as well as a full year of operation of an additional early production facility.
The Water & Flowback Services Division gross profit decreased due to lower revenues resulting from the decreased activity levels described above and operating cost inflation.
The Water & Flowback Services Division income before taxes decreased during 2024 compared to the prior year primarily due the decrease in gross profit, partially offset by a $0.4 million increase in other income, a $0.3 million decrease in general and administrative expenses from headcount reductions, and a $0.2 million increase in unrealized gain on our investment.
Corporate Overhead
Year Ended
December 31, Period to Period Change
2024 2023 2024 vs. 2023 % Change
(In Thousands, Except Percentages)
Depreciation and amortization $ 357 $ 400 $ (43) (10.8) %
General and administrative expense 45,099 49,135 (4,036) (8.2) %
Interest expense, net 23,114 22,790 324 1.4 %
Impairments and other charges
109 777 (668) (86.0) %
Loss on debt extinguishment
5,535 - 5,535 100.0 %
Other income, net
(9,361) (763) 8,598 1,126.9 %
Loss before taxes and discontinued operations
$ (64,853) $ (72,339) $ 7,486 10.3 %
Corporate Overhead loss before taxes decreased during 2024 compared to the prior year primarily due to an $8.3 million increase in unrealized gain on our investment in Kodiak, which acquired CSI Compressco in April 2024. General administrative expenses decreased primarily due to a $4.5 million decrease in salary related expenses. Impairments decreased $0.7 million primarily from an impairment of our corporate office lease in the prior year. These were partially offset by a $5.5 million loss on debt extinguishment from non-cash unamortized finance costs expensed in connection with the repayment of our prior Term Credit Agreement in January 2024 and a $1.0 million increase in professional services.
Non-GAAP Financial Measures
We use U.S. GAAP financial measures such as revenues, gross profit, income (loss) before taxes, and net cash provided by operating activities, as well as certain non-GAAP financial measures, including Adjusted EBITDA, as performance measures for our business.
Adjusted EBITDA. We define Adjusted EBITDA as net income (loss) before taxes and discontinued operations, excluding impairments, exploration and pre-development costs, certain special, non-recurring or other charges (or credits), interest, depreciation and amortization, income from collaborative arrangement and certain non-cash items such as equity-based compensation expense. The most directly comparable GAAP financial measure is net income (loss) before taxes and discontinued operations. Exploration and pre-development costs represent expenditures incurred to evaluate potential future development of TETRA’s lithium and bromine properties in Arkansas. Such costs include exploratory drilling and associated engineering studies. Income from collaborative arrangement represents the portion of exploration and pre-development costs that are reimbursable by our strategic partner. Exploration and pre-development costs, net of the associated income from collaborative arrangement are excluded from Adjusted EBITDA because they do not relate to the Company’s current business operations. Adjustments to long-term incentives represent adjustments to valuation of long-term cash incentive compensation awards that are related to prior years. These costs are excluded from Adjusted EBITDA because they do not relate to the current year and are considered to be outside of normal operations. Long-term incentives are earned over a three-year period and the costs are recorded over the three-year period they are earned. The amounts accrued or incurred are based on a cumulative of the three-year period. Equity-based compensation expense represents compensation that has been or will be paid in equity and is excluded from Adjusted EBITDA because it is a non-cash item.
Adjusted EBITDA is used by management as a supplemental financial measure to assess financial performance, without regard to charges or credits that are considered by management to be outside of its normal operations and without regard to financing methods, capital structure or historical cost basis, and to assess the Company’s ability to incur and service debt and fund capital expenditures.
Adjusted EBITDA is a financial measure that is not in accordance with U.S. GAAP and should not be considered an alternative to net income, operating income, cash flows from operating activities, or any other measure of financial performance presented in accordance with U.S. GAAP. This measure may not be comparable to similarly titled financial metrics of other entities, as other entities may not calculate Adjusted EBITDA in the same manner as we do. Management compensates for the limitations of Adjusted EBITDA as analytical tools by reviewing
the comparable U.S. GAAP measures, understanding the differences between the measures, and incorporating this knowledge into management’s decision-making processes.
The following table reconciles net income (loss) to Adjusted EBITDA for the periods indicated:
Year Ended
December 31, 2024
Completion Fluids & Products Water & Flowback Services Corporate SG&A Other and Eliminations Total
(In Thousands, Except Percents)
Revenue $ 311,301 $ 287,810 $ - $ - $ 599,111
Net income (loss) before taxes and discontinued operations 82,895 10,700 (45,099) (19,754) 28,742
Completion fluids buy-back allowance adjustment
(1,776) - - - (1,776)
Impairments and other charges - - - 109 109
Former CEO stock appreciation right credit
- - (701) - (701)
Transaction, restructuring and other (income) expenses
(26) 349 1,026 - 1,349
Loss on debt extinguishment
- - - 5,535 5,535
Unusual foreign exchange loss
- 1,387 - - 1,387
Interest (income) expense, net
(713) 64 - 23,114 22,465
Depreciation, amortization, and accretion
9,733 25,631 - 357 35,721
Equity-based compensation expense - - 6,572 - 6,572
Adjusted EBITDA $ 90,113 $ 38,131 $ (38,202) $ 9,361 $ 99,403
Adjusted EBITDA as % of revenue 28.9 % 13.2 % 16.6 %
Year Ended
December 31, 2023
Completion Fluids & Products Water & Flowback Services Corporate SG&A Other and Eliminations Total
(In Thousands, Except Percents)
Revenue $ 313,030 $ 313,232 $ - $ - $ 626,262
Net income (loss) before taxes and discontinued operations 78,314 25,724 (49,135) (23,204) $ 31,699
Insurance recoveries
(2,678) - - - (2,678)
Impairments and other charges
2,189 - 777 - 2,966
Exploration, pre-development costs, and collaborative arrangements
2,838 - - - 2,838
Adjustment to long-term incentives - - 1,526 - 1,526
Former CEO stock appreciation right expense - - 237 - 237
Transaction, restructuring, and other expenses
- - 502 - 502
Unusual foreign exchange loss
- 2,444 - - 2,444
Interest (income) expense, net
(647) 205 - 22,791 22,349
Depreciation, amortization, and accretion
9,053 24,876 - 400 34,329
Equity-based compensation expense - - 10,622 - 10,622
Adjusted EBITDA $ 89,069 $ 53,249 $ (35,471) $ (13) $ 106,834
Adjusted EBITDA as % of revenue 28.5 % 17.0 % 17.1 %
Liquidity and Capital Resources
We believe that our capital structure allows us to meet our financial obligations and fund future growth as needed, despite uncertain operating conditions and financial markets. Our liquidity at the end of the fourth quarter of 2024 was $182.2 million consisting of $37.0 million of unrestricted cash, $75.0 million of availability under our delayed draw term loan and $70.2 million of availability under our credit agreements. Liquidity is defined as unrestricted cash plus availability under the delayed draw from our Term Credit Agreement and availability under our revolving credit facilities.
Our consolidated sources and uses of cash for the years ended December 31, 2024 and 2023 are as follows:
Year Ended December 31,
2024 2023
(In Thousands)
Operating activities $ 36,520 $ 70,206
Investing activities $ (59,059) $ (27,027)
Financing activities $ 8,869 $ (4,663)
Operating Activities
Consolidated cash flows provided by operating activities totaled $36.5 million during 2024 compared to $70.2 million during the prior year, a decrease of $33.7 million. Operating cash flows decreased compared to the prior year primarily due to decreased activity levels from changes in market conditions and product mix, as well as the effect of working capital movements. We continue to monitor customer credit risk in the current environment and focus on serving larger capitalized oil and gas operators and national oil companies.
Investing Activities
Total cash capital expenditures during 2024 were $60.7 million. Our Water & Flowback Services Division spent $23.4 million on capital expenditures, primarily to deploy additional SandStorm units to meet increased demands and maintain, automate and upgrade its water management and flowback equipment fleet. Water and Flowback Services Division capital expenditures also included expenditures for expansion of an early production facility in Argentina. Our Completion Fluids & Products Division spent $37.0 million on capital expenditures during 2024, including $22.4 million on our strategic initiatives in Arkansas, net of reimbursement from our Evergreen Unit partner, to advance engineering and reservoir studies and began laying the groundwork for plant site preparation and power infrastructure for our bromine project. We also made additional investments to support higher activity levels in the United States and Europe.
We have rights to the brine underlying our approximately 40,000 gross acres of brine leases in the Smackover Formation in Southwest Arkansas, including rights to the bromine and lithium contained in the brine. Additional information on these resources is described in Part I, “Item 2. Properties” in this Annual Report. The extraction of lithium and bromine from these brine leases will likely require a significant amount of time and capital, which are subject to further analysis and consideration. In August 2024, we published a definitive feasibility study and updated technical resources report with respect to bromine from our Evergreen Brine Unit. We have ongoing negotiations with various bromine providers for bridging supply agreements that, if and when finalized, will give us flexibility on the timing of a plant start-up, allowing us to accumulate additional cash from our base business. These initiatives are expected to provide us the volumes necessary for the growing deepwater market plus the growing long-duration battery requirements, while deferring investments in Arkansas or scaling up our bromine production at lower levels than previously anticipated. If and when the bridging supply agreement is finalized, we will announce our revised Arkansas investment and timing plans.
Historically, a significant majority of our planned capital expenditures have been related to identified opportunities to grow and expand our existing businesses. We are also focused on enhancing shareholder value by capitalizing on our key mineral assets, brine mineral extraction expertise, and deep chemistry competency to expand our offerings into the low carbon energy markets. However, we continue to review all capital expenditure plans carefully in an effort to conserve cash. If the forecasted demand for our products and services increases or decreases, or we proceed with development of brine resources in Arkansas, the amount of planned expenditures on growth and expansion may be adjusted.
Financing Activities
During the year ended December 31, 2024, consolidated net cash used in financing activities was $8.9 million, consisting of $184.8 million borrowings under our new Term Credit Agreement and revolving credit facilities and $163.6 million repayments of our Term Credit Agreement and revolving credit facilities, $6.6 million debt issuance costs associated with our new term loan in January 2024 and the ABL Amendment in May 2024, as well as $1.4 million of payments of finance lease obligations. We may supplement our existing cash balances and
cash flow from operating activities with short-term borrowings, long-term borrowings, issuances of equity and debt securities, and other sources of capital.
Term Credit Agreement. On January 12, 2024, the Company entered into a definitive agreement for a $265.0 million credit facility consisting of a $190.0 million funded term loan and a $75.0 million delayed-draw term loan (collectively the “Term Credit Agreement”) that refinanced the Company’s prior Term Credit Agreement and provided capital to advance the Company’s Arkansas bromine processing project. The maturity date of the New Term Credit Agreement is January 1, 2030.
Asset-Based Credit Agreement. On May 13, 2024, we entered into an amendment (the ABL Amendment”) to the Asset-Based Lending agreement dated September 10,2018 (as amended, the “ABL Credit Agreement). In connection with the ABL Amendment, Bank of America, N.A. became successor administrative agent to JPMorgan Chase Bank, N.A. approximately $0.9 million of fees were incurred in connection with the ABL Amendment, which were deferred and will be amortized over the term of the ABL Credit Agreement.
The amended ABL Credit Agreement provides, with certain restrictions, for a senior secured revolving credit facility of up to $100.0 million with a $25.0 million accordion. The credit facility is subject to a borrowing base determined monthly by reference to the value of inventory and accounts receivable, and includes a sublimit of $20.0 million for letters of credit, and a swingline loan sublimit of $11.5 million.
The ABL Credit Agreement may be used for working capital needs, capital expenditures and other general corporate purposes. The amounts we may borrow under the ABL Credit Agreement are derived from our accounts receivable, certain accrued receivables and certain inventory. Changes in demand for our products and services have an impact on our eligible accounts receivable, accrued receivables and the value of our inventory, which could result in significant changes to our borrowing base and therefore our availability under our ABL Credit Agreement. The ABL Credit Agreement is scheduled to mature on May 13, 2029. As of December 31, 2024, we had no balance outstanding under the ABL Credit Agreement and, subject to compliance with the covenants, borrowing base, and other provisions of the agreement that may limit borrowings, we had availability of $65.7 million under the ABL Credit Agreement. As of February 25, 2025, we have no outstanding borrowings under our ABL Credit Agreement and $0.2 million letters of credit, resulting in $79.8 million of availability.
Swedish Credit Facility. In January 2022, the Company entered into a revolving credit facility for seasonal working capital needs of subsidiaries in Sweden and Finland (“Swedish Credit Facility”). As of December 31, 2024, we had no balance outstanding and availability of approximately $4.5 million under the Swedish Credit Facility. During each year, all outstanding loans under the Swedish Credit Facility must be repaid for at least 30 consecutive days. Borrowings bear interest at a rate of 2.95% per annum. The Swedish Credit Facility expires on December 31, 2025 and the Company intends to renew it annually.
Finland Credit Agreement. In January 2022, the Company entered into an agreement guaranteed by certain accounts receivable and inventory in Finland (“Finland Credit Agreement”). As of December 31, 2024, we had $1.4 million of letters of credit outstanding against the Finland Credit Agreement. The Finland Credit Agreement has been renewed by the Company through January 31, 2026.
As of December 31, 2024, we are in compliance with all covenants of our debt agreements. See Note 10 - “Long-Term Debt and Other Borrowings” and Note 18 - “Subsequent Events” in the Notes to Consolidated Financial Statements for further information.
Other Sources and Uses of Cash
In addition to the aforementioned credit facilities and senior notes, we fund our short-term liquidity requirements from cash generated by our operations and from short-term vendor financing. In addition, as of December 31, 2024, the market value of our equity holdings of Kodiak and Standard Lithium were $18.4 million and $1.2 million, respectively, with no holding restrictions on our ability to monetize our investments. In January 2025, we sold our Kodiak shares for proceeds of $19.0 million, net of transaction and broker fees. Should additional capital be required, the ability to raise such capital through the issuance of additional debt or equity securities may currently be limited. Instability or volatility in the capital markets at the times we need to access capital may affect the cost of capital and the ability to raise capital for an indeterminable length of time. If it is necessary to issue additional equity to fund our capital needs, additional dilution of our common stockholders will occur. We periodically evaluate engaging in strategic transactions and may consider divesting non-core assets where our evaluation
suggests such transaction is in the best interest of our business. In challenging economic environments, we may experience increased delays and failures by customers to pay our invoices. We could experience delayed customer payments and payment defaults associated with customer liquidity issues and bankruptcies. If our customers delay paying or fail to pay us a significant amount of our outstanding receivables, it could have an adverse effect on our liquidity. An increase of unpaid receivables would also negatively affect our borrowing availability under the ABL Credit Agreement and Swedish Credit Facility.
Leases
We have operating leases for some of our transportation equipment, office space, warehouse space, operating locations, and machinery and equipment, as well as a sales-type lease and subleases for certain facilities. See Note 2 - “Basis of Presentation and Significant Accounting Policies” and Note 8 - “Leases” in the Notes to Consolidated Financial Statements for further information on our lease obligations.
Asset Retirement Obligations
We operate facilities in various U.S. and foreign locations that are used in the manufacture, storage, and sale of our products, inventories, and equipment. We are required to take certain actions in connection with the retirement of these assets.
Product Purchase Obligations
In the normal course of our Completion Fluids & Products Division operations, we enter into supply agreements with certain manufacturers of various raw materials and finished products. For information on product purchase obligations, see - Note 11 - “Commitments and Contingencies” in the Notes to Consolidated Financial Statements.
Off Balance Sheet Arrangements
As of December 31, 2024, we do not have any off balance sheet arrangements that may have a current or future material effect on our consolidated financial condition or results of operations.
Litigation
For information regarding litigation, including contingencies of discontinued operations, see Note 11 - “Commitments and Contingencies” in the Notes to Consolidated Financial Statements.
Critical Accounting Policies and Estimates
This discussion and analysis of our financial condition and results of operations is based upon our consolidated financial statements. We prepared these financial statements in conformity with U.S. GAAP. In preparing our consolidated financial statements, we make assumptions, estimates, and judgments that affect the amounts reported. We base these on historical experience, available information, and various other assumptions that we believe are reasonable. Our assumptions, estimates, and judgments may change as new events occur, as new information is acquired, and as changes in our operating environments are encountered. Actual results are likely to differ from our current estimates, and those differences may be material.
An accounting policy is considered critical if it is both material to the presentation of the financial statements and requires management to make difficult, subjective or complex judgments that could have a material effect on the financial condition or results of operations. Accounting estimates and assumptions may become critical when they are material due to the levels of subjectivity and judgment necessary to account for highly uncertain matters or the susceptibility of such matters to change, and that have a material impact on financial condition or operating performance.
Critical accounting estimates are estimates that require us to make assumptions about matters that were highly uncertain at the time the accounting estimate was made and if different estimates that we reasonably could have used in the current period, or changes in the accounting estimate that are reasonably likely occur from period to period, have a material impact on the presentation of our financial condition, changes in financial condition or results of operations. We believe that of our significant accounting policies described in Note 2 - Basis of
Presentation and Significant Accounting Policies in Part II, Item 8 of this Annual Report on Form 10-K, the critical accounting estimates, assumptions, and judgments that have the most significant impact on our consolidated financial statements are described below.
Income Taxes
Deferred tax assets and liabilities are recognized for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis amounts. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. The effect of a change in tax rates is recognized as income or expense in the period that includes the enactment date.
We recognize deferred tax assets to the extent that we believe that these assets are more likely than not to be realized. In making such a determination, we consider available positive and negative evidence, including future reversals of existing taxable temporary differences, projected future taxable income, tax-planning strategies, and results of recent operations. If we determine that we would be able to realize our deferred tax assets in the future in excess of their net recorded amount, we would make an adjustment to the deferred tax asset valuation allowance, which would reduce the provision for income taxes. A portion of the carrying value of certain deferred tax assets are subject to a valuation allowance.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Item 7A. Quantitative and Qualitative Disclosures about Market Risk.
Interest Rate Risk
The interest on our borrowings is subject to market risk exposure related to changes in applicable interest rates. On January 12, 2024, the Company entered into a New Term Credit Agreement consisting of a $190.0 million funded term loan and a $75.0 million delayed-draw term loan that refinanced the Company’s Term Credit Agreement outstanding as of December 31, 2023. Borrowings under the New Term Credit Agreement bear interest at a rate per annum equal to SOFR plus 5.75%. The Company is required to pay a commitment fee on the unutilized commitments with respect to the delayed-draw term loan at the rate of 1.5% per annum. Borrowings under our Asset-Based Credit Agreement bear interest at an agreed-upon percentage rate spread above SOFR. Borrowings under our Swedish Credit Facility, if any, bear interest at fixed rates of 2.95%. The following table sets forth as of December 31, 2024, the principal amount due under our long-term debt obligations and their respective weighted average interest rates. We are not a party to an interest rate swap contract or other derivative instrument designed to hedge our exposure to interest rate fluctuation risk.
Interest December 31,
Scheduled Maturity Rate 2024
(In Thousands)
Term credit agreement January 1, 2030 10.23% $ 190,000
Total long-term debt $ 190,000
Exchange Rate Risk
We have currency exchange rate risk exposure related to revenues, expenses, operating receivables, and payables denominated in foreign currencies. We may enter into short-term foreign-currency forward derivative contracts as part of a program designed to mitigate the currency exchange rate risk exposure on selected transactions of certain foreign subsidiaries. Although contracts pursuant to this program will serve as an economic hedge of the cash flow of our currency exchange risk exposure, they are not expected to be formally designated as hedge contracts or qualify for hedge accounting treatment. Accordingly, any change in the fair value of these derivative instruments during a period will be included in the determination of earnings for that period. As of December 31, 2024, we did not have any foreign currency exchange contracts outstanding.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Item 8. Financial Statements and Supplementary Data.
The financial statements and supplementary data required to be included in this Item 8 are set forth in Item 15 of this Annual Report.

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ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.
None.

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ITEM 9A. CONTROLS AND PROCEDURES
Item 9A. Controls and Procedures.
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
Under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, we conducted an evaluation of our disclosure controls and procedures, as such term is defined under Rule 13a-15(e) promulgated under the Exchange Act as of the end of the period covered by this report. Based on this evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of December 31, 2024.
Management’s Report on Internal Control over Financial Reporting
Our management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is defined in Exchange Act Rule 13a-15(f). Our Internal control over financial reporting is a process to provide reasonable assurance regarding the reliability of our financial reporting for external purposes in accordance with accounting principles generally accepted in the United States of America.
Our internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that in reasonable detail accurately and fairly reflect the transactions and dispositions of our assets; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures are being made only in accordance with authorizations of our management and directors; and (3) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. In addition, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Under the supervision and with the participation of management, including our Chief Executive Officer and Chief Financial Officer, an evaluation of the effectiveness of our internal control over financial reporting as of December 31, 2024 was conducted based on the framework in Internal Control - Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework) (“COSO”). Based on this assessment, management has determined that our internal control over financial reporting was effective as of December 31, 2024.
Grant Thornton LLP, our independent registered public accounting firm, has issued an attestation report on the effectiveness of our internal control over financial reporting as of December 31, 2024. Grant Thornton LLP’s report on our internal control over financial reporting is included herein.
Changes in Internal Control over Financial Reporting
There were no changes in our internal control over financial reporting that occurred during the fourth quarter of the fiscal year ended December 31, 2024, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

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ITEM 9B. OTHER INFORMATION
Item 9B. Other Information.
Rule 10b5-1 Trading Arrangements
During the three months ended December 31, 2024, no director or officer of TETRA adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule10b5-1 trading arrangement,” as each term is defined in Item 408(a) of Regulation S-K.

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Item 10. Directors, Executive Officers, and Corporate Governance.
The information required by this Item is hereby incorporated by reference from the information appearing under the captions “Proposal No. 1: Election of Directors,” “Executive Officers,” “Corporate Governance,” “Board Meetings and Committees,” in our definitive proxy statement (the “Proxy Statement”) for the annual meeting of stockholders to be held on May 23, 2025, which involves the election of directors and is to be filed with the SEC pursuant to the Exchange Act within 120 days of the end of our fiscal year on December 31, 2024.

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ITEM 11. EXECUTIVE COMPENSATION
Item 11. Executive Compensation.
The information required by this Item is hereby incorporated by reference from the information appearing under the captions “Management and Compensation Committee Report,” “Management and Compensation Committee Interlocks and Insider Participation,” “Compensation Discussion and Analysis,” “Compensation of Executive Officers,” and “Director Compensation” in our Proxy Statement. Notwithstanding the foregoing, in accordance with the instructions to Item 407 of Regulation S-K, the information contained in our Proxy Statement under the subheading “Compensation Committee Report” shall be deemed furnished, and not filed, in this Form 10-K, and shall not be deemed incorporated by reference into any filing under the Securities Act, or the Exchange Act, as a result of this furnishing, except to the extent we specifically incorporate it by reference.

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ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.
The information required by this Item is hereby incorporated by reference from the information appearing under the captions “Beneficial Stock Ownership of Certain Stockholders and Management” and “Equity Compensation Plan Information” in our Proxy Statement.

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ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
Item 13. Certain Relationships and Related Transactions, and Director Independence.
The information required by this Item is hereby incorporated by reference from the information appearing under the captions “Certain Transactions” and “Director Independence” in our Proxy Statement.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Item 14. Principal Accounting Fees and Services.
The information required by this Item is hereby incorporated by reference from the information appearing under the caption “Fees Paid to Principal Accounting Firm” in our Proxy Statement.
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
Item 15. Exhibits and Financial Statement Schedules.
(a) List of documents filed as part of this Report
1. Financial Statements of the Company
Page
Reports of Independent Registered Public Accounting Firm (PCAOB ID Number Grant Thornton LLP: 248)
Consolidated Balance Sheets at December 31, 2024 and 2023
Consolidated Statements of Operations for the years ended December 31, 2024, 2023, and 2022
Consolidated Statements of Comprehensive Income (Loss) for the years ended December 31, 2024, 2023, and 2022
Consolidated Statements of Equity for the years ended December 31, 2024, 2023, and 2022
Consolidated Statements of Cash Flows for the years ended December 31, 2024, 2023, and 2022
Notes to Consolidated Financial Statements
2. Financial statement schedules
All other schedules for which provision is made in the applicable accounting regulation of the Securities and Exchange Commission are not required under the related instructions or are inapplicable and therefore have been omitted.
3. List of Exhibits
2.1+++ Asset Purchase and Sale Agreement, dated February 28, 2018, by and between Maritech Resources, LLC, TETRA Technologies, Inc., and Orinoco Natural Resources, LLC (incorporated by reference to Exhibit 2.1 to the Company’s Quarterly Report on Form 10-Q filed on May 10, 2018 (SEC File No. 001-13455)).
2.2+++ Equity Interest Purchase and Sale Agreement, dated February 28, 2018, by and among TETRA Technologies, Inc., TETRA Production Testing Holding LLC, and Epic Offshore Specialty, LLC (incorporated by reference to Exhibit 2.2 to the Company’s Quarterly Report on Form 10-Q filed on May 10, 2018 (SEC File No. 001-13455)).
2.3+++ Equity Interest Purchase Agreement, dated February 13, 2018, by and among the sellers listed therein, the sellers representative and TETRA Technologies, Inc (incorporated by reference to Exhibit 2.3 to the Company’s Quarterly Report on Form 10-Q filed on May 10, 2018 (SEC File No. 001-13455)).
2.4+++ Membership Interest Purchase And Sale Agreement, dated as of February 28, 2018, by and among TETRA Applied Technologies, LLC, Maritech Resources, LLC, TETRA Technologies, Inc., and Orinoco Natural Resources, LLC (incorporated by reference to Exhibit 2.4 to the Company’s Quarterly Report on Form 10-Q filed on May 10, 2018 (SEC File No. 001-13455)).
3.1 Amended and Restated Certificate of Incorporation of TETRA Technologies, Inc. (incorporated by reference to Exhibit 3.1 to the Company’s Current Report on Form 8-K filed on May 25, 2023 (SEC File No. 001-13455)).
3.2 Second Amended and Restated Bylaws of TETRA Technologies, Inc. (incorporated by reference to Exhibit 3.2 to the Company’s Current Report on Form 8-K filed on May 25, 2023 (SEC File No. 001-13455)).
4.1 Form of Senior Indenture (including form of senior debt security) (incorporated by reference to Exhibit 4.11 to the Company's Registration Statement on Form S-3 filed on May 5, 2022 (SEC File No. 333-264709)).
4.2
Credit Agreement dated as of January 12, 2024 among TETRA Technologies, Inc., Silver Point Finance, LLC, as administrative agent, and the lenders party thereto (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on January 18, 2024 (SEC File No. 001-13455)).
4.3
Sixth Amendment to Credit Agreement and Second Amendment to Pledge and Security Agreement dated May 13, 2024 between TETRA Technologies, Inc., certain subsidiaries of the company, and Bank of America, N.A (incorporated by reference to Exhibit 10.2 to the Company's Current Report on Form 8-K/A filed on May 20, 2024 (SEC File No. 001-13455)).
4.4
Tax Benefits Preservation Plan, dated February 28, 2023, between TETRA Technologies, Inc. and Computershare Trust Company N.A., as Rights Agent (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K filed on March 1, 2023 (SEC File No. 001-13455)).
4.5
Description of the Registrant's Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934 (incorporated by reference to Exhibit 4.11 to the Company’s Annual Report on Form 10-Q filed on February 27, 2024 (SEC File No. 001-13455)).
10.1*** TETRA Technologies, Inc. Nonqualified Deferred Compensation Plan (incorporated by reference to Exhibit 10.9 to the Company’s Quarterly Report on Form 10-Q filed on August 13, 2002 (SEC File No. 001-13455)).
10.2*** TETRA Technologies, Inc. Nonqualified Deferred Compensation Plan and The Executive Excess Plan Adoption Agreement effective on June 30, 2005 (incorporated by reference to Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q/A filed on March 16, 2006 (SEC File No. 001-13455)).
10.3***
TETRA Technologies, Inc. Non-Employee Director Deferred Compensation Plan effective on December 13, 2023 incorporated by reference to Exhibit 10.3 to the Company’s Annual Report on Form 10-K filed on February 27, 2024 (SEC File No, 001-13455)).
10.4***
TETRA Technologies, Inc. Amended and Restated 2007 Long Term Incentive Compensation Plan, as amended through February 20, 2015 (incorporated by reference to Exhibit 10.3 to the Company's Quarterly Report on Form 10-Q filed on August 10, 2015 (SEC File No. 001-13455)).
10.5***
Form of Employee Incentive Stock Option Agreement under the TETRA Technologies, Inc. 2007 Long Term Incentive Compensation Plan (incorporated by reference to Exhibit 4.12 to the Company’s Registration Statement on Form S-8 filed on May 5, 2010 (SEC File No. 333-166537)).
10.6***
Third Amended and Restated 2011 Long Term Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to the Company's Current Report Form 8-K filed on May 6, 2016 (SEC File No. 001-13455)).
10.7
Lease Agreement dated December 31, 2012 by and between Tetris Property LP and TETRA Technologies, Inc. (incorporated by reference to Exhibit 10.36 to the Company's Annual Report on Form 10-K filed on March 4, 2013 (SEC File No. 001-13455)).
10.8
Bonding Agreement, dated February 28, 2018, between TETRA Technologies, Inc., Orinoco Natural Resources, LLC, and Epic Offshore Specialty, LLC (incorporated by reference to Exhibit 10.3 to the Company’s Quarterly Report on Form 10-Q filed May 10, 2018 (SEC File No. 001-13455)).
10.9***
Form of Change in Control Agreement (incorporated by reference to Exhibit 10.21 to the Company’s Annual Report on Form 10-K filed on March 16, 2020 (SEC File No. 001-13455)).
10.10***
TETRA Technologies, Inc. Cash Incentive Compensation Plan (incorporated by reference to Exhibit 4.1 to the Company’s Quarterly Report on Form 10-Q filed on May 10, 2010 (SEC File No. 001-13455)).
10.11+***
Amendment to the TETRA Technologies, Inc. Cash Incentive Compensation Plan dated February 19, 2015.
10.12***
Amendment No. 2 to the TETRA Technologies, Inc. Cash Incentive Compensation Plan (incorporated by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K filed on February 26, 2016 (SEC File No. 001-13455)).
10.13***
Stand-Alone Cash-Settled Stock Appreciation Rights Award Agreement, dated February 22, 2018, between TETRA Technologies, Inc. and Stuart M. Brightman (incorporated by reference to Exhibit 10.44 to the Company’s Annual Report on Form 10-K filed on March 4, 2019 (SEC File No. 001-13455)).
10.14***
TETRA Technologies, Inc. 2018 Inducement Restricted Stock Plan (incorporated by reference to Exhibit 4.5 to the Company’s Registration Statement on Form S-8 filed on February 12, 2018 ((SEC File No. 333-222976)).
10.15***
Form of TETRA Technologies, Inc. 2018 Inducement Restricted Stock Plan Restricted Stock Award Agreement (incorporated by reference to Exhibit 4.6 to the Company’s Registration Statement on Form S-8 filed on February 12, 2018 (SEC File No. 333-222976)).
10.16***
TETRA Technologies, Inc. Second Amended and Restated 2018 Equity Incentive Plan (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on May 25, 2023 (SEC File No. 001-13455)).
10.17***
Form of TETRA Technologies, Inc. Second Amended and Restated 2018 Equity Incentive Plan Restricted Stock Unit Award (incorporated by reference to Exhibit 10.33 to the Company’s Annual Report on Form 10-K filed on February 27, 2024 (SEC File No. 001-13455)).
10.18***
Form of TETRA Technologies, Inc. Second Amended and Restated 2018 Equity Incentive Plan Restricted Stock Unit Award for outside directors (incorporated by reference to Exhibit 10.34 to the Company’s Annual Report on Form 10-K filed on February 27, 2024 (SEC File No. 001-13455)).
10.19***
Form of TETRA Technologies, Inc. Second Amended and Restated 2018 Equity Incentive Plan Cash Award (incorporated by reference to Exhibit 10.35 to the Company’s Annual Report on Form 10-K filed on February 27, 2024 (SEC File No. 001-13455)).
10.20***
Form of TETRA Technologies, Inc. 2018 Equity Incentive Plan Incentive Stock Option Award Agreement (incorporated by reference to Exhibit 4.7 to the Company’s registration statement on Form S-8 filed on May 4, 2018 (SEC File No. 333-224679).
10.21
Form of Indemnification Agreement for directors and executive officers of TETRA Technologies, Inc. (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K filed on November 12, 2008 (SEC File No. 001-13455)).
10.22
Memorandum of Understanding between TETRA Technologies, Inc. and Saltwerx LLC dated June 19, 2023 (incorporated by reference to Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q filed on July 31, 2023 (SEC File No. 001-13455)).
10.23
Memorandum of Understanding Amendment No. 1 between TETRA Technologies, Inc. and Saltwerx LLC dated November 29, 2023 (incorporated by reference to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q filed on April 30, 2024 (SEC File No. 001-13455)).
10.24
Memorandum of Understanding Amendment No. 2 between TETRA Technologies, Inc. and Saltwerx LLC dated January 16, 2024 (incorporated by reference to Exhibit 10.2 to the Company’s Quarterly Report on Form 10-Q filed on April 30, 2024 (SEC File No. 001-13455)).
10.25
Memorandum of Understanding Amendment No. 3 between TETRA Technologies, Inc. and Saltwerx LLC dated March 20, 2024 (incorporated by reference to Exhibit 10.3 to the Company’s Quarterly Report on Form 10-Q filed on April 30, 2024 (SEC File No. 001-13455)).
10.26
Memorandum of Understanding Amendment No. 4 between TETRA Technologies, Inc. and Saltwerx LLC dated April 15, 2024 (incorporated by reference to Exhibit 10.4 to the Company’s Quarterly Report on Form 10-Q filed on April 30, 2024 (SEC File No. 001-13455)).
10.27
Memorandum of Understanding Amendment No. 5 between TETRA Technologies, Inc. and Saltwerx LLC dated August 19, 2024 (incorporated by reference to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q filed on October 29, 2024 (SEC File No. 001-13455)).
19+
TETRA Technologies, Inc. Policy on Trading in Company Securities.
21+ Subsidiaries of the Company.
23.1+ Consent of Grant Thornton LLP
31.1+ Certification Pursuant to Rule 13(a)-14(a) or 15(d)-14(a) of the Exchange Act, As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2+ Certification Pursuant to Rule 13(a)-14(a) or 15(d)-14(a) of the Exchange Act, As Adopted Pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1** Certification Furnished Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Chief Executive Officer).
32.2** Certification Furnished Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 (Chief Financial Officer).
97.1
TETRA Technologies, Inc. Incentive-Based Compensation Recoupment Policy effective on October 25, 2023 (incorporated by reference to Exhibit 97.1 to the Company’s Annual Report on Form 10-K filed on February 27, 2024 (SEC file No. 001-13455)).
101.INS++ XBRL Instance Document.
101.SCH++ XBRL Taxonomy Extension Schema Document.
101.CAL++ XBRL Taxonomy Extension Calculation Linkbase Document.
101.LAB++ XBRL Taxonomy Extension Label Linkbase Document.
101.PRE++ XBRL Taxonomy Extension Presentation Linkbase Document.
101.DEF++ XBRL Taxonomy Extension Definition Linkbase Document.
104++ Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).
+ Filed with this report
** Furnished with this report.
*** Management contract or compensatory plan or arrangement.
++ Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) Consolidated Statements of Operations for the years ended December 31, 2024, 2023 and 2022; (ii) Consolidated Balance Sheets as of December 31, 2024 and December 31, 2023; (iii) Consolidated Statements of Comprehensive Income for the years ended December 31, 2024, 2023 and 2022; (iv) Consolidated Statements of Cash Flows for the years ended December 31, 2024, 2023 and 2022; (v) Consolidated Statements of Stockholders’ Equity for the years ended December 31, 2024, 2023 and 2022; and (vi) Notes to Consolidated Financial Statements for the year ended December 31, 2024.
+++ Certain schedules have been omitted pursuant to Item 601(a)(5) of Regulation S-K. The registrant agrees to furnish supplementally a copy of any such omitted schedule to the SEC upon request.