EDGAR 10-K Filing

Company CIK: 1121484
Filing Year: 2025
Filename: 1121484_10-K_2025_0001121484-25-000024.json

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ITEM 1. BUSINESS
Item 1. Business
Our Company
Oil States International, Inc., through its subsidiaries, is a global provider of manufactured products and services to customers in the energy, industrial and military sectors. The Company’s manufactured products include highly engineered capital equipment and consumable products. Oil States is headquartered in Houston, Texas with manufacturing and service facilities strategically located across the globe. Our customers include many national oil and natural gas companies, major and independent oil and natural gas companies, offshore drilling companies and other oilfield service, defense and industrial companies. We operate through three business segments - Offshore Manufactured Products, Completion and Production Services (previously referred to as Well Site Services) and Downhole Technologies - and maintain a leadership position with certain of our product and service offerings in each segment. In this Annual Report on Form 10-K, references to the “Company” or “Oil States,” or to “we,” “us,” “our,” and similar terms are to Oil States International, Inc. and its consolidated subsidiaries.
Available Information
Our website can be found at www.oilstatesintl.com. We make available, free of charge through our website, our Annual Report on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, our proxy statement, our Registration Statements and Forms 3, 4 and 5 filed on behalf of directors and executive officers, and amendments to these reports, as soon as reasonably practicable after we electronically file such material with, or furnish such material to, the SEC. We are not including the information contained on our website or any other website as a part of, or incorporating it by reference into, this Annual Report on Form 10-K or any other filing we make with the SEC. The filings are also available through the SEC’s website at www.sec.gov. Our Board of Directors (the “Board”) has documented its governance practices by adopting several corporate governance policies. These governance policies, including our Corporate Governance Guidelines, Corporate Code of Business Conduct and Ethics, Financial Code of Ethics for Senior Officers, Supplier Code of Conduct and Human Rights Policy, as well as the charters for the committees of the Board (Audit Committee, Compensation Committee and Nominating, Governance and Sustainability Committee) may also be viewed on our website. The Financial Code of Ethics for Senior Officers applies to our principal executive officer, principal financial officer, principal accounting officer and other senior officers. Copies of such
documents will be provided to stockholders without charge upon written request to the corporate secretary at the address shown on the cover page of this Annual Report on Form 10-K.
Our Business Strategy
We have historically grown our product and service offerings organically, through capital spending, and strategic acquisitions. Our investments are focused in areas where we expect to be able to expand market share through our new and existing technology offerings and where we believe we can achieve an attractive return on our investment. Given the highly cyclical nature of select U.S. service lines, we implemented strategic restructuring actions in our U.S. land-based businesses during 2024 to reduce costs and improve future operating margins. As part of our long-term strategy, we continue to: review opportunities for offshore and international business expansion; strategically optimize our U.S. land-based operations; market new technology offerings; invest in research and development; and fund organic capital expenditures to enhance our cash flows, leverage our cost structure and increase our stockholders’ returns. For additional discussion of our business strategy, please read “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Annual Report on Form 10-K.
Recent Developments
Increased capital investments by our offshore and international customers in 2024 was offset by a decline in U.S. land-based investments by our customers, competitive market conditions and management’s decision to exit certain underperforming locations and service offerings in the United States, as shown below (in thousands).
Year ended December 31,
2024 2023 Change
Revenues $ 692,588 $ 782,283 $ (89,695)
Operating income (loss)(1)
(1,689) 23,164 (24,853)
Net income (loss)(1)
(11,258) 12,891 (24,149)
Cash flow from operations
45,894 56,575 (10,681)
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(1)Operating loss in 2024 included $24.6 million in non-cash goodwill, intangible asset and operating lease asset impairment charges, as well as other charges totaling $13.7 million associated with facility consolidations and exits, patent defense and other management actions. These charges were partially offset by a net gain of $15.3 million associated with the sale of a previously idled facility. Excluding these items, operating income would have been $21.3 million and net income would have been $11.2 million.
In 2023, we began implementing initiatives, which continued throughout 2024, to reduce costs. Management actions in 2024 included: the consolidation, relocation and exit of certain underperforming locations; the exit of certain service offerings; reductions in our U.S. work force as well as the realignment of operations discussed below. We also incurred legal and other related costs to enforce certain patents related to our proprietary technologies. As a result of these actions, our reported pre-tax results for 2024 included $24.6 million in non-cash goodwill, intangible asset and operating lease asset impairment charges as well as $13.7 million of facility consolidation and exit costs, patent defense and other charges.
Certain short-cycle, consumable product operations historically reported within the Offshore Manufactured Products segment (legacy frac plugs and elastomer products) were integrated into the Downhole Technologies segment in early 2024 to better align with the underlying activity demand drivers and current segment management structure, as well as provide for additional operational synergies. Historical financial data, supplemental disaggregated revenue and backlog information as of and for the years ended December 31, 2023 and 2022 (presented herein) were conformed with the 2024 segment presentation. Additionally, following the sale of its remaining U.S. land-based drilling rigs and the exit of the flowback and well testing service offering in the third quarter of 2024, our Well Site Services segment name was changed to the Completion and Production Services segment.
In February 2024, we amended our senior secured credit facility, which provides for a $125.0 million asset-based revolving credit facility (as amended, the “ABL Facility”), to extend its maturity date to February 16, 2028.
During 2024, we sold two manufacturing and service facilities that were classified as held for sale assets, generating net proceeds of $35.1 million, we purchased $14.2 million of our common stock, and we purchased $11.5 million principal amount of our 4.75% convertible senior notes (the “2026 Notes”) for $10.8 million.
In October 2024, our Board of Directors also terminated our existing common stock repurchase program and replaced it with a new $50.0 million common stock repurchase authorization, which expires in October 2026.
Our Industry
We provide a broad range of products and services to our customers through each of our business segments. See Note 14, “Segments and Related Information,” to the Consolidated Financial Statements included in this Annual Report on Form 10-K for financial information by segment along with a geographical breakout of revenues and long-lived assets for each of the three years in the period ended December 31, 2024. Demand for our products and services is cyclical and substantially dependent upon activity levels in the oil and natural gas industry, particularly upon the willingness of our customers to invest capital in the exploration for and development of crude oil and natural gas reserves. Our customers’ capital spending programs are generally based on their outlook for near-term and long-term commodity prices, economic growth, commodity demand and estimates of resource production as well as regulatory and market pressures related to Environmental, Social and Governance (“ESG”) considerations. As a result, demand for our products and services is largely sensitive to expectations regarding future crude oil and natural gas prices.
Our historical financial results reflect the cyclical nature of the oilfield services industry - witnessed by periods of increasing and decreasing activity in each of our operating segments. The level of capital spending in recent years by oil and gas companies for exploration and production activities has improved from the lows observed during 2020 and 2021, which resulted from the economic downturn associated with the global response to the COVID-19 pandemic. As discussed previously, we saw continued growth and recovery in offshore and international project activity in 2024, offset by a decline in U.S. activity due to well completion efficiencies leading to higher production and a decline in commodity prices from 2023 levels. For additional information about activities in each of our segments, see “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.”
Demand for the products and services supplied by our Offshore Manufactured Products segment is primarily driven by the longer-term outlook for commodity prices. In this regard, exploration and production companies generally evaluate their capital expenditure commitments for offshore (particularly deepwater) and international projects based on the longer-term outlook for commodity prices since they are expensive to drill and complete and have long lead times to first production. Bidding and quoting activity, along with customer orders, for offshore and international projects remained strong in 2024, following improvements in recent years in the longer-term outlook for the sustainability of crude oil and natural gas demand. With these market improvements, we grew our backlog and related project-driven revenues in 2024.
Demand for our Completion and Production Services segment is primarily affected by well completion activity in the United States, including the Gulf of America, and, to a lesser extent, the rest of the world. U.S. well completion activity and, in turn, our Completion and Production Services segment results, are sensitive to near-term fluctuations in WTI crude oil and natural gas prices, given the shorter lead times for investment and the call-out nature of our operations in the segment.
Similarly, demand for our Downhole Technologies segment products is predominantly tied to land-based oil and natural gas exploration and production activity levels in the United States and, to a lesser extent, internationally. The primary driver for this activity is the price of crude oil and, to a lesser extent, natural gas. In past years, operator spending in our industry has been particularly focused on crude oil and liquids-rich exploration and development in the U.S. shale plays utilizing enhanced horizontal drilling and completion techniques.
Offshore Manufactured Products
Overview
For the years ended December 31, 2024, 2023 and 2022, our Offshore Manufactured Products segment generated 44% to 57% of our consolidated revenue. Through this segment, we provide technology-driven, highly-engineered products and services for offshore oil and natural gas production systems and facilities, military and other energy applications, as well as certain products and services to offshore drilling and completion markets. Products and services used primarily in deepwater producing regions include our FlexJoint® technology, advanced connector systems, high-pressure riser systems, managed pressure drilling systems, compact valves, deepwater mooring systems, cranes, subsea pipeline products, offshore installation services and inspection and repair services. In addition, we recently introduced other products and services used by non-oil and gas customers, including subsea mineral gathering systems, offshore wind applications, geothermal products and services, valves and sound and vibration dampening products used in military applications. We have facilities globally that support our Offshore Manufactured Products segment.
Market
The market for products and services offered by our Offshore Manufactured Products segment centers primarily on the development of infrastructure for offshore production facilities and their subsequent operations, exploration and drilling
activities, and to a lesser extent, on-vessel construction, refurbishments or upgrades. Demand for oil and natural gas, and the related drilling and production in offshore areas throughout the world, particularly in deeper water, drive spending for these activities.
Products and Services
In operation for over 80 years, our Offshore Manufactured Products segment provides a broad range of products and services for use in offshore development and drilling activities. This segment also produces a variety of products for use in industrial, military and other applications outside the traditional energy industry. Our Offshore Manufactured Products segment is dependent in part on the industry’s continuing innovation and creative applications of existing technologies. We invest in research and product development (and have been awarded select contracts and are bidding on additional projects) to facilitate the development of alternative energy sources, including offshore wind and deepsea mineral gathering opportunities. We own various patents covering some of our technology, particularly in our connector and valve product lines.
Backlog
Offshore Manufactured Products’ backlog consists of firm customer purchase orders for which contractual commitments exist and delivery is scheduled. Backlog in our Offshore Manufactured Products segment was $311 million as of December 31, 2024, compared to $327 million as of December 31, 2023 and $300 million as of December 31, 2022. We expect approximately 70% of our backlog as of December 31, 2024 to be recognized as revenue during 2025. In some instances, these purchase orders are cancellable by the customer, subject to the payment of termination fees and/or the reimbursement of our costs incurred. While backlog cancellations have historically been insignificant, material cancellations may occur in the future. We believe backlog is an important indicator of future Offshore Manufactured Products’ shipments and major project revenues; however backlog as of any particular date may not be indicative of our actual operating results for any future period. The offshore construction and development business is characterized by lengthy projects and a “long lead-time” order cycle. The change in backlog levels from one period to the next does not necessarily evidence a long-term trend.
Regions of Operations
Our Offshore Manufactured Products segment provides products and services to customers in the major offshore crude oil and natural gas producing regions of the world, including the Gulf of America, Brazil, West Africa, the North Sea, Azerbaijan, India, Southeast Asia, China, the United Arab Emirates and Australia. In addition, we provide a variety of products for use in applications outside the traditional energy industry in the United States and abroad.
Customers and Competitors
We market our products and services to a broad customer base, including end-users, engineering and design companies, prime contractors, and at times, our competitors through outsourcing arrangements. No customer in this segment represented more than 10% of our total consolidated revenue in any period presented. Our main competitors in this segment include Baker Hughes Company, Hutchinson Group (a subsidiary of Total S.A.), NOV Inc., OneSubsea (a joint venture between SLB, Aker Solutions and Subsea 7), Sparrows Offshore Group Limited and TenarisHydril (a division of Tenaris S.A.).
Completion and Production Services
Overview
For the years ended December 31, 2024, 2023 and 2022, our Completion and Production Services segment generated 24% to 31% of our consolidated revenue. Our Completion and Production Services segment includes equipment and services that are used to establish and maintain the flow of oil and natural gas from a well throughout its life cycle. In this segment, our operations primarily include completion-focused equipment and services, which are used in both onshore and offshore applications throughout the completion and production phases of a well’s life cycle. Prior to the sale of our remaining drilling rigs in August 2024, our operations included land drilling services in the United States.
Market, Services, Customers and Competitors
Demand for our completion and production services is predominantly tied to the level of oil and natural gas exploration and production activity on land in the United States. The primary driver for this activity is the price of crude oil and, to a lesser extent, natural gas. Activity levels have been, and we expect will continue to be, highly correlated with hydrocarbon commodity prices.
Our Completion and Production Services business, which is primarily marketed through the brand names Oil States Energy Services and Tempress, currently provides services used in the onshore and offshore oil and gas industry, including pressure control equipment, and downhole and extended-reach technologies.
As of December 31, 2024, we provided completion and production services through 17 locations serving our customers in the United States, including the Gulf of America, and international markets. Employees in our Completion and Production Services segment typically rig up and operate our equipment on the well site for our customers. Our equipment is primarily used during the completion and production stages of a well. We provide our services and equipment based on daily rates which vary depending on the type of equipment, the complexity of activities and the length of the job. We own patents or have patents pending covering some of our technology, particularly in our wellhead frac stack equipment and downhole extended-reach technology product lines. Our customers in this segment include major, independent and private oil and gas companies and other large oilfield service companies. No customer in this segment represented more than 10% of our total consolidated revenue in any period presented. Competition in the Completion and Production Services segment is widespread and includes many smaller companies, although we also compete with the larger oilfield service companies for certain equipment and services.
Downhole Technologies
Overview
For the years ended December 31, 2024, 2023 and 2022, our Downhole Technologies segment contributed 19% to 25% of our consolidated revenue. This segment provides oil and gas perforation systems, downhole tools and services in support of completion, intervention, wireline and well abandonment operations. This segment designs, manufactures and markets its consumable engineered products to oilfield service as well as exploration and production companies.
Market
Similar to our Completion and Production Services segment, demand for our Downhole Technologies segment products is predominantly tied to land-based oil and natural gas exploration and production activity levels in the United States and well decommissioning activity internationally. The primary drivers for this activity are the price of crude oil and, to a lesser extent, natural gas. Activity levels have been, and we expect will continue to be, highly correlated with hydrocarbon commodity prices. Demand for this segment’s products is also influenced by continued trends toward longer lateral lengths, increased frac stages and more perforation clusters to target increased unconventional well productivity.
Products
Product and service offerings for this segment utilize innovations in perforation technology through patented and proprietary systems combined with advanced modeling and analysis tools. Our expertise has led to the optimization of perforation hole size, depth, and quality of tunnels, which are key factors for maximizing the effectiveness of hydraulic fracturing. Additional offerings include proprietary toe valve and frac plug products, which are focused on zonal isolation for hydraulic fracturing of horizontal wells, and a broad range of consumable products, such as setting tools and bridge plugs, that are used in completion, intervention and decommissioning applications.
Customers and Competitors
Our customers in the Downhole Technologies segment include other oilfield services companies as well as major, independent and private oil and gas companies. No customer in this segment represented more than 10% of our total consolidated revenue in any period presented. Competition in the Downhole Technologies business is widespread and includes many smaller companies, although we also compete with the larger oilfield service companies for certain products and services.
Seasonality of Operations
Our operations are directly impacted by customer budgets and seasonal weather conditions in certain areas in which we operate, most notably in the Rocky Mountain and Northeast regions of the United States, where severe winter weather conditions can restrict access to work areas. In addition, summer and fall completion and drilling activity can be restricted due to hurricanes and other storms prevalent in the Gulf of America and along the Gulf Coast. As a result, full-year results are not likely to be a direct multiple of any particular quarter or combination of quarters.
Human Capital
Employees
As of December 31, 2024, we had a total of 2,439 full-time employees - with 60% in our Offshore Manufactured Products segment, 18% in our Completion and Production Services segment, 19% in our Downhole Technologies segment and 3% in our corporate headquarters. We were party to collective bargaining agreements covering approximately 350 employees located outside the United States as of December 31, 2024. We believe we have good labor relations with our employees.
Safety
The health and safety of our employees, contractors, business partners, visitors and the communities where we work is a cornerstone of our culture, “Safety Focus from the Top.” We are transparent in our communications about our health, safety and environmental (“HSE”) commitment to employees, contractors, vendors, suppliers and customers. We solicit input to improve our programs and employee participation is a vital element in our success.
We establish global targets in an effort to promote HSE improvement and monitor our performance through real-time reporting. Executive management and operations personnel review incidents and loss trends on a weekly basis and we update our Board no less than monthly.
We seek to encourage our employees to actively participate in HSE initiatives through safety committees, behavior-based observations, and employees stopping work if at-risk conditions are observed, among other aspects of our safety management system. We monitor global compliance with our internal policies and procedures, internationally recognized/certified management systems and all applicable national, state, local and international laws and regulations.
Our focus on safety was recognized with the 2023 NOIA Safety in Seas Culture of Safety Award, which recognizes overall organizational immersion in, and commitment to, safety through measurable and sustained safety performance over a prolonged period of time.
Our Global Workforce
We recognize that our employees are critical to our long-term success. Our operations are global and demand a multifaceted workforce, which we believe provides us with a competitive advantage and allows us to better understand and communicate with a wide population of constituents. Our strong focus on innovation necessitates an equally strong focus on technical skills and training programs, which we believe creates high performing teams that can arrive at better solutions to problems. We strive to cultivate a culture and work environment that enables us to attract, train, promote and retain a group of skilled individuals with diverse experience, backgrounds and perspectives who collectively enable us to safely provide quality, innovative solutions to our customers while remaining considerate of the environment and of our communities.
Hiring, Training and Development of our Workforce
Our employee hiring, training, career development and retention practices are key to our success. We are committed to the principles of equal employment opportunity and prohibit all forms of unlawful discrimination in accordance with applicable law. We strive to cultivate a workplace where all employees feel valued and have a sense of belonging. We recruit and train our workforce while providing competitive wages and benefits. Our industry is cyclical, leading to varying headcount needs during industry cycles. We prioritize recalling our experienced employees for manufacturing and field positions to the extent possible.
We invest in ongoing training and development of our employees through technical and non-technical courses and programs, which are regularly refreshed and designed to meet the requirements of an evolving business landscape. Employee training and development includes course work as well as on the job mentoring - emphasizing, among others matters, safety, ethical behavior, compliance with our internal policies and laws and regulations, protection of the environment, cyber and other security threats, and skills and competencies necessary for a specific position. In addition to internal training and development, we also value the benefits of continuing formal education and maintain an educational assistance program that reimburses eligible expenses from accredited institutions.
Environmental and Occupational Health and Safety Matters
Our business operations are subject to stringent environmental and occupational health and safety laws and regulations that may be imposed domestically at the federal, regional, state, tribal and local levels or by foreign governments. Numerous governmental entities, including domestically the U.S. Environmental Protection Agency (“EPA”), the federal Bureau of Alcohol, Tobacco, Firearms and Explosives (“ATF”), a law enforcement agency under the U.S. Department of Justice, the U.S. Occupational Safety and Health Administration (“OSHA”) and analogous state agencies, have the power to enforce compliance with these laws and regulations and the permits issued under them, often requiring difficult and costly actions. These laws and regulations may, among other things: (i) require the acquisition of permits to conduct drilling and other regulated activities; (ii) restrict the types, quantities and concentration of various substances that can be released into the environment or injected into subsurface formations in connection with oil and natural gas drilling and production activities and well site support services; (iii) limit or prohibit drilling activities on certain lands lying within wilderness, wetlands and other protected areas; (iv) impose stringent regulations on the licensing or storage and use of explosives; (v) require remedial measures to mitigate pollution from former and ongoing operations, such as requirements to close pits and plug abandoned wells or decommission offshore facilities; (vi) impose specific safety and health criteria addressing worker protection; and (vii) impose substantial liabilities for pollution resulting from drilling operations and well site support services.
The more significant of these existing environmental and occupational health and safety laws and regulations include the following U.S. legal standards, as amended from time to time:
•the Clean Air Act (“CAA”), which restricts the emission of air pollutants from many sources and imposes various pre-construction, operational, monitoring and reporting requirements, and that the EPA has relied upon as authority for adopting climate change regulatory initiatives relating to greenhouse gas (“GHG”) emissions;
•the Federal Water Pollution Control Act, also known as the Clean Water Act (“CWA”), which regulates discharges of pollutants from facilities to state and federal waters and establishes the extent to which waterways are subject to federal jurisdiction and rulemaking as protected waters of the United States;
•the Oil Pollution Act of 1990, which subjects owners and operators of vessels, onshore facilities, and pipelines, as well as lessees or permittees of areas in which offshore facilities are located, to liability for removal costs and damages arising from an oil spill in waters of the United States;
•U.S. Department of the Interior (“DOI”) regulations, which govern oil and natural gas operations on federal lands and waters and impose obligations for establishing financial assurances for decommissioning activities, liabilities for pollution cleanup costs resulting from operations, and liabilities for pollution damages;
•the Comprehensive Environmental Response, Compensation and Liability Act of 1980 (“CERCLA”), which imposes liability, without regard to fault or the legality of the original conduct, on generators, transporters, disposers and arrangers of hazardous substances at sites where hazardous substance releases have occurred or are threatening to occur;
•the Resource Conservation and Recovery Act (“RCRA”), which governs the generation, treatment, storage, transport, and disposal of solid wastes, including oil and natural gas exploration and production wastes and hazardous wastes;
•the Safe Drinking Water Act (“SDWA”), which ensures the quality of the nation’s public drinking water through adoption of drinking water standards and controlling the injection of waste fluids into below-ground formations that may adversely affect drinking water sources;
•the Emergency Planning and Community Right-to-Know Act, which requires facilities to implement a safety hazard communication program and disseminate information to employees, local emergency planning committees, and response departments on toxic chemical uses and inventories;
•the Occupational Safety and Health Act, which establishes workplace standards for the protection of the health and safety of employees, including the implementation of hazard communications programs designed to inform employees about hazardous substances in the workplace, potential harmful effects of these substances, and appropriate control measures;
•the Endangered Species Act (“ESA”), which restricts activities that may affect federally identified endangered and threatened species or their habitats through the implementation of operating restrictions or a temporary, seasonal, or permanent ban in affected areas;
•the National Environmental Policy Act, which requires federal agencies, including the DOI, to evaluate major agency actions having the potential to impact the environment and that may require the preparation of environmental assessments and more detailed environmental impact statements that may be made available for public review and comment;
•the U.S. Department of Transportation regulations, which relate to advancing the safe transportation of energy and hazardous materials, including explosives, and emergency response preparedness; and
•regulations adopted by the ATF, that impose stringent licensing conditions with respect to the acquisition, storage and use of explosives for well site support services in the oil and natural gas sector.
Additionally, there exist regional, state, tribal and local jurisdictions in the United States where we operate that also have, or are developing or considering developing, similar environmental and occupational health and safety laws and regulations governing many of these same types of activities. Outside of the United States, there are countries and provincial, regional, tribal or local jurisdictions therein where we are conducting business that also have, or may be developing, regulatory initiatives or analogous controls that regulate our environmental-related activities. While the legal requirements imposed in foreign countries or jurisdictions therein may be similar in form to U.S. laws and regulations, in some cases, the actual implementation of these requirements may impose additional, or more stringent, conditions or controls that can significantly restrict, delay or cancel the permitting, development or expansion of a project or significantly increase the cost of doing business. Any failure by us to comply with these laws, regulations and regulatory initiatives or controls may result in: the assessment of sanctions, including administrative, civil, and criminal penalties; the imposition of investigatory, remedial, and corrective action obligations or the incurrence of capital expenditures; the occurrence of restrictions, delays or cancellations in the permitting, development or expansion of projects; and issuance of injunctions restricting or prohibiting some or all of our activities in a particular area. We have incurred and will continue to incur operating and capital expenditures, some of which may be material, to comply with environmental and occupational health and safety laws and regulations. Historically, our environmental and worker safety compliance costs have not had a material adverse effect on our results of operations. However, there can be no assurance that such costs will not be material in the future or that such future compliance will not have a material adverse effect on our business and operational results.
We own, lease or operate numerous properties that have been used for well site support services for many years. We also have acquired certain properties supportive of oil and natural gas activities from third parties whose actions with respect to the management and disposal or release of hydrocarbons, hazardous substances or wastes at or from such properties were not under our control prior to acquiring them. Under environmental laws and regulations such as CERCLA and RCRA, we could incur strict joint and several liability due to damages to natural resources or for remediating hydrocarbons, hazardous substances or wastes disposed of or released by prior owners or operators. Moreover, an accidental release of materials into the environment during the course of our operations may cause us to incur significant costs and liabilities. We also could incur costs related to the clean-up of third-party sites to which we sent regulated substances for disposal or to which we sent equipment for cleaning, and for damages to natural resources or other claims related to releases of regulated substances at or from such third-party sites.
Over time, both in the United States and in foreign countries, the trend in environmental and occupational health and safety laws and regulations is to typically place more restrictions and limitations on activities that may adversely affect the environment or expose workers to injury. If existing regulatory requirements or enforcement policies change or new regulatory or enforcement initiatives are developed and implemented in the future, we or our customers may be required to make significant, unanticipated capital and operating expenditures. Examples of recent regulations or other regulatory initiatives in the United States include the following:
•Hydraulic fracturing. Hydraulic fracturing is typically regulated by state oil and gas commissions, but the practice continues to attract considerable public, scientific and governmental attention in certain parts of the country, resulting in increased scrutiny and regulation, including by federal agencies. At the federal level, the EPA asserted federal regulatory authority under the SDWA over certain hydraulic fracturing activities involving the use of diesel fuels and published permitting guidance for such activities. Additionally, the EPA issued a final regulation under the CWA prohibiting discharges to publicly owned treatment works of wastewater from onshore unconventional oil and gas extraction facilities. At the state level, many states have adopted legal requirements that have imposed new or more stringent permitting, public disclosure or well construction requirements on hydraulic fracturing activities, including states where our oil and gas exploration and production customers operate. States could also elect to place prohibitions on hydraulic fracturing and local governments may seek to adopt ordinances within their jurisdictions regulating the time, place or manner of drilling activities in general or hydraulic fracturing activities in particular.
•Lease development. The Biden Administration has at times called for revisions and restrictions to the leasing and permitting programs for oil and gas development on federal lands and, for a time, suspended federal oil and gas leasing activities. The Inflation Reduction Act (“IRA 2022”) contains provisions requiring particular offshore oil and gas lease sales under the 2017 - 2022 leasing program to proceed and the DOI has announced plans for those sales. In 2023, the DOI published a final offshore leasing program for 2024-2029. Although leasing has resumed, the areas offered for leasing in the 2024-2029 program are the smallest since federal offshore leasing for oil and gas development began. Future actions taken by the federal government to limit the availability of new oil and gas leases would adversely
impact the oil and gas industry and impact demand for our products and services. Separately, in April 2024, the federal Bureau of Land Management (“BLM”) finalized a rule that would limit flaring from well sites on federal lands, increase the costs associated with federal oil and gas leasing and require operators to submit a methane waste minimization plan or a self-certification statement committing the operator to capturing 100% of the gas produced from a well and pay royalties on lost gas as part of the permit application process. This rule is currently subject to litigation, its implementation has been halted in North Dakota, Texas, Utah, Montana, and Wyoming, and it is uncertain what actions the Trump Administration may take with respect to this rule, if any. Additionally, the BLM finalized a rule to update the fiscal terms of federal oil and gas leases, increasing fees, rents, royalties, and bonding requirements according to provisions in the IRA 2022.
•Induced seismicity. In recent years, wells in the United States used for the disposal by injection of flowback water or certain other oilfield fluids below ground into non-producing formations have been associated with an increased number of seismic events, with research suggesting that the link between seismic events and wastewater disposal may vary by region and local geology. The U.S. geological survey has in the recent past identified six states with the most significant hazards from induced seismicity: Oklahoma, Kansas, Texas, Colorado, New Mexico and Arkansas. In response to these concerns, regulators in some of the states in which our oil and gas exploration and production customers operate have adopted additional requirements related to seismicity and its potential association with hydraulic fracturing. For example, Oklahoma and Texas have issued rules for wastewater disposal wells that imposed certain permitting and operating restrictions and reporting requirements on disposal wells in proximity to faults. States such as Oklahoma and Texas have also issued orders, from time to time, for certain wells where seismic incidents have occurred to restrict or suspend disposal well operations. In this regard, the Texas Railroad Commission has pursued several regulatory initiatives in recent years as a result of recent seismic activity in areas of the Midland Basin, including voluntary reductions in produced water disposals through injection wells, suspending injection operations of certain deep disposal wells, and suspending all disposal well permits to inject oil and gas waste in certain areas. The Oklahoma Corporation Commission has similarly suspended certain deep disposal well operations in the recent past following earthquakes of certain magnitudes in Oklahoma. Another consequence of seismic events may be lawsuits alleging that disposal well operations have caused damage to neighboring properties or otherwise violated state and federal rules regulating waste disposal. In countries outside of the United States where we or our customers conduct operations, there may exist similar governmental restrictions or controls over well disposal activities in an effort to limit the occurrence of induced seismicity.
•Offshore marine safety. Regulatory agencies such as the federal Bureau of Safety and Environmental Enforcement and Bureau of Ocean Energy Management may issue new or amended rulemakings regarding deepwater leasing, permitting or drilling that could result in more stringent or costly restrictions, delays or cancellations to our oil and gas exploration and production customers with respect to their offshore operations or significantly increase financial assurances of operators for decommissioning of offshore facilities on the Outer Continental Shelf. Our customers’ compliance with such new, more stringent legal requirements may result in increased costs for our customers and could adversely affect, delay or curtail new or ongoing drilling and development efforts by our customers. Outside of the United States, there are countries and provincial, regional, tribal or local jurisdictions therein where our customers are conducting business that also have, or may be developing, regulatory initiatives or analogous controls that regulate the permitting and regulatory safety and performance aspects of those customers’ development and production activities, which could significantly restrict, delay or cancel the leasing, permitting, development or expansion of an offshore energy project or substantially increase the cost of doing business offshore.
•Ground-level ozone standards. In 2015, the EPA under the Obama Administration issued a final rule under the CAA, making the National Ambient Air Quality Standard (“NAAQS”) for ground-level ozone more stringent. Since that time, the EPA has issued area designations with respect to ground-level ozone and final requirements that apply to state, local and tribal air agencies for implementing the 2015 NAAQS for ground-level ozone and, more recently, in December 2020, the EPA (under the first Trump Administration) published a final action that, upon conducting a periodic review of the ozone standard in accord with CAA requirements, elected to retain the 2015 ozone NAAQS without revision on a going-forward basis. The EPA’s consideration of this standard remains ongoing. State implementation of a revised NAAQS could, among other things, require installation of new emission controls on some of our or our customers’ equipment, result in longer permitting timelines, and significantly increase our or our customers’ capital expenditures and operating costs.
•Waters of the United States. There continues to be uncertainty on the federal government’s applicable jurisdictional reach under the Clean Water Act over waters of the United States, including wetlands as the EPA and the U.S. Army Corps of Engineers (“Corps”) under the Obama, Trump and Biden Administrations have pursued multiple rulemakings since 2015 in an attempt to determine the scope of such reach. Following legal actions, implementation of the most
recent rule is currently split by jurisdiction, with 27 states subject to an injunction resulting in implementation of the pre-2015 rule taking into account the changes made by the Supreme Court decision in Sackett v. EPA. States outside the reach of that injunction are subject to a rule defining waters of the United States published in September 2023. Additionally, the Trump Administration may seek to take additional action to revise or clarify the reach of federal jurisdiction, though the substance and timing of such action cannot be predicted. Therefore, determinations regarding the reach of federal jurisdiction over waterbodies and wetlands under the CWA remain uncertain at this time. To the extent that any action further expands the scope of the CWA’s jurisdiction in areas where our customers conduct operations, such developments could delay, restrict or halt permitting or development of projects, result in longer permitting timelines, or increased compliance expenditures or mitigation costs for our customers’ operations, which may reduce the rate of production from operators.
•Climate change. In the United States, no comprehensive climate change legislation has been implemented at the federal level. However, certain federal laws, such as the IRA 2022, have been enacted to advance numerous climate-related objectives. The IRA 2022 contains hundreds of billions of dollars in incentives for the development of renewable energy, clean hydrogen, clean fuels, electric vehicles, and supporting infrastructure and carbon capture and sequestration, among other provisions. However, on January 20, 2025, President Trump issued an executive order pausing certain funding disbursements under the IRA 2022; the potential impact of this action and any future similar attempts to limit the incentives under the IRA 2022 are uncertain. Moreover the EPA has adopted rules that, among other things, establish construction and operating permit reviews for GHG emissions from certain large stationary sources, require the monitoring and annual reporting of GHG emissions from certain petroleum and natural gas system sources, and impose new standards reducing methane emissions from oil and gas operations through limitations on venting and flaring and the implementation of enhanced emission leak detection and repair requirements. In recent years, there has been considerable uncertainty surrounding regulation of methane emissions. While the Trump Administration took a number of actions to revise federal regulation of methane from the oil and natural gas sector, these actions were subsequently reversed by both the Biden Administration and Congress. The IRA 2022 also imposes the first-ever federal fee on the emission of GHGs through a methane emissions charge, which the EPA has finalized regulations to implement. Additionally, in December 2023, the EPA published a final rule that established the so-called Quad Ob new source and Quad Oc first-time existing source standards of performance under applicable agency regulations established at 40 C.F.R. Part 60 for methane and volatile organic compound emissions for the crude oil and natural gas source category. Owners or operators of affected emission units or processes will have to comply with specific standards of performance that may include leak detecting using optical gas imaging and subsequent repair requirements, reduction of regulated emissions through capture and control systems, zero-emission requirements for certain equipment or processes, operations and maintenance requirements and requirements for “green well” completions. The rules also impose expanded inspection, monitoring and emissions control requirements on oil and gas sites, as well as strengthen requirements related to emissions from equipment and routine flaring, as well as establish a “Super Emitter Response Program” that would trigger certain operator investigation and repair requirements in response to emissions events exceeding 200 pounds per hour, as detected by regulatory authorities or qualified third parties. However, the Trump Administration or Congress may take actions to revise or repeal the methane charge or the finalized EPA rules related to methane emissions, though the timing and outcome of such actions cannot be predicted. As a result, we cannot predict the scope of any final methane regulatory requirements, or the expected cost to comply with such requirements, but any such increase in regulatory scope and oversight may increase compliance expenditures or mitigation costs for our or our customers’ operations. Additionally, various states and groups of states have adopted or are considering adopting legislation, regulations or other regulatory initiatives that are focused on such areas as greenhouse gas cap and trade programs, carbon taxes, reporting and tracking programs, and restriction of emissions. At the international level, there exists the United Nations-sponsored “Paris Agreement,” which requires nations to submit non-binding GHG emissions reduction goals every five years after 2020. President Biden recommitted the United States to the Paris Agreement and, in April 2021, announced a GHG emissions reduction goal for the United States of 50% to 52% below 2005 levels by 2030. In addition, the annual Conferences of the Parties have resulted in multiple announcements, including a call for parties to eliminate certain fossil fuel subsidies and pursue further action on non-carbon dioxide GHGs, agreements to transition away from fossil fuels in energy systems and increase renewable energy capacity, and similar initiatives, though none are legally binding. However, on January 20, 2025, President Trump issued an executive order withdrawing from the Paris Agreement. The United States’ future participation in these international climate-related conferences and the degree and manner in which countries, including the United States, may implement these voluntary international climate commitments is uncertain. Litigation risks are also increasing, as a number of states, municipalities and other plaintiffs have sought to bring suit against oil and natural gas companies in state or federal court, alleging, among other things, that such energy companies created public nuisances by producing fuels that contributed to global warming effects 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. Additionally, our access to capital may be impacted by climate change policies as stockholders and bondholders currently invested in carbon-intensive energy companies concerned about the potential effects of climate change may elect in the future to shift some or all of their investments into non-fossil fuel energy related sectors. Institutional lenders who provide financing to carbon-intensive energy companies also have become more attentive to sustainable lending and investment practices that favor “clean” power sources such as wind and solar, making those sources more attractive, and some of them may elect not to provide funding for fossil fuel energy companies. Additionally, there is the possibility that financial institutions will be pressured or required to adopt policies that limit funding for fossil fuel energy companies. However, this trend has waned in recent years. In addition, the SEC has finalized a rule that would require registrants to make certain climate-related disclosures in registration statements and annual reports, including their governance of climate-related risks, material climate-related impacts on strategy, outlook and business model, climate risk management, Scope 1 and 2 GHG emissions, and if the registrant has set them, climate-related targets and goals. The implementation of this rule has been paused pending litigation, and the SEC is expected to repeal or further modify the rule; however, the timeline for any such action, if at all, is subject to uncertainty and may face additional legal challenges. Several states have also enacted or are considering enhanced climate-related disclosure requirements. Such enhanced disclosure could increase our operating costs and may also lead to reputational or other harm with customers, regulators or other stakeholders. These changes could also increase our litigation risks relating to alleged climate-related damages resulting from our operations, statements alleged to have been made by us or others in our industry regarding climate-change risks, or in connection with any future disclosures we may make regarding reported emissions, particularly given the inherent uncertainties and estimation with respect to calculation and reporting GHG emissions. The SEC has also, from time to time, focused additional scrutiny on existing climate-change related disclosures in public filings, and there is the potential for enforcement if the SEC were to allege that an issuer’s existing climate disclosures were misleading or deficient. Such public and private sector efforts have made and may continue to make it more difficult for certain of our customers’ to secure financing for their projects, which in turn may reduce the demand for our products and services. Finally, increasing concentrations of GHG in the Earth’s atmosphere may produce climate changes that have significant physical effects, such as increased frequency and severity of storms, droughts, floods, rising sea levels and other climatic events, as well as chronic shifts in temperature and precipitation patterns. For more information, see our risk factor titled “Climatic impacts could adversely impact our operations or those of our customers or suppliers.”
While we maintain insurance coverage for certain environmental and occupational health and safety risks that we believe is consistent with insurance coverage held by other similarly situated industry participants, our insurance does not cover any penalties or fines that may be issued by a government authority. In addition, it is possible that other developments, such as stricter and more comprehensive environmental and occupational health and safety laws and regulations, claims for damages to property or persons or disruption of our customers’ operations resulting from our actions or omissions, and imposition of penalties due to our operations, could have a material adverse effect on us and our results of operations.

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ITEM 1A. RISK FACTORS
Item 1A. Risk Factors
The risks described in this Annual Report on Form 10-K are not the only risks we face. Additional risks and uncertainties not currently known to us or that we currently deem to be immaterial also may materially adversely affect our business, financial condition or future results.
Business and Operating Risks
Demand for the majority of our products and services is substantially dependent on the levels of expenditures by companies in the crude oil and natural gas industry. Ongoing uncertainties related to future crude oil demand and the willingness of operators to invest in U.S. land-based drilling, completion and production activities given regulatory pressures has reduced the demand for, and the prices we are able to charge for, our products and services. This has had and may in the future have a material adverse effect on our financial condition and results of operations.
Demand for most of our products and services depends substantially on the level of capital expenditures invested in the oil and natural gas industry. Ongoing uncertainties related to future crude oil demand and the willingness of operators to invest in U.S. land-based drilling, completion and production activities given efficiencies gained and regulatory pressures have resulted in an oversupply of many of our products and services leading to competitive pressures and reduced prices we can charge our customers for these services and products. A worsening of these conditions may result in a material adverse impact on our financial condition, results of operations and cash flows.
The level of capital expenditures by companies in the crude oil and natural gas industry could remain highly volatile and have adverse effects on our business and operations due to numerous factors, including:
•worldwide demand for and supply of oil and natural gas;
•crude oil and natural gas prices;
•inflation in wages, materials, parts, equipment and other costs;
•the level of drilling and completion activity;
•the level of oil and natural gas production;
•the levels of oil and natural gas inventories;
•depletion rates;
•the expected cost of finding, developing and producing new reserves;
•delays in major offshore and onshore oil and natural gas field permitting or development timetables;
•the availability of attractive offshore and onshore oil and natural gas field prospects that may be affected by governmental actions or environmental activists that may restrict, suspend or cancel development;
•the availability of transportation infrastructure for oil and natural gas, refining capacity and shifts in end-customer preferences toward fuel efficiency and the use of natural gas;
•global weather conditions and natural disasters;
•worldwide economic activity including growth in developing countries;
•national government political requirements, including the ability and willingness of OPEC to set and maintain production levels and prices for oil and government policies which could nationalize or expropriate oil and natural gas exploration, production, refining or transportation assets;
•stockholder activism or activities by non-governmental organizations to limit or cease certain sources of funding for the energy sector or restrict the exploration, development, production and transportation of oil and natural gas;
•the impact of military actions, including, but not limited to: energy market disruptions, supply chain disruptions and increased costs, government sanctions, and delays or potential cancellation of planned customer projects;
•rapid technological change and the timing and extent of development of energy sources, including LNG as well as nuclear, solar, wind and other renewable energy sources;
•environmental and other governmental laws, regulations and executive actions; and
•U.S. and foreign tax policies, including those regarding tariffs, duties and global minimum tax rates.
Any prolonged reduction in the overall level of exploration and production activities, whether resulting from changes in oil and natural gas prices or otherwise, could have an adverse effect on our equipment utilization, revenues, cash flows and profitability; our ability to obtain additional capital to finance our business and the cost of that capital; and our ability to attract and retain skilled personnel.
We might be unable to compete successfully with other companies in our industry.
The markets in which we operate are highly competitive and certain of them, particularly those supporting U.S. land driven activities, have relatively few barriers to entry. The principal competitive factors in our markets are product, equipment and service quality, availability, responsiveness, experience, technology, safety performance and price. In some of our product and service offerings, we compete with the oil and natural gas industry’s largest oilfield service providers. These large national and multi-national companies have greater financial, technical and other resources, and greater name recognition than we do. Several of our competitors provide a broader array of services and have a stronger presence in more geographic markets. In addition, we compete with many smaller companies capable of competing effectively on a regional or local basis. Our competitors may be able to respond more quickly to new or emerging technologies and services, and changes in customer requirements. Many contracts are awarded on a bid basis, which further increases competition based on price. As a result of competition, we may lose market share or be unable to maintain or increase prices for our present products and services, or to acquire additional business opportunities, which could have a material adverse effect on our business, financial condition and results of operations.
Consolidation of our customers and competitors may impact our results of operations.
The oil and gas industry has undergone rapid consolidation, which may result in reduced capital spending by some of our customers, the acquisition of one or more of our primary customers or competitors or consolidated entities using size and purchasing power to seek pricing or other concessions, which may lead to decreased demand for our products and services. In addition, recent, ongoing and future mergers, combinations and consolidations in our industry could result in existing competitors increasing their market share. As a result, industry consolidation may have a significant negative impact on our results of operations, financial position or cash flows. We are unable to predict what effect industry consolidations may have on the pricing of our products and services, capital spending by our customers, our selling strategies, our competitive position, our ability to retain customers or our ability to negotiate favorable agreements with our customer and suppliers.
Disruption of our supply chain could adversely impact our ability to manufacture, transport and sell our products.
We and our suppliers use multiple forms of transportation to bring our products to market, including truck, ocean and air-cargo shipments. Disruption to the timely supply of raw materials, parts and finished goods or increases in the cost of transportation services, including due to general inflationary pressures, cost of fuel and labor, trade disputes, tariffs, duties, labor disputes, governmental regulation or governmental restrictions limiting specific forms of transportation, could have an adverse effect on our ability to manufacture, transport and sell our products, which would adversely affect our results of operations, cash flows and financial position.
We might be unable to employ and retain a sufficient number of key personnel.
We believe that our success depends upon our ability to employ and retain key personnel with both technical and business expertise. As observed in the U.S. shale play regions such as the Permian Basin in 2022 and 2023, during periods of increased activity, the demand for such personnel is high, and the supply is limited. When these events occur, our cost structure increases and our growth potential could be impaired. Conversely, during periods of reduced activity, such as 2024, we are forced to reduce headcount, freeze or reduce wages, and implement other cost-saving measures which could lead skilled personnel to migrate to other industries. Other opportunities in our industry and market interest in ESG and alternative energy sources may also make it more difficult for us to attract and retain employees who may prefer employment opportunities other than our business. The inability to attract, or the loss of, key personnel to competitors or companies in other industries could adversely affect us.
If we do not develop new competitive technologies and products, our business and revenues may be adversely affected.
The market for our products and services is characterized by continual technological developments to provide better performance in increasingly greater depths, higher pressure levels and harsher conditions. If we are unable to design, develop and produce commercially competitive products in a timely manner in response to changes in technology, our business and revenues will be adversely affected. Many of our competitors are large multi-national companies that may have significantly greater financial resources than we have, and they may be able to devote greater resources to research and development of new systems, services and technologies than we are able to do. In addition, competitors or customers may develop new technologies, which address similar or improved solutions to our existing technology. Additionally, the development and commercialization of new products and services requires substantial expenditures and we may not have access to needed capital at attractive rates or at all due to our financial condition, disruptions of the bank or capital markets, or other reasons beyond our control to continue these activities. Should our technologies become the less attractive solution, our operations and profitability would be negatively impacted.
Our business, results of operations and financial condition could be adversely affected by security threats, including cybersecurity threats and other disruptions.
Our information and operational technology systems, and those of our vendors, suppliers, customers and other business partners, may experience various security threats, including cybersecurity threats designed to gain unauthorized access to sensitive information or to render data or systems unusable; threats to the safety of our employees, threats to our infrastructure, or third-party infrastructure; and terrorist attacks or related threats. Cybersecurity attacks in particular are evolving and have increased in frequency. Cybersecurity attacks are becoming more sophisticated and include, but are not limited to, ransomware attacks, credential stuffing, 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. Although we devote resources to protect the systems and data we rely on in our business, including through monitoring, procedural safeguards, and employee training, our information and operational technology systems may still be subject to cyberattacks or security breaches, including as a result of employee error, malfeasance or other threats. The realization of any of these threats could lead to the unauthorized access, corruption, loss, or disclosure of proprietary and sensitive data, including
proprietary information, intellectual property, and employee or customer data. Additionally such incidents could lead to misdirected wire transfers, operational downtime, environmental damage, disruptions to key communications and services, and could significantly impair our ability to fulfill customer obligations and comply with legal and regulatory requirements. In addition, the evolving nature of data security regulations globally presents challenges, as compliance requires continual updates to our policies and practices to address new standards and avoid penalties. While we utilize various procedures and controls to monitor these security threats and mitigate our exposure to such threats and other disruptions, there can be no assurance that these procedures and controls will be sufficient in preventing security threats from materializing. No security measure is infallible. The interconnected nature of modern technology means that weaknesses or breaches within the systems of third-party vendors, suppliers, or business partners could significantly impact our operations, potentially introducing vulnerabilities into our own systems despite our safeguards. If a security breach or cyberattack were to materialize, it could lead to the loss, disclosure, or hindrance of sensitive information (including our intellectual property, and employee and customer data), critical infrastructure, personnel or capabilities essential to our operations. In addition, a cyberattack or security breach could result in liability resulting from data privacy or cybersecurity claims, liquidated or other contractual damages, regulatory penalties, damage to our reputation, significant negative press coverage, long-lasting loss of confidence in us, or additional costs for remediation and modification or enhancement of our information systems to prevent future occurrences, all of which could have a material adverse effect on our reputation, financial position, results of operations, or cash flows. As cyberattacks continue to evolve, we may be required to allocate additional resources to strengthen our cybersecurity infrastructure, enhance employee training programs, or implement emerging technologies to address new threats.
We depend on several significant customers in each of our business segments, and the loss of one or more such customers or the inability of one or more such customers to meet their obligations to us, could adversely affect our results of operations.
While no customer accounted for more than 10% of our consolidated revenues in 2024, 2023 or 2022, the loss of a significant portion of customers in any of our business segments, or a sustained decrease in demand by any of such customers, could result in a loss of revenues and could have a material adverse effect on our results of operations. In addition, the concentration of customers in one industry impacts our overall exposure to credit risk, in that customers may be similarly affected by changes in economic and industry conditions. While we perform ongoing credit evaluations of our customers, we do not generally require collateral in support of our accounts receivables.
As a result of our industry concentration, risks of nonpayment and nonperformance by our counterparties are a concern in our business. Many of our customers finance their activities through cash flow from operations, the incurrence of debt or the issuance of equity. The inability, or failure of, our significant customers to meet their obligations to us, or their insolvency or liquidation, may adversely affect our financial results.
The ongoing military actions in Europe and the Middle East could adversely affect our business, financial condition and results of operations.
The ongoing military conflicts in Europe and the Middle East could cause market and other disruptions that could adversely affect us, such as: volatility in crude oil and natural gas prices, which can adversely affect demand for our products and services; further supply chain constraints and disruptions, or increased prices for certain raw materials and component parts, such as steel and forgings, that are used in products we manufacture and other products needed by our customers in connection with their ongoing operations; instability in financial markets; higher inflation; delays or cancellations of planned projects by our customers due to rising costs; changes in currency rates; and increases in cyberattacks and espionage. In addition, governments in the European Union, the United States, the United Kingdom, Switzerland and other countries have enacted sanctions against Russia and Russian interests as a result of Russia’s invasion of Ukraine. Such sanctions, and other measures, as well as existing and potential further responses from Russia or other countries to such sanctions, could exacerbate the foregoing risks. Any of these developments could adversely affect our business, financial condition and results of operations.
Climate events could adversely impact our operations or those of our customers or suppliers.
Severe weather events in the areas in which we or our customers or suppliers operate, such as hurricanes, floods and prolonged periods of cold weather, whether from climate change or otherwise, can cause disruptions and, in some cases, delays in, or suspension of, our operations and those of our customers or suppliers. Seasonal differences in weather in the areas in which we operate, most notably in the Rocky Mountain and Northeast regions of the United States, where severe winter weather conditions occur, can also restrict our operations and those of our customers or suppliers. In addition, summer and fall completion and drilling activity can be restricted due to hurricanes and other storms prevalent in the Gulf of America and along
the Gulf Coast. As a result of these seasonal differences, full year results are not likely to be a direct multiple of any particular quarter or combination of quarters.
Many forecasters also believe that potential climate changes may have significant physical effects, such as increased frequency and severity of storms, floods and other climatic events, as well as chronic shifts in temperature and precipitation patterns, which could have an adverse effect on our or our customers’ or suppliers’ operations. These climatic developments have the potential to also cause physical damage to our assets or delays to our supply chains, which may have an adverse effect on our operations.
Any unusual or prolonged severe weather or increased frequency thereof in our or customers’ areas of operations or markets, whether due to climate change or otherwise, could have a material adverse effect on our business, results of operations and financial condition. Adverse climate events could also affect our third-party suppliers, which could limit their ability to provide us with the necessary products or raw materials to maintain operations of our facilities or services. Our planning for normal climatic variation, insurance programs and emergency recovery plans may inadequately mitigate the effects of such weather conditions, and not all such effects can be predicted, eliminated or insured against. Additionally, changing meteorological conditions, particularly temperature, may result in changes to the amount, timing or location of demand for energy or the products our customer produce, which may impact demand for our products and services.
Our inability to control the inherent risks of identifying and integrating businesses that we have or may acquire, including any related increases in debt or issuances of equity securities, could adversely affect our operations.
From time to time, we review complementary acquisition opportunities and we may seek to consummate acquisitions of such businesses in the future. However, we may not be able to identify and acquire acceptable acquisition candidates on favorable terms in the future or at all. In addition, we have in the past and may in the future incur indebtedness to finance acquisitions and also may issue equity securities in connection with such acquisitions, which could impose a significant burden on our results of operations and financial condition and could result in significant dilution to stockholders.
We expect to gain certain business, financial, and strategic advantages as a result of business combinations we undertake, including synergies and operating efficiencies. However, these transactions, and the successful integration and operation of acquired businesses, involve numerous risks. If we fail to manage any of these risks successfully, our business could be harmed. Our capitalization and results of operations may change significantly following an acquisition, and our stockholders may not have the opportunity to evaluate the economic, financial, and other relevant information that we will consider in evaluating future acquisitions.
Financial Risks
We may be adversely affected by the effects of inflation and increases in tariffs on goods we import.
Inflation in wages, materials, parts, equipment and other costs, including as a result of tariffs imposed on certain of the goods and materials we import, has the potential to adversely affect our results of operations, cash flows and financial position by increasing our overall cost structure, particularly if we are unable to achieve commensurate increases in the prices we charge our customers for our products and services. In addition, the existence of inflation in the economy has and may continue to result in higher interest rates, which could result in higher borrowing costs, supply shortages, increased costs of labor and materials, weakening exchange rates and other similar effects.
We may be unable to access the capital and credit markets or borrow on affordable terms to obtain additional capital that we may require.
We rely on our liquidity to pay our operating and capital expenditures, interest and principal payments on debt, taxes and other similar costs. Historically, we have sought to finance the operation of our business primarily with cash on-hand and cash provided by operating activities, but we have also relied on the bank and capital markets. A recession or long-term market correction could negatively impact the value of our common stock, our access to capital or our liquidity or ability to generate cash from operations in the near and long-term. If we are unable to access the bank and capital markets on favorable terms, or if we are not successful in raising capital at an attractive cost within the time period required or at all, we may not be able to grow or maintain our business, which could have a material adverse effect on our business, results of operations and financial condition.
In addition, events involving limited liquidity, defaults, non-performance or other adverse developments that affect financial institutions, transactional counterparties or other companies in the financial services industry or the financial services industry generally, or concerns or rumors about such events or other similar risks, have in the past and may in the future lead to
acute or market-wide liquidity problems. In addition, if any of our customers, suppliers or other business counterparties are unable to access funds held by such a financial institution, such parties' ability to pay their obligations to us or to enter into new commercial arrangements requiring additional payments to us could be adversely affected.
Backlog in our Offshore Manufactured Products segment is subject to unexpected adjustments and cancellations and, therefore, has limitations as an indicator of our future revenues and earnings.
The revenues projected in our Offshore Manufactured Products segment backlog may not be realized or, if realized, may not result in profits. Because of potential changes in the scope or schedule of our customers’ projects, we cannot predict with certainty when or if backlog will be realized. Material delays, cancellations or payment defaults could materially affect our financial condition, results of operations, and cash flows.
Some of the contracts in our backlog are cancellable by the customer, subject to the payment of termination fees and/or the reimbursement of our costs incurred. We typically have no contractual right to the total revenues reflected in our backlog once a project is canceled. While backlog cancellations have not been significant in the past, if commodity prices decline, we may incur additional cancellations or experience material declines in our backlog.
We may assume contractual risks in developing, manufacturing and delivering products in our Offshore Manufactured Products segment.
Many of our products from our Offshore Manufactured Products segment are ordered by customers under frame agreements or project-specific contracts. In many cases these contracts stipulate a fixed price for the delivery of our products and impose liquidated damages or late delivery fees if we do not meet specific customer deadlines. Our actual costs, and any gross profit realized on these fixed-price contracts, may vary from the expected contract economics for various reasons, including but not limited to:
•errors or omissions in estimates or bidding;
•changes in availability and cost of materials and labor, including from price inflation and supply chain disruptions;
•failures of our suppliers to deliver materials and other goods that comply with our specifications;
•variations in productivity from our original estimates;
•changes in tariffs or tax regimes; and
•material changes in foreign currency exchange rates.
These variations and the risks inherent in our projects may result in reduced profitability or losses on projects. Depending on the size of a project, variations from estimated contract performance could have a material adverse impact on our operating results.
In addition, there are other risks and liabilities associated with these contracts, such as consequential damages payable (generally as a result of our gross negligence or willful misconduct), unforeseen technical or logistical challenges in fulfilling the contracts, or warranty claims, any of which could result in our not being fully or properly compensated for the cost to develop, design, and manufacture the final product and resulting in a significant impact on our reported operating results as we progress towards completion of major jobs.
Exchange rate fluctuations could adversely affect our U.S. reported results of operations and financial position.
In the ordinary course of our business, we enter into purchase and sales commitments that are denominated in currencies that differ from the functional currency used by our operating subsidiaries. Currency exchange rate fluctuations can create volatility in our consolidated financial position, results of operations, and/or cash flows. Although we may enter into foreign exchange agreements with financial institutions in order to reduce our exposure to fluctuations in currency exchange rates, these transactions, if entered into, will not eliminate that risk entirely. To the extent that we are unable to match revenues received in foreign currencies with expenses paid in the same currency, exchange rate fluctuations could have a negative impact on our consolidated financial position, results of operations and/or cash flows. Additionally, because our consolidated financial results are reported in U.S. dollars, if we generate net revenues or earnings in countries whose currency is not the U.S. dollar, the translation of such amounts into U.S. dollars can result in an increase or decrease in the amount of our net revenues and earnings depending upon exchange rate movements. As a result, a material decrease in the value of these currencies relative to the U.S. dollar may have a negative impact on our reported results of operations and cash flows. Any currency controls implemented by local monetary authorities in countries where we currently operate could also adversely affect our business, financial condition, cash flows and results of operations.
Given the cyclical nature of our business, a severe prolonged downturn could negatively affect the value of our goodwill and other intangible assets.
As of December 31, 2024, goodwill and other intangible assets represented 7% and 13%, respectively, of our total assets. We record goodwill when the consideration we pay in acquiring a business exceeds the fair market value of the tangible and separately measurable intangible net assets of that business. We are required to at least annually review the goodwill and other intangible assets of our applicable reporting units (Offshore Manufactured Products, Completion and Production Services and Downhole Technologies) for impairment in value and to recognize a non-cash charge against earnings causing a corresponding decrease in stockholders’ equity if circumstances, some of which are beyond our control, indicate that the carrying amounts will not be recoverable.
As further discussed in Note 4, Asset Impairments and Other Charges and Credits, in 2024 we recognized a goodwill impairment charge of $10.0 million in our Downhole Technologies segment associated with the realignment of operations between our Offshore Manufactured Products and our Downhole Technologies segments. Additionally, we recognized intangible asset impairments totaling $10.8 million associated with the decision to exit a service offering in our Completion and Production Services segment.
While no other provisions for goodwill or other intangible asset impairment were recognized during 2024, it is possible that we could recognize goodwill or other intangible assets impairment losses in the future if, among other factors:
•global economic and industry conditions deteriorate;
•the outlook for future profits and cash flow for any of our reporting units deteriorate as the result of many possible factors, including, but not limited to, increased or unanticipated competition, lack of technological development, reductions in customer capital spending plans, loss of key personnel or customers, adverse legal or regulatory developments, future operating losses at a reporting unit, downward forecast revisions, or restructuring plans;
•we implement certain strategic management actions;
•costs of equity or debt capital increase further;
•laws, executive actions or regulatory initiatives are imposed, which significantly restrict, delay or otherwise reduce the drilling, completion and production of oil and natural gas wells;
•U.S. and/or foreign income tax rates increase, or regulations change;
•valuations for comparable public companies or comparable acquisition valuations deteriorate; or
•our stock price experiences a sustained decline.
Legal or Regulatory Risks
We do business in international jurisdictions which exposes us to unique risks.
A portion of our revenue and net assets are attributable to operations in countries outside the United States. Risks associated with our international operations include, but are not limited to:
•expropriation, confiscation or nationalization of assets;
•renegotiation or nullification of existing contracts;
•foreign capital controls or similar monetary or exchange limitations;
•foreign currency fluctuations;
•foreign and global minimum taxation regulations;
•tariffs and duties on imported and exported goods;
•the inability to repatriate earnings or capital in a tax efficient manner;
•changing political conditions;
•economic or trade sanctions;
•changing foreign and domestic monetary and trade policies;
•regulatory restrictions or controls more stringently applied or enforced;
•changes in trade activity;
•military or social situations, such as a widespread outbreak of an illness or other public health issues, in foreign areas where we do business, and the possibilities of war, other armed conflict or terrorist attacks; and
•regional economic downturns.
Additionally, in some jurisdictions we are subject to foreign governmental regulations favoring or requiring the awarding of contracts to local contractors, or requiring foreign contractors to employ citizens of, or purchase supplies from, a particular jurisdiction. These regulations may adversely affect our ability to compete in such jurisdictions.
The U.S. Foreign Corrupt Practices Act (the “FCPA”), and similar anti-bribery laws in other jurisdictions, including the United Kingdom Bribery Act 2010, generally prohibit companies and their intermediaries from making improper payments to foreign officials for the purpose of obtaining or retaining business. We operate in many parts of the world that have experienced governmental corruption to some degree and, in certain circumstances, strict compliance with anti-bribery laws may conflict with local customs and practices and impact our business. Any failure to comply with the FCPA or other anti-bribery legislation could subject us to civil and criminal penalties or other sanctions, which could have a material adverse impact on our business, financial condition and results of operations. We could also face fines, sanctions, and other penalties from authorities in the relevant foreign jurisdictions, including prohibition of our participating in, or curtailment of, business operations in those jurisdictions and the seizure of assets. Additionally, we may have competitors who are not subject to the same ethics-related laws and regulations which provides them with a competitive advantage over us by securing business awards, licenses, or other preferential treatment, in those jurisdictions using methods that certain ethics-related laws and regulations prohibit us from using.
The regulatory regimes in some foreign countries may be substantially different than those in the United States, and may be unfamiliar to U.S. investors. Violations of foreign laws could result in monetary and criminal penalties against us or our subsidiaries and could damage our reputation and, therefore, our ability to do business.
We use a variety of domestically produced and imported raw materials and component products, including steel, in the manufacture of our products. In 2018, the United States imposed tariffs on a variety of imported products, including steel and aluminum. In response to the U.S. tariffs on steel and aluminum, the European Union and several other countries, including Canada and China, have threatened and/or imposed retaliatory tariffs. In addition, in response to Russia’s invasion of Ukraine, governments in the European Union, the United States, the United Kingdom, Switzerland and other countries have enacted sanctions against Russia and Russian interests. In addition, the Trump Administration has proposed the imposition of certain new tariffs. The effect of these sanctions and tariffs and the application and interpretation of existing trade agreements and customs, anti-dumping and countervailing duty regulations continue to evolve, and we continue to monitor these matters. While we cannot predict with certainty the impact of any new or increased tariffs, or the impact of any retaliatory tariffs, if we encounter difficulty in procuring these raw materials and component products, or if the prices we have to pay for these products increase and we are unable to pass corresponding cost increases on to our customers, our financial position, cash flows and results of operations could be adversely affected. Furthermore, uncertainty with respect to potential costs in the drilling and completion of oil and gas wells could cause our customers to delay or cancel planned projects which, if this occurred, would adversely affect our financial position, cash flows and results of operations.
Explosive incidents arising out of dangerous materials used in our business could disrupt operations and result in bodily injuries and property damages, which occurrences could have a material adverse effect our business, results of operations and financial conditions.
Our Downhole Technologies segment operations include the licensing, storage and handling of explosive materials that are subject to regulation by the ATF and analogous state and international agencies. Despite our use of specialized facilities to store and handle dangerous materials and our performance of employee training programs, the storage and handling of explosive materials could result in explosive incidents that temporarily shut down or otherwise disrupt our or our customers’ operations or could cause restrictions, delays or cancellations in the delivery of our services. It is possible that such incidents could result in death or significant injuries to employees and other persons. Material property damage to us, our customers and third parties arising from an explosion or resulting fire could also occur. Any explosion could expose us to adverse publicity and liability for damages or cause production restrictions, delays or cancellations, any of which occurrences could have a material adverse effect on our operating results, financial condition and cash flows. Moreover, failure to comply with any applicable existing or newly established requirements, or the occurrence of an explosive incident, may also result in the loss of our ATF or analogous state and international license to store and handle explosives, which would have a material adverse effect on our business, financial condition and results of operations.
We may not have adequate insurance for potential liabilities and our insurance may not cover certain liabilities, including litigation risks.
The products that we manufacture and the services that we provide are complex, and the failure of our equipment to operate properly or to meet specifications may greatly increase our customers’ costs. In addition, many of these products are used in inherently hazardous applications where an accident or product failure can cause personal injury or loss of life, damages to property, equipment, or the environment, regulatory investigations and penalties, and the suspension or cancellation of the end-user’s operations. If our products or services fail to meet specifications, or are involved in accidents or failures, we could face warranty, contract, or other litigation claims for which we may be held responsible and our reputation for providing quality products may suffer. In the ordinary course of business, we have and may become the subject of various claims, lawsuits and administrative proceedings, seeking damages or other remedies concerning our commercial operations, products, employees and other matters, including occasional claims by individuals alleging exposure to hazardous materials as a result of our products or operations. Some of these claims may relate to the activities of businesses that we have sold, and some may relate to the activities of businesses that we have acquired, even though these activities may have occurred prior to our acquisition of such businesses.
We maintain insurance to cover many of our potential losses, and we are subject to various self-retentions and deductibles under our insurance policies. It is possible, however, that a judgment could be rendered against us in cases in which we could be uninsured and beyond the amounts that we currently have reserved or anticipate incurring for such matters. Even a partially uninsured or underinsured claim, if successful and of significant size, could have a material adverse effect on our results of operations or consolidated financial position. We also face the following other risks related to our insurance coverage:
•we may not be able to continue to obtain insurance on commercially reasonable terms;
•we may be faced with types of liabilities that will not be covered by our insurance, such as damages from environmental contamination, fines and penalties imposed for failure to comply with applicable law, terrorist attacks or acts of war;
•we may face difficulties obtaining or maintaining insurance coverage to the extent we do not meet the ESG-related conditions or requirements of our insurers;
•the counterparties to our insurance contracts may pose credit risks; and
•we may incur losses from interruption of our business or cybersecurity attacks that exceed our insurance coverage.
We might be unable to protect our intellectual property rights and we may be subject to litigation if another party claims that we have infringed upon its intellectual property rights.
We rely on a variety of intellectual property rights that we use in our businesses, including our patents and proprietary rights relating to our FlexJoint®, Merlin®, Active Seat Gate Valves, Evolv® and SmartStart Plus® technologies, and intervention and downhole extended-reach tools (including our HydroPull® tool) utilized in the completion or workover of oil and natural gas wells. The market success of our technologies will depend, in part, on our ability to obtain, secure, maintain and enforce our proprietary rights in these technologies and to safeguard our trade secrets and non-public information. We may not be able to successfully preserve these intellectual property rights and these rights could be invalidated, circumvented or challenged by third parties. In addition, we may be required to expend significant amounts of money pursuing and defending our intellectual property rights, and these proceedings may not ultimately be successful. In addition, we face risks related to the global nature of our business, as the laws of some foreign countries in which our products and services may be sold may provide less robust protection of enforcement mechanisms than those available in the United States. If any of our patents or other intellectual property rights are determined to be invalid or unenforceable, or if a court or other tribunal limits the scope of claims in a patent or fails to recognize our trade secret rights, our competitive advantages could be significantly reduced in the relevant technology, allowing competition for our customer base to increase, adversely affecting our competitive position.
In addition, the tools, techniques, methodologies, programs and components we use to provide our products and services may infringe, or be alleged to infringe, upon the intellectual property rights of others. Infringement claims, whether or not with merit, may result in significant legal and other costs, and may distract us from running our core business. Royalty payments under a license from third parties, if available, would increase our costs. If a license was not available, we might not be able to continue providing a particular service or product. Any of these developments could have a material adverse effect on our business, financial condition and results of operations.
Laws, regulations and other executive actions or regulatory initiatives regarding hydraulic fracturing could increase our costs of doing business and result in additional operating restrictions, delays or cancellations in the completion of oil and natural gas wells, or possible bans on the performance of hydraulic fracturing that may reduce demand for our products and services and could have a material adverse effect on our business, results of operations and financial condition.
Although we do not directly engage in hydraulic fracturing, a material portion of our operations support many of our oil and natural gas exploration and production customers in such activities. There exists federal regulatory initiatives and various state laws and regulations that have increased, and have the potential to further increase, the regulatory burden imposed on hydraulic fracturing. Moreover, there has existed, from time to time, the potential for new or amended laws, regulations, executive actions and other regulatory initiatives that could impose more stringent restrictions on hydraulic fracturing, including potential restrictions on hydraulic fracturing on federal lands. Additionally, the BLM has recently finalized rules to update the terms of federal oil and gas leases, including increasing the associated costs and fees. Moreover, further or different constraints may be adopted by the U.S. federal or state governments in the future, including but not limited to a delay in permitting procedures, which may reduce the desirability or viability of projects on federals lands or waters. See “Part I, Item 1. Business - Environmental and Occupational Health and Safety Matters - Hydraulic Fracturing” for more discussion on these matters. The occurrence of any one or more of these developments with respect to hydraulic fracturing in areas where our oil and natural gas exploration and production customers operate could result in potentially significant added costs to comply with requirements relating to permitting, construction, financial assurance, monitoring, recordkeeping and/or plugging and abandonment. In addition, they could experience restrictions, delays or cancellations in the pursuit of production or development activities. Any of the foregoing could reduce demand for the products and services of one or more of our business segments and have a material adverse effect on our business, financial condition and results of operations.
In countries outside of the United States, including provincial, regional, tribal or local jurisdictions therein where we conduct operations, there may exist similar governmental restrictions or controls on our customers’ hydraulic fracturing activities, which, if such restrictions or controls exist or are adopted in the future, our customers may incur significant costs to comply with such requirements or may experience restrictions, delays or cancellations in the permitting or pursuit of their operations, which could have a material adverse effect on our business, financial condition and results of operations.
Legislative and regulatory initiatives related to induced seismicity could result in operating restrictions or delays in the drilling and completion of oil and natural gas wells that may reduce demand for our products and services and could have a material adverse effect on our business, results of operations and financial condition.
Our oil and natural gas producing customers dispose of flowback water or certain other oilfield fluids gathered from oil and natural gas producing operations in accordance with permits issued by government authorities overseeing such disposal activities. In recent years, wells in the United States used for the disposal by injection of flowback water or certain other oilfield fluids below ground into non-producing formations have been associated with an increased number of seismic events. In response, regulators in states in which our customers operate have adopted additional requirements related to seismicity and its potential association with hydraulic fracturing. See “Part I, Item 1. Business-Environmental and Occupational Health and Safety Matters” for more discussion on these seismicity matters. The introduction of new environmental laws and regulations related to the disposal of wastes associated with the exploration or production of hydrocarbons could limit or prohibit the ability of our customers to utilize underground injection wells. As a result, our customers may have to limit disposal well volumes, disposal rates or locations and, in some instances those customers, or third-party disposal well operators that are used by those customers to dispose of the customers’ wastewater, may be obligated to shut down disposal wells, which developments could adversely affect our customers’ business and result in a corresponding decrease in the need for our products and services, which could have a material adverse effect on our business, results of operations and financial condition.
Imposition of laws, executive actions or regulatory initiatives to restrict, delay or cancel leasing, permitting or drilling activities in deepwaters of the United States or foreign countries may reduce demand for our services and products and have a material adverse effect on our business, financial condition, or results of operations.
A significant portion of our Offshore Manufactured Products segment provides products and services for oil and natural gas exploration and production customers operating offshore in the deepwaters of the United States and in other countries. To a lesser extent, our Completion and Production Services and Downhole Technologies segments also provide equipment and services to customers operating offshore in the deepwaters of the United States and in other countries. Regulatory agencies may issue new or amended rulemakings regarding deepwater leasing, permitting or drilling that could result in more stringent or costly restrictions, delays or cancellations in offshore oil and natural gas exploration and production activities. See “Part I, Item 1. Business - Environmental and Occupational Health and Safety Matters” for more discussion on deepwater regulatory matters.
Any new legislation, executive actions or regulatory initiatives, whether in the United States or in other countries, that impose increased costs, more stringent operational standards or result in significant delays, cancellations or disruptions in our customers’ operations, increase the risk of losing leasing or permitting opportunities, expired leases due to the time required to develop new technology, increased supplemental bonding costs, or cause our customers to incur penalties, fines, or shut-in production at one or more of their facilities, any or all of which could reduce demand for our products and services. Also, if material spill events were to occur in the future, the United States or other countries where such an event were to occur could elect to issue directives to temporarily cease drilling activities and, in any event, may from time to time issue further safety and environmental laws and regulations regarding offshore oil and natural gas exploration and development, any of which developments could have a material adverse effect on our business. We cannot predict with any certainty the full impact of any new laws, regulations, executive actions or regulatory initiatives on our customers’ drilling operations or the opportunity to pursue such operations, or on the cost or availability of insurance to cover the risks associated with such operations. The matters described above, individually or in the aggregate, could have a material adverse effect on our business, financial condition and results of operations.
We are subject to numerous environmental laws and regulations that may expose us to significant costs and liabilities.
Our operations and those of our customers in the United States and in foreign countries are subject to stringent federal, state and local legal requirements governing environmental protection. These requirements may take the form of laws, regulations, executive actions and various other legal initiatives. See “Part I, Item 1. Business - Environmental and Occupational Health and Safety Matters” for more discussion on these matters.
Compliance with these regulations and other regulatory initiatives, or any other new environmental laws and regulations could, among other things, require us or our customers to install new or modified emission controls on equipment or processes, incur longer permitting timelines, and incur increased capital or operating expenditures, which costs may be significant. Additionally, one or more of these developments that impact our oil and natural gas exploration and production customers could reduce demand for our products and services, which could have a material adverse effect on our business, financial condition and results of operations.
An accidental release of pollutants into the environment may cause us to incur significant costs and liabilities.
Our business activities present risks of incurring significant environmental costs and liabilities in our business as a result of our handling of petroleum hydrocarbons, because of air emissions and wastewater discharges related to our operations, and due to historical industry operations and waste disposal practices. Additionally, private parties, including the owners or operators of properties upon which we perform services and facilities where our wastes are taken for reclamation or disposal, also may have the right to pursue legal actions to enforce compliance as well as to seek damages for non-compliance with environmental laws and regulations or for personal injury or property or natural resource damages. Some environmental laws and regulations may impose strict liability, which means that in some situations we could be exposed to liability as a result of our conduct that was lawful at the time it occurred or the conduct of, or conditions caused by prior owners or operators of properties or other third parties. Remedial costs and other damages, including natural resources damages arising as a result of environmental laws and costs associated with changes in environmental laws and regulations could be substantial and could have a material adverse effect on our liquidity, results of operations and financial condition. We may not be able to recover some or any of these costs from insurance.
We could incur significant costs in complying with stringent occupational health and safety requirements.
We are subject to stringent federal and state laws and regulations, including the federal Occupational Safety and Health Act and comparable state statutes, whose purpose is to protect the health and safety of workers, both generally and within the Offshore Manufactured Products, Completion and Production Services and Downhole Technologies business segments. In addition, the OSHA hazard communication standard, the EPA community right-to-know regulations under Title III of the Federal Superfund Amendment and Reauthorization Act and comparable state statutes require that information be maintained concerning hazardous materials used or produced in our operations and that this information be provided to employees, state and local government authorities and citizens. We are also subject to OSHA Process Safety Management regulations, which are designed to prevent or minimize the consequences of catastrophic releases of toxic, reactive, flammable or explosive chemicals. See “Part I. Item I. Business - Environmental and Occupational Health and Safety Matters” for more discussion on these matters.
We have incurred and will continue to incur operating and capital expenditures to comply with occupational health and safety laws and regulations. Historically these costs have not had a material adverse effect on our results of operations. However, there can be no assurance that such costs will not be material in the future or that such future compliance will not have a material adverse effect on our business, financial condition and results of operation.
Our and our customers’ operations are subject to a series of risks arising out of the threat of climate change that could result in increased operating costs, limit the areas in which oil and natural gas production may occur, and reduce demand for the products and services we provide.
The threat of climate change continues to attract considerable attention in the United States and in foreign countries. Numerous proposals have been made and could continue to be made at the international, national, regional and state levels of government to monitor and limit existing emissions of GHGs as well as to restrict or eliminate such future emissions. For example, the U.S. federal government has, in recent years, issued executive orders, new legislation, and regulatory initiatives pursuing action on climate change, including the IRA 2022. However, on his first day in office, President Trump signed several Executive Orders rescinding many of the previous administration’s climate-related initiatives, including withdrawing from the Paris Agreement and pausing the disbursement of certain IRA 2022 funding. As a result, our operations as well as the operations of our oil and natural gas exploration and production customers are subject to a series of regulatory, political, financial and litigation risks and uncertainty associated with the production and processing of fossil fuels and emission of GHGs. See “Part I, Item 1. Business - Environmental and Occupational Health and Safety Matters” for more discussion on these risks.
The adoption and implementation of new or more stringent international, federal or state executive actions, legislation, regulations or 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 GHG emissions could result in increased costs of compliance or costs of consuming fossil fuels. Such legislation or regulations 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 services and products. Additionally, political, financial, reputational and litigation risks may result in our oil and natural gas customers restricting or canceling production activities, incurring liability for infrastructure damages as a result of climatic changes, or impairing the ability to continue to operate in an economic manner, which also could reduce demand for our services and products. One or more of these developments could have a material adverse effect on our business, financial condition and results of operation. Moreover, the increased competitiveness of alternative energy sources (such as wind, solar, nuclear, geothermal, tidal and biofuels), and government grants, incentives and subsidies such as those contained in the IRA 2022, could reduce demand for hydrocarbons, and therefore demand for our products and services, which would have an adverse effect on our business and results of operations.
The ESA, the Migratory Bird Treaty Act and other laws intended to protect certain species of wildlife govern our and our oil and natural gas exploration and production customers’ operations, which constraints could have an adverse impact on our ability to expand some of our existing operations or limit our customers' ability to develop new oil and natural gas wells.
In the United States, the ESA and comparable state laws were established to protect endangered and threatened species. Under the ESA, if a species is listed as threatened or endangered, restrictions may be imposed on activities adversely affecting that species’ habitat. Similar protections are offered to migratory birds under the Migratory Bird Treaty Act (“MBTA”). The U.S. Fish and Wildlife Service (“FWS”) (under the first Trump Administration) issued a final rule on January 7, 2021, which notably clarifies that criminal liability under the MBTA will apply only to actions “directed at” migratory birds, their nests, or their eggs; however, in October 2021, the FWS under the Biden Administration revoked the Trump Administration’s rule on incidental take and published an advanced notice of proposed rulemaking to codify a general prohibition on incidental take while establishing a process to regulate or permit exceptions to such a prohibition. While comments have been closed, no final action has been taken on the proposed rulemaking at this time and it is uncertain what actions, if, any, the Trump Administration may take regarding such rule. Oil and natural gas operations in our operating areas may be adversely affected by seasonal or permanent restrictions on drilling and completion activities designed to protect various wildlife, which may limit our ability to operate in protected areas. Permanent restrictions imposed to protect endangered and threatened species could prohibit drilling and completion activities in certain areas or require the implementation of expensive mitigation measures.
Moreover, the FWS may make determinations on the listing of numerous species as endangered or threatened under the ESA. For example, the FWS published a rule listing two distinct population segments of the lesser prairie-chicken under the ESA, a species found in some states where we operate, including Texas, Oklahoma and Colorado. The dunes sagebrush lizard, located in west Texas and New Mexico, has also been listed as endangered under the ESA. Further, agencies may also enact protections related to critical habitats of listed species, which require federal agencies to ensure their actions are not likely to destroy or adversely modify the critical habitat. For example, in 2023 the National Marine Fisheries Service proposed to designate certain waters in the Gulf of America as critical habitat for the Rice’s whale under the ESA. While no final action has been taken on that proposal, the designation of previously unidentified endangered or threatened species or their critical habitats could indirectly cause us to incur additional costs, cause our or our oil and natural gas exploration and production customers’ operations to become subject to operating restrictions or bans, and limit future development activity in affected areas, which could reduce demand for our products and services to those customers.
Increasing attention to ESG matters may impact our business.
Companies across all industries are facing increasing scrutiny from investors, customers, employees, regulatory bodies and other stakeholders related to their ESG practices. Companies which do not adapt to or comply with such stakeholder expectations and standards, which are evolving, or which are perceived to have not responded appropriately to the growing concern for ESG-related issues, regardless of whether there is a legal requirement to do so, may suffer from reputational damage and the business, financial condition, and/or stock price of such a company could be materially and adversely affected. Increasing attention to climate change, increasing societal expectations on companies to address climate change, and potential consumer use of substitutes to energy commodities may result in increased costs, reduced demand for our customers’ hydrocarbon products and our products and services, reduced profits, increased investigations and litigation, and negative impacts on our stock price and access to capital markets, or ability to attract and retain a talented workforce. Increasing attention to climate change, for example, may result in demand shifts for our customers’ hydrocarbon products and additional governmental investigations and private litigation against those customers.
Our Board’s Nominating, Governance and Sustainability Committee is responsible for overseeing and managing our ESG initiatives. Committee members review the implementation and effectiveness of our ESG programs and policies. We have sought to strengthen our ESG performance through certain voluntary operational strategies, including, for example (i) pursuing a goal to reduce GHG emissions generated by us; (ii) seeking to co-locate certain of our facilities and common processes, where feasible, to mitigate our GHG emission impacts; (iii) pursuing the implementation of alternative energy systems (for example, solar power) at certain of our facilities, where applicable; (iv) seeking to identify and select low-impact energy providers, where geographically available; (v) evaluating the addition of an onboard system for our trucks that would link to integral vehicle systems to reduce vehicle idling time on work locations; and (vi) purchasing alternative fueled vehicles to reduce carbon-based emissions and improved technology offerings, as fleet replacements occur from time to time, among others. Despite our governance designs to pursue and oversee these matters, however, we cannot guarantee that we will be able to implement any of the opportunities we may review or explore, or, for any opportunities we do choose to implement, to implement them successfully and within a specific timeframe or across all operational assets. Moreover, we note that even with our governance oversight in place, we may not be able to adequately identify or manage ESG-related risks and opportunities, which may include failing to achieve ESG-related strategies and goals or inadvertently increasing certain risks with some stakeholders in an attempt to address those of other stakeholders.
Also, despite any aspirational goals, we may receive pressure from investors, lenders or other groups to adopt more aggressive climate or other ESG-related goals, but we cannot guarantee that we will be able to implement such goals because of changes in activity levels, potential costs or technical or operational obstacles. Certain statements or initiatives with respect to ESG matters that we may pursue or assert are increasingly subject to heightened scrutiny from the public and governmental authorities, as well as other parties. For example, the SEC has recently taken enforcement action against companies for ESG-related misconduct, including alleged “greenwashing,” (i.e., the process of conveying misleading information or making false claims that overstate potential ESG benefits). Certain regulators, such as the SEC and various state agencies, as well as nongovernmental organizations and other private actors have filed lawsuits under various securities and consumer protection laws alleging that certain ESG statements, goals or standards were misleading, false or otherwise deceptive. 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. More recent political developments could result in increased criticism or litigation risks from certain “anti-ESG” parties, including various governmental agencies. Such sentiment may focus on our environmental or social 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 our decision-making could be subject to increasing scrutiny and objection from such anti-ESG parties. As a result, we may be subject to pressure in the media or through other means, such as governmental investigations, enforcement actions, or other proceedings, all of which could adversely affect our reputation, business, financial performance, market access and growth. Accordingly, there may be increased costs related to reviewing, implementing and managing such policies, as well as compliance and litigation risks based both on positions we do or do not take, or work we do or do not perform.
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. Currently, there are no universal standards for such scores or ratings, but the importance of sustainability evaluations is becoming more broadly accepted by investors and stockholders. Such ratings are used by some investors to inform their investment and voting decisions. Additionally, certain investors use these scores to benchmark companies against their peers and if a company is perceived as lagging, these investors may engage with companies to require improved ESG disclosure or performance. Moreover, certain members of the broader investment community may consider a company’s sustainability score as a reputational or other factor
in making an investment decision. Consequently, a low sustainability score could result in exclusion of our stock from consideration by certain investment funds, engagement by investors seeking to improve such scores and a negative perception of our operations by certain investors or other constituencies.
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, former President Biden signed the IRA 2022 into law. The IRA 2022 contains hundreds of billions of dollars 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. These incentives could further accelerate the transition of the economy away from the use of fossil fuels towards lower- or zero-carbon emissions alternatives, which could decrease demand for oil and gas and consequently adversely affect the business of our customers, thereby reducing demand for our products and services. However, on January 20, 2025, President Trump issued an executive order pausing certain funding disbursements under the IRA 2022; the potential impact of this action and any future similar attempts to limit the incentives under the IRA 2022 are uncertain. 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 CAA to impose a fee on the emission of methane from sources required to report their GHG emissions to the EPA, including those sources in the offshore and onshore petroleum and natural gas production and gathering and boosting source categories. The methane emissions charge starts in 2024 at $900 per ton of methane, increases to $1,200 in 2025, and increases to $1,500 for 2026 and each year after. Regulations to implement the methane emissions charge were finalized in November 2024. The methane emissions charge could increase our customers’ operating costs and adversely affect their businesses, thereby reducing demand for our products and services. While the Trump Administration and Congress could take action to revise or repeal the methane charge or other elements of the IRA 2022, the timing or outcome of such actions cannot be predicted.
Changes to applicable tax laws and regulations may result in our incurring additional income tax liabilities, which could have a material adverse effect on our business, results of operations and financial condition.
We are subject to various complex and evolving U.S. federal, state, local and foreign taxes. U.S. federal, state, local and foreign tax laws, policies, statutes, rules, regulations or ordinances could be implemented, interpreted, changed, modified or applied adversely to us, in each case, possibly with retroactive effect. For example, the Organisation for Economic Co-operation and Development, an international association of 38 countries that includes the United States, has adopted a set of international tax model rules known as the “Pillar Two” framework, a central component of which is the imposition of a global minimum corporate tax rate of 15%. Once we reach the Pillar Two applicable revenue thresholds, which we expect to occur no earlier than 2026, the Pillar Two rules could increase tax compliance complexity and uncertainty and result in additional administrative costs and income tax liabilities in those taxing jurisdictions where we operate that have implemented Pillar Two rules. Further, absent U.S. congressional action, the U.S. federal tax rate applicable to certain income earned by our non-U.S. subsidiaries will increase for tax years beginning after December 31, 2025, and certain taxpayer beneficial provisions of the Tax Cuts and Jobs Act will expire. All of the above contemplated and non-contemplated changes in the applicable tax rules may have a material adverse effect on our business, results of operations and financial condition.

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ITEM 1B. UNRESOLVED STAFF COMMENTS
Item 1B. Unresolved Staff Comments
None.

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ITEM 2. PROPERTIES
Item 2. Properties
We own and lease numerous manufacturing facilities, service centers, sales and administrative offices, storage yards and data processing centers in support of our worldwide operations. The following presents the location of our principal owned or leased facilities, by segment as of December 31, 2024.
Offshore Manufactured Products - Rio de Janeiro and Macae, Brazil; Aberdeen and West Lothian, Scotland; Rayong, Thailand; Singapore; Batam, Indonesia; Navi Mumbai, India; Las Palmas, Spain; Abu Dhabi, UAE; and in the United States: Arlington and Houston, Texas; Oklahoma City, Oklahoma and Houma, Louisiana.
Completion and Production Services - Houston and Midland, Texas; New Iberia, Broussard and Houma, Louisiana; Oklahoma City, Oklahoma; Casper and Rock Springs, Wyoming; Williston, North Dakota and Renton, Washington in the United States; and Red Deer, Alberta, Canada.
Downhole Technologies - Nunn, Colorado; Tulsa, Oklahoma; Millsap, Fort Worth, Lampasas and Midland, Texas; and Clearfield, Pennsylvania in the United States; and Aberdeen, Scotland.
Our principal corporate offices are located in Houston, Texas.
We believe that our leases are at competitive or market rates and do not anticipate any difficulty in leasing additional suitable space upon the expiration of our current lease terms.

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ITEM 3. LEGAL PROCEEDINGS
Item 3. Legal Proceedings
Information regarding legal proceedings is set forth in Note 15, “Commitments and Contingencies,” of the Consolidated Financial Statements included in this Annual Report on Form 10-K and is incorporated herein by reference.

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ITEM 4. MINE SAFETY DISCLOSURE
Item 4. Mine Safety Disclosures
Not applicable.
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 Purchases of Equity Securities
Common Stock Information
Our authorized common stock consists of 200,000,000 shares of common stock. There were 61,760,608 shares of common stock outstanding as of February 14, 2025. The approximate number of record holders of our common stock as of February 14, 2025 was 150. Our common stock is traded on the New York Stock Exchange (“NYSE”) under the ticker symbol “OIS”.
We have not declared or paid any cash dividends on our common stock since our initial public offering in 2001 and, while permitted, our ABL Facility limits the payment of dividends. For additional discussion of such restrictions, see “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” of this Annual Report on Form 10-K. Any future determination as to the declaration and payment of dividends will be at the discretion of our Board and will depend on then existing conditions, including our financial condition, results of operations, contractual restrictions, capital requirements, business prospects and other factors that our Board considers relevant.
Performance Graph
The following graph and table compare the cumulative five-year total stockholder return on our common stock relative to the cumulative total returns of the Standard & Poor’s 500 Stock Index, the PHLX Oil Service Sector index, an index of oil and gas related companies that represent an industry composite of our peer group, and customized peer groups of twelve companies, with the individual companies listed in footnotes (1) and (2) below, respectively for the period from December 31, 2019 to December 31, 2024. The graph and chart show the value at the dates indicated of $100 invested as of December 31, 2019 and assume the reinvestment of all dividends. The stockholder return set forth below is not necessarily indicative of future performance. The following graph and related information shall not be deemed “soliciting material” or to be “filed” with the SEC, nor shall such information be incorporated by reference into any future filing under the Securities Act or the Exchange Act, except to the extent that we specifically incorporate it by reference into such filing.
COMPARISON OF 5 YEAR CUMULATIVE TOTAL RETURN
Among Oil States International, Inc., the S&P 500 Index,
the PHLX Oil Service Sector Index, our Old Peer Group(1) and our New Peer Group(2)
2019 2020 2021 2022 2023 2024
Oil States International, Inc. $ 100.00 $ 30.78 $ 30.47 $ 45.74 $ 41.63 $ 31.02
Old Peer Group(1)
$ 100.00 $ 58.37 $ 61.40 $ 98.48 $ 99.60 $ 107.37
New Peer Group(2)
$ 100.00 $ 60.02 $ 63.17 $ 90.17 $ 97.35 $ 109.02
PHLX Oil Service Sector $ 100.00 $ 57.92 $ 69.94 $ 112.94 $ 115.10 $ 101.68
S&P 500 $ 100.00 $ 118.40 $ 152.39 $ 124.79 $ 157.59 $ 197.02
____________________
(1)The twelve companies included in our first customized peer group (“Old Peer Group”) are: Archrock, Inc., Core Laboratories N.V., Expro Group Holdings N.V., Forum Energy Technologies, Inc., Helix Energy Solutions Group, Inc., Helmerich & Payne, Inc., Innovex International, Inc., (Dril-Quip, Inc., prior to merger), NPK International, Inc. (formerly Newpark Resources, Inc.), Oceaneering International, Inc., RPC, Inc., Select Water Solutions, Inc. (formerly Select Energy Services, Inc.), and TETRA Technologies, Inc.
(2)The twelve companies included in our second customized peer group (“New Peer Group”) are: Archrock, Inc., Core Laboratories N.V., Expro Group Holdings N.V., Forum Energy Technologies, Inc., Helix Energy Solutions Group, Inc., Innovex International, Inc., (Dril-Quip, Inc., prior to merger), NPK International, Inc. (formerly Newpark Resources, Inc.), Oceaneering International, Inc., ProPetro Holding Corp., RPC, Inc., Select Water Solutions, Inc. (formerly Select Energy Services, Inc.), and TETRA Technologies, Inc.
Information used in the graph and table was obtained from Research Data Group, Inc., a source believed to be reliable, but we are not responsible for any errors or omissions in such information. Used with permission.
Unregistered Sales of Equity Securities and Use of Proceeds
None.
Purchases of Equity Securities by the Issuer and Affiliated Purchases
Period Total Number of Shares Purchased(1)
Average Price Paid per Share(1)
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans or Programs(2)
October 1 through October 31, 2024
- $ - - $ 50,000,000
November 1 through November 30, 2024
890,484 5.34 890,484 45,245,016
December 1 through December 31, 2024
730,020 5.26 730,020 41,306,216
Total 1,620,504 $ 5.30 1,620,504
____________________
(1)Average price paid per share excludes the impact of excise taxes.
(2)In February 2023, our Board approved a share repurchase program of up to $25.0 million, through February 2025. On October 24, 2024, our Board of Directors terminated our existing common stock repurchase program and replaced it with a new $50.0 million common stock repurchase authorization, which expires in October 2026. As of December 31, 2024, $8.7 million of share repurchases were made under this new authorization.

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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
Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with our Consolidated Financial Statements and related notes appearing in “Part II Item 8 Financial Statements and Supplementary Data.” This discussion contains “forward-looking statements” within the meaning of Section 27A of the Securities Act and Section 21E of the Exchange Act that are based on our current expectations, estimates and projections about our business operations. Our actual results may differ materially from those currently anticipated and expressed in such forward-looking statements as a result of numerous factors, including the known material factors set forth in “Part I, Item 1A. Risk Factors.” You should read the following discussion and analysis together with our Consolidated Financial Statements and the notes to those statements included elsewhere in this Annual Report on Form 10-K in order to understand factors, such as business combinations, charges and credit and financing transactions, which may impact comparability from period to period.
We provide a broad range of manufactured products and services to customers in the energy, industrial and military sectors through our Offshore Manufactured Products, Completion and Production Services (previously referred to as Well Site Services) and Downhole Technologies segments. Demand for our products and services is cyclical and substantially dependent upon activity levels in the oil and gas industry, particularly our customers’ willingness to invest capital in the exploration for and development of crude oil and natural gas reserves. Our customers’ capital spending programs are generally based on their cash flows and their outlook for near-term and long-term commodity prices, making demand for our products and services sensitive to expectations regarding future crude oil and natural gas prices, as well as economic growth, commodity demand and estimates of resource production and regulatory pressures.
Recent Developments
Brent and West Texas Intermediate (“WTI”) crude oil and natural gas pricing trends were as follows:
Average Price(1) for quarter ended
Average Price(1) for year ended December 31
Year March 31 June 30 September 30 December 31
Brent Crude (per bbl)
2024 $ 82.92 $ 84.68 $ 80.01 $ 74.66 $ 80.52
2023 81.01 77.99 86.65 84.01 82.47
2022 100.87 113.84 100.71 88.77 100.99
WTI Crude (per bbl)
2024 $ 77.50 $ 81.81 $ 76.43 $ 70.73 $ 76.61
2023 75.91 73.54 82.25 78.53 77.56
2022 95.18 108.83 93.06 82.79 94.90
Henry Hub Natural Gas (per MMBtu)
2024 $ 2.15 $ 2.07 $ 2.11 $ 2.44 $ 2.19
2023 2.64 2.16 2.59 2.74 2.53
2022 4.67 7.50 8.03 5.55 6.45
________________
(1)Source: U.S. Energy Information Administration (spot prices).
In 2023, we began implementing initiatives, which continued throughout 2024, to reduce costs. Management actions in 2024 included: the consolidation, relocation and exit of certain underperforming locations; the exit of certain service offerings; reductions in our U.S. work force as well as the realignment of operations discussed below. We also incurred legal and other related costs to enforce certain patents related to our proprietary technologies. As a result of these actions, our reported pre-tax results for 2024 included $24.6 million in non-cash goodwill, intangible asset and operating lease asset impairment charges as well as $13.7 million of facility consolidation and exit, patent defense and other charges.
Certain short-cycle, consumable product operations historically reported within the Offshore Manufactured Products segment (legacy frac plugs and elastomer products) were integrated into the Downhole Technologies segment in early 2024 to better align with the underlying activity demand drivers and current segment management structure, as well as provide for additional operational synergies. Historical financial data, supplemental disaggregated revenue and backlog information as of and for the years ended December 31, 2023 and 2022 (presented herein) were conformed with the 2024 segment presentation. Additionally, following the sale of its remaining U.S. land-based drilling rigs and the exit of the flowback and well testing service offering in the third quarter of 2024, our Well Site Services segment name was changed to the Completion and Production Services segment.
On February 16, 2024, we amended the ABL Facility to extend its maturity date from February 10, 2025 to February 16, 2028.
During 2024, we sold two manufacturing and service facilities that were classified as held for sale assets, generating net proceeds of $35.1 million, we purchased $14.2 million of our common stock, and we purchased $11.5 million principal amount of our 2026 Notes for $10.8 million.
In October 2024, our Board of Directors terminated our existing common stock repurchase program and replaced it with a new $50.0 million common stock repurchase authorization, which expires in October 2026.
On February 14, 2025, Brent crude oil, WTI crude oil and natural gas spot prices closed at $75.81 per barrel, $71.05 per barrel and $4.60 per MMBtu, respectively - above the fourth quarter 2024 averages. Additionally, the U.S. drilling rig count reported on February 14, 2025 was 588 rigs - comparable to the fourth quarter 2024 average.
Overview
Current and expected future pricing for WTI crude oil and natural gas and inflationary cost increases, along with expectations regarding the regulatory environment in the regions in which we operate, are factors that will continue to influence our customers’ willingness to invest capital in their businesses. Expectations for the longer-term price for Brent crude oil will continue to influence our customers’ spending related to global offshore and international drilling and development and, thus, a significant portion of the activity of our Offshore Manufactured Products segment.
Crude oil and natural gas prices and levels of demand for crude oil and natural gas are likely to remain highly volatile due to numerous factors, including: geopolitical conflicts in Europe and the Middle East, along with associated international tensions; the moderate perceived risk of a global economic recession; the levels of domestic or international crude oil and natural gas production; changes in governmental rules and regulations; sanctions; the willingness of operators to invest capital in the exploration for and development of resources; use of alternative fuels; improved vehicle fuel efficiency; timing of capital investments in alternative energy sources; a more sustained movement to electric vehicles; and the potential for ongoing supply/demand imbalances.
U.S. drilling, completion and production activity and, in turn, our financial results, are sensitive to near-term fluctuations in commodity prices, particularly U.S. crude oil and natural gas prices, given the short-term, call-out nature of our U.S. operations.
Customer spending in the natural gas shale plays has declined in recent years due to technological advancements that have led to significant amounts of natural gas being produced from prolific basins in the Northeastern United States and from associated gas produced from the drilling and completion of unconventional oil wells in the United States. However, the extended outlook for natural gas in the United States is positive with increased exports of LNG, as well as increased power needs for the technology sector, namely data centers.
Our Offshore Manufactured Products segment provides technology-driven, highly-engineered products and services for offshore oil and natural gas production systems and facilities globally, as well as certain products and services to the offshore drilling and completion markets. This segment is particularly influenced by global spending on deepwater drilling and production, which is primarily driven by our customers’ longer-term commodity demand forecasts and outlook for crude oil and natural gas prices. Approximately 90% of Offshore Manufactured Products segment sales in 2024 were driven by our customers’ capital spending for products and services used in exploratory and developmental drilling, greenfield offshore production infrastructure, and subsea pipeline tie-in and repair system applications, along with upgraded equipment for existing offshore drilling rigs and other vessels (referred to herein as “project-driven products and services”). Deepwater oil and gas development projects typically involve significant capital investments and multi-year development plans. Such projects are generally undertaken by larger exploration, field development and production companies (primarily international oil companies and state-run national oil companies) using relatively conservative crude oil and natural gas pricing assumptions. Given the long lead times associated with field development, we believe some of these deepwater projects, once approved for development, are generally less susceptible to change based on short-term fluctuations in the price of crude oil and natural gas. This segment also produces a variety of products for use in industrial, military and other applications outside the traditional energy industry. Additionally, we are investing in research and product development (and have been awarded select contracts and are bidding on additional projects) to facilitate the development of alternative energy sources, including offshore wind and deepsea mineral gathering opportunities.
Backlog reported by our Offshore Manufactured Products segment decreased to $311 million as of December 31, 2024 from $327 million as of December 31, 2023. Bookings totaled $392 million in 2024, yielding an annual book-to-bill ratio of 1.0x in 2024. This compares to total bookings of $414 million in 2023 and a book-to-bill ratio of 1.1x. The following table sets forth backlog as of the dates indicated (in millions).
Backlog as of
Year March 31 June 30 September 30 December 31
2024 $ 305 $ 300 $ 313 $ 311
2023 316 328 341 327
2022 255 232 248 300
Our Completion and Production Services segment provides completion and production services in the United States (including the Gulf of America) and internationally. Prior to the sale of its drilling rigs in August of 2024, the segment also provided land drilling services in the United States. U.S. drilling and completion activity and, in turn, our Completion and Production Services results, are sensitive to near-term fluctuations in commodity prices, particularly WTI crude oil prices, given the short-term, call-out nature of its operations. We primarily supply equipment and service personnel utilized in the completion of, and initial production from, new and recompleted wells in our U.S. operations, which are dependent primarily upon the level and complexity of drilling, completion and workover activity in our areas of operations. Well intensity and complexity have increased with the continuing transition to multi-well pads, the drilling of longer lateral wells and increased downhole pressures, along with the increased number of frac stages completed in horizontal wells.
Our Downhole Technologies segment provides oil and gas perforation systems, downhole tools and services in support of completion, intervention, wireline and well abandonment operations. This segment designs, manufactures and markets its consumable engineered products to oilfield service as well as exploration and production companies. Product and service offerings for this segment include innovations in perforation technology through patented and proprietary systems combined with advanced modeling and analysis tools. This expertise has led to the optimization of perforation hole size, depth, and quality of tunnels, which are key factors for maximizing the effectiveness of hydraulic fracturing. Additional offerings include frac plugs, toe valves and other elastomer products, which are focused on zonal isolation for hydraulic fracturing of horizontal wells, and a broad range of consumable products, such as setting tools and bridge plugs, that are used in completion, intervention and decommissioning applications. Demand drivers for the Downhole Technologies segment include continued trends toward longer lateral lengths, increased frac stages and more perforation clusters to target increased unconventional well productivity.
Demand for our completion-related products and services within our Completion and Production Services and Downhole Technologies segments is highly correlated to changes in the total number of wells drilled in the United States, total footage drilled, the number of drilled wells that are completed and changes in the drilling rig count. The following table sets forth a summary of the U.S. drilling rig count, as measured by Baker Hughes Company, as of and for the periods indicated.
As of February 14, 2025
Average for the
Year Ended December 31,
2024 2023 2022
United States Rig Count:
Land - Oil 467 473 527 557
Land - Natural gas and other 105 107 138 148
Offshore 16 19 21 18
588 599 686 723
The U.S. energy industry is primarily focused on crude oil and liquids-rich exploration and development activities in U.S. shale plays utilizing horizontal drilling and completion techniques. As of December 31, 2024, oil-directed drilling accounted for 82% of the total U.S. rig count - with the balance largely natural gas related.
We use a variety of domestically produced and imported raw materials and component products, including steel, in the manufacture of our products. In 2018, the United States imposed tariffs on a variety of imported products, including steel and aluminum. In response to the U.S. tariffs on steel and aluminum, the European Union and several other countries, including Canada and China, have threatened and/or imposed retaliatory tariffs. In addition, in response to Russia’s invasion of Ukraine, governments in the European Union, the United States, the United Kingdom, Switzerland and other countries have enacted sanctions against Russia and Russian interests. In early 2025, the Trump Administration, after taking office, proposed increases to existing U.S. tariffs as well as the imposition of certain new tariffs. The effect of these sanctions and tariffs and the application and interpretation of existing trade agreements and customs, anti-dumping and countervailing duty regulations continue to evolve, and we continue to monitor these matters. While we cannot predict with certainty the impact of any new or increased tariffs, or the impact of any retaliatory tariffs, if we encounter difficulty in procuring these raw materials and component products, or if the prices we have to pay for these products increase and we are unable to pass corresponding cost increases on to our customers, our financial position, cash flows and results of operations could be adversely affected. Furthermore, uncertainty with respect to potential costs in the drilling and completion of oil and gas wells could cause our customers to delay or cancel planned projects which, if this occurred, would adversely affect our financial position, cash flows and results of operations.
Other factors that can affect our business and financial results include but are not limited to: the general global economic environment; competitive pricing pressures; customer consolidations; labor market constraints; supply chain disruptions; inflation in wages, materials, parts, equipment and other costs; climate-related and other regulatory changes; geopolitical conflicts and tensions; management’s implementation of strategic decisions; public health crises; natural disasters; and changes in tax laws in the United States and in the international markets in which we operate. We continue to monitor the global economy, the prices of and demand for crude oil and natural gas, and the resultant impact on the capital spending plans and operations of our customers in order to plan and manage our business.
Selected Financial Data
This selected financial data should be read in conjunction with our Consolidated Financial Statements and related notes included in “Part II, Item 8. Financial Statements and Supplementary Data” of this Annual Report on Form 10-K and “Part II, Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations” in order to understand factors, such as charges, credits and financing transactions, which may impact comparability of the selected financial data.
In the first quarter of 2024, certain short-cycle manufacturing operations historically reported within the Offshore Manufactured Products segment (legacy frac plug and elastomer products) were integrated into the Downhole Technologies segment to better align with the underlying activity demand drivers and the current segment management structure, as well as provide for additional operational synergies. Historical financial data, supplemental disaggregated revenue information and related discussion and analysis as of and for the years ended December 31, 2023 and 2022 (presented herein) were conformed with the 2024 segment presentation. Additionally, following the sale of its remaining U.S. land-based drilling rigs and the exit of the flowback and well testing service offering in the third quarter of 2024, our Well Site Services segment name was changed to the Completion and Production Services segment.
Consolidated Results of Operations
The following summarizes our consolidated results of operations for the years ended December 31, 2024, 2023 and 2022 (in thousands, except per share amounts):
Variance
2024 2023 2022 2024 vs. 2023
2023 vs. 2022
Revenues:
Products $ 402,565 $ 418,550 $ 385,564 $ (15,985) $ 32,986
Services 290,023 363,733 352,142 (73,710) 11,591
692,588 782,283 737,706 (89,695) 44,577
Costs and expenses:
Product costs 314,628 328,815 307,371 (14,187) 21,444
Service costs 221,573 278,073 271,185 (56,500) 6,888
Cost of revenues (exclusive of depreciation and amortization expense presented below) 536,201 606,888 578,556 (70,687) 28,332
Selling, general and administrative expenses
95,009 94,185 96,038 824 (1,853)
Depreciation and amortization expense 54,708 60,778 67,334 (6,070) (6,556)
Impairment of goodwill
10,000 - - 10,000 -
Impairments of intangible assets
10,787 - - 10,787 -
Impairments of operating lease assets
3,767 - - 3,767 -
Other operating income, net(1)
(16,195) (2,732) (7,127) (13,463) 4,395
694,277 759,119 734,801 (64,842) 24,318
Operating (loss) income (1,689) 23,164 2,905 (24,853) 20,259
Interest expense, net (7,731) (8,189) (10,280) 458 2,091
Other income, net
1,568 849 3,315 719 (2,466)
(Loss) income before income taxes (7,852) 15,824 (4,060) (23,676) 19,884
Income tax provision (3,406) (2,933) (5,480) (473) 2,547
Net (loss) income $ (11,258) $ 12,891 $ (9,540) $ (24,149) $ 22,431
Net (loss) income per share:
Basic
$ (0.18) $ 0.20 $ (0.15)
Diluted
(0.18) 0.20 (0.15)
Weighted average number of common shares outstanding:
Basic
62,004 62,690 61,638
Diluted
62,004 63,152 61,638
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(1)During 2024, we recognized a net gain of $15.3 million associated with the sale of a previously idled facility. During 2022, we recognized a gain of $6.1 million associated with the settlement of outstanding litigation.
Segment Results of Operations
We manage and measure our business performance in three distinct operating segments: Offshore Manufactured Products, Completion and Production Services and Downhole Technologies. Supplemental financial information by operating segment for the years ended December 31, 2024, 2023 and 2022 is summarized below (in thousands):
Variance
2024 2023 2022 2024 vs. 2023
2023 vs. 2022
Revenues:
Offshore Manufactured Products
Project-driven:
Products $ 232,867 $ 235,080 $ 189,842 $ (2,213) $ 45,238
Services 123,906 112,742 98,968 11,164 13,774
356,773 347,822 288,810 8,951 59,012
Military and other products 41,127 33,889 33,560 7,238 329
397,900 381,711 322,370 16,189 59,341
Completion and Production Services
163,902 242,633 231,189 (78,731) 11,444
Downhole Technologies 130,786 157,939 184,147 (27,153) (26,208)
$ 692,588 $ 782,283 $ 737,706 $ (89,695) $ 44,577
Operating income (loss):
Offshore Manufactured Products(1)
$ 65,279 $ 56,289 $ 35,697 $ 8,990 $ 20,592
Completion and Production Services(2)
(23,225) 13,881 4,865 (37,106) 9,016
Downhole Technologies(3)
(20,904) (5,874) 2,902 (15,030) (8,776)
Corporate(4)
(22,839) (41,132) (40,559) 18,293 (573)
$ (1,689) $ 23,164 $ 2,905 $ (24,853) $ 20,259
_______________
(1)During 2024 and 2023, we recognized facility consolidation and other charges of $3.4 million and $2.5 million, respectively, within the Offshore Manufactured Products segment, associated primarily with the segment’s consolidation and relocation of certain manufacturing and service locations. During 2022, we recognized a gain of $6.1 million associated with the settlement of outstanding litigation against certain service providers.
(2)During 2024, we recognized charges of $24.3 million within the Completion and Production Services segment, associated primarily with the exit of its flowback and well testing service offering, the consolidation and exit of certain underperforming service locations, and the defense of certain patents. In 2023, we recognized $0.6 million in costs associated with the defense of certain of the segment’s patents.
(3)During 2024, we recognized a $10.0 million non-cash impairment charge within the Downhole Technologies segment related to goodwill reassigned to the business in connection with the segment realignment discussed above.
(4)During 2024, we recognized a net gain of $15.3 million within Corporate associated with the sale of a previously idled facility.
For further discussion of charges and credits recognized during the years ended December 31, 2024, 2023 and 2022, see Note 4, “Asset Impairments and Other Charges and Credits,” to the Consolidated Financial Statements included in this Annual Report on Form 10-K for additional discussion.
Year Ended December 31, 2024 Compared to Year Ended December 31, 2023
We reported a net loss for the year ended December 31, 2024 of $11.3 million, or $0.18 per share. The reported 2024 net loss included net charges and credits of $22.4 million ($22.0 million after tax, or $0.35 per share) associated with the restructuring of certain of our U.S. land-based operations, facility consolidations and closures, patent defense, personnel reductions and debt extinguishment, partially offset by a gain recognized on the sale of a previously idled facility. These results compare to net income for the year ended December 31, 2023 of $12.9 million, or $0.20 per share, which included facility consolidation charges of $2.5 million ($2.0 million after-tax, or $0.03 per share) and patent defense costs of $0.6 million ($0.5 million after-tax, or $0.01 per share).
Results of operations for 2024 reflect the impact of operators’ continued investment in offshore and international projects and associated backlog conversion, partially offset by a decline in land-based investments by our U.S. customers, competitive market conditions and management’s decision to exit certain underperforming locations and service offerings in the United States.
Revenues. Consolidated total revenues in 2024 decreased $89.7 million, or 11%, from 2023. Of this decrease, $74.4 million, or 83%, was concentrated in service offerings and locations exited by our Completion and Production Services segment over the past 15 months.
Consolidated product revenues in 2024 decreased $16.0 million, or 4%, from 2023, with the impact of a decline in U.S. customer demand for completion and perforating products partially offset by higher customer demand for military products. Consolidated service revenues in 2024 decreased $73.7 million, or 20%, from 2023. This decrease was concentrated in the United States - driven by lower land-based customer investments (particularly in natural gas basins), competitive market conditions and our exit of certain underperforming service offerings and locations during 2024, partially offset by higher offshore and international service activity.
The following table provides supplemental disaggregated revenue from contracts with customers by operating segment for the year ended December 31, 2024 and 2023 (in thousands):
Offshore Manufactured Products
Completion and Production Services
Downhole Technologies Total
Year Ended December 31 2024 2023 2024 2023 2024 2023 2024 2023
Project-driven:
Products $ 232,867 $ 235,080 $ - $ - $ - $ - $ 232,867 $ 235,080
Services 123,906 112,742 - - - - 123,906 112,742
Total project-driven 356,773 347,822 - - - - 356,773 347,822
Military and other products 41,127 33,889 - - - - 41,127 33,889
Short-cycle:
Products - - - - 128,571 149,581 128,571 149,581
Services - - 163,902 242,633 2,215 8,358 166,117 250,991
Total short-cycle
- - 163,902 242,633 130,786 157,939 294,688 400,572
$ 397,900 $ 381,711 $ 163,902 $ 242,633 $ 130,786 $ 157,939 $ 692,588 $ 782,283
By destination:
Offshore and international $ 369,535 $ 346,657 $ 46,150 $ 48,509 $ 35,163 $ 30,948 $ 450,848 $ 426,114
U.S. land 28,365 35,054 117,752 194,124 95,623 126,991 241,740 356,169
$ 397,900 $ 381,711 $ 163,902 $ 242,633 $ 130,786 $ 157,939 $ 692,588 $ 782,283
Cost of Revenues (exclusive of Depreciation and Amortization Expense). Our consolidated total cost of revenues (exclusive of depreciation and amortization expense) decreased $70.7 million, or 12%, in 2024 compared to 2023.
Consolidated product costs in 2024 decreased $14.2 million, or 4%, compared to 2023 due primarily to the reported decrease in product revenue. Consolidated service costs in 2024 decreased $56.5 million, or 20%, compared to 2023, with the impact of lower U.S. activity levels and implemented cost control measures partially offset by facility consolidation and exit costs, and severance expenses incurred in 2024.
Selling, General and Administrative Expense. Selling, general and administrative expense totaled $95.0 million in 2024, which included $2.8 million of costs associated with enforcing certain of our patents. Excluding these patent defense costs, selling, general and administrative costs decreased $1.4 million, or 1%, from the level reported in 2023, with the impact of
lower short- and long-term incentive compensation expenses and cost reduction measures partially offset by an increase in the provision for bad debt.
Depreciation and Amortization Expense. Depreciation and amortization expense decreased $6.1 million, or 10%, in 2024 compared to the prior-year period. Note 14, “Segments and Related Information,” to our Consolidated Financial Statements included in this Annual Report on Form 10-K presents depreciation and amortization expense by segment.
Impairment of Goodwill. In the first quarter of 2024, our Downhole Technologies operations recognized a non-cash impairment charge of $10.0 million related to goodwill transferred to the business in connection with the segment realignment discussed above. See Note 4, “Asset Impairments and Other Charges and Credits,” to our Consolidated Financial Statements included in this Annual Report on Form 10-K for additional discussion.
Impairments of Intangible Assets. In 2024, as a result of our decision to exit an underperforming service offering, our Completion and Production Services business recognized non-cash impairment charges of $10.8 million to reduce the carrying amount of its long-lived intangible assets to estimated fair value. See Note 4, “Asset Impairments and Other Charges and Credits,” to our Consolidated Financial Statements included in this Annual Report on Form 10-K for additional discussion.
Impairments of Operating Lease Assets. In 2024, management made strategic decisions to exit seven leased service locations within our Completion and Production Services segment and one within our Downhole Technologies segment. As a result of these decisions, our Completion and Production Services and Downhole Technologies segments recognized non-cash impairment charges totaling $3.8 million to reduce the carrying amount of the related operating lease assets. See Note 4, “Asset Impairments and Other Charges and Credits,” to our Consolidated Financial Statements included in this Annual Report on Form 10-K for additional discussion.
Other Operating Income, Net. In 2024, we recognized a net gain of $15.3 million associated with the sale of a previously idled facility. Other operating income, net for 2023 included gains on disposals of assets totaling $4.1 million, partially offset by charges of $2.5 million recognized in connection with our ongoing consolidation of certain manufacturing and service locations within our Offshore Manufactured Products segment.
Operating Income (Loss). Our consolidated operating loss was $1.7 million in 2024, which included non-cash charges of $24.6 million for goodwill, intangible asset and operating lease asset impairments, other charges totaling $13.7 million associated with facility consolidations and exits, patent defense and other management actions, and a net gain of $15.3 million on the sale of an idled facility. This compares to consolidated operating income of $23.2 million in 2023, which included facility consolidation and other charges of $3.1 million. Excluding these charges, operating results declined $5.0 million year-over-year, driven by the substantial decline in activity levels in the United States during 2024.
Interest Expense, Net. Net interest expense totaled $7.7 million in 2024, which compares to $8.2 million in 2023. Interest expense as a percentage of total debt outstanding was approximately 7% in 2024 and 2023.
Income Tax. For 2024, our income tax provision was $3.4 million, which included the impact of a goodwill impairment charge, other non-deductible expenses and an increase in valuation allowances recorded against deferred tax assets, on a pre-tax loss of $7.9 million. This compares to an income tax provision of $2.9 million, which included the impact of certain non-deductible expenses, discrete tax items and a reduction in valuation allowances recorded against deferred tax assets, on pre-tax income of $15.8 million for 2023.
Other Comprehensive Income (Loss). Reported comprehensive income (loss) is the sum of reported net income (loss) and other comprehensive income (loss). Other comprehensive loss was $9.5 million in 2024 compared to comprehensive income of $9.0 million in 2023 due to fluctuations in foreign currency exchange rates compared to the U.S. dollar for certain of the international operations of our operating segments. For 2024 and 2023, currency translation adjustments recognized as a component of other comprehensive income (loss) were primarily attributable to the United Kingdom and Brazil. During 2024, the exchange rates for both the British pound and the Brazilian real weakened compared to the U.S. dollar. This compares to 2023, when the exchange rates for both the British pound and the Brazilian real strengthened compared to the U.S. dollar.
Segment Operating Results
Offshore Manufactured Products
Revenues. Our Offshore Manufactured Products segment revenues increased $16.2 million, or 4%, in 2024 compared to 2023 due primarily to increased demand for international and offshore-project driven services and military products.
Operating Income. Our Offshore Manufactured Products segment reported operating income of $65.3 million in 2024, which included $3.4 million in facility consolidation and other charges. This compares to operating income of $56.3 million in 2023, which included $2.5 million in facility consolidation and other charges. Excluding these charges, the Offshore Manufactured Products segment’s operating income increased $9.9 million year-over-year due to the reported revenue growth in 2024 and a favorable shift in revenue mix.
Backlog. Backlog in our Offshore Manufactured Products segment totaled $311 million as of December 31, 2024 compared to $327 million as of December 31, 2023. Bookings during 2024 were $392 million, yielding a book-to-bill ratio of 1.0x.
Completion and Production Services
Revenues. Our Completion and Production Services segment revenues decreased $78.7 million, or 32%, in 2024 compared to 2023, driven primarily by lower U.S. customer activity levels (particularly in natural gas basins), competitive market conditions and the exit of two underperforming service offerings and four additional underperforming service facilities during 2024.
Operating Income (Loss). Our Completion and Production Services segment reported an operating loss of $23.2 million in 2024, which included charges totaling $24.3 million associated with the exit of certain service offerings, facility consolidations and exits, the defense of patents and other management actions. This compares to operating income of $13.9 million in 2023, which included patent defense costs of $0.6 million. Excluding these charges, the Completion and Production Services segment’s operating results declined $13.4 million from the prior-year period, with the impact of a decrease in U.S. land-based revenues partially offset by implemented cost control measures.
The segment’s U.S. land-based service offerings and facilities exited during 2024 collectively generated revenues of $40.6 million and operating losses of $19.6 million in 2024, which included intangible and operating lease asset impairment, facility closure and other charges totaling $21.1 million as well as depreciation and amortization expense of $7.9 million.
Downhole Technologies
Revenues. Our Downhole Technologies segment revenues decreased $27.2 million, or 17%, in 2024 from 2023 due to lower U.S. customer demand for completion and perforating products during 2024.
Operating Loss. Our Downhole Technologies segment reported an operating loss of $20.9 million in 2024, which included the $10.0 million non-cash goodwill impairment charge related to the segment realignment in the first quarter of 2024 and $1.2 million in charges related to the exit of a facility, personnel reductions and a customer bankruptcy. This compares to an operating loss of $5.9 million reported in 2023. Excluding the 2024 charges discussed above, the Downhole Technologies segment’s operating loss increased $3.9 million from the prior-year period, due primarily to the reported decrease in revenue and lower manufacturing volumes.
Corporate
Operating Loss. Corporate expenses in 2024 decreased $18.3 million, or 44%, from 2023, due primarily to the recognition in 2024 of a net gain of $15.3 million associated with the sale of a previously idled facility and lower short- and long-term incentive compensation expense.
Year Ended December 31, 2023 Compared to Year Ended December 31, 2022
We reported net income for the year ended December 31, 2023 of $12.9 million, or $0.20 per share, which included facility consolidation charges of $2.5 million ($2.0 million after-tax, or $0.03 per share) and patent defense costs of $0.6 million ($0.5 million after-tax, or $0.01 per share). These results compare to a net loss for the year ended December 31, 2022 of $9.5 million, or $0.15 per share, which included a gain of $6.1 million ($4.6 million after-tax, or $0.07 per share) recognized in connection with the settlement of a litigation matter.
Increased capital investments by our offshore and international customers, together with our internal cost control and strict capital discipline measures and other corporate actions, resulted in improvements in our consolidated results in 2023. The favorable impact of continued growth in offshore and international project activity and associated backlog conversion was partially offset by the impact of an industry-wide decline in U.S. well completions (the U.S. year-end rig count declined 20% from December 2022) - triggered by weaker commodity prices.
Revenues. Consolidated total revenues in 2023 increased $44.6 million, or 6%, from 2022.
Consolidated product revenues in 2023 increased $33.0 million, or 9%, from 2022, driven primarily by higher customer demand for project-driven production facility and connector products. Consolidated service revenues in 2023 increased $11.6 million, or 3%, from 2022 due primarily to increased customer project spending internationally.
The following table provides supplemental disaggregated revenue from contracts with customers by operating segment for the years ended December 31, 2023 and 2022 (in thousands):
Offshore Manufactured Products
Completion and Production Services
Downhole Technologies Total
Year Ended December 31
2023 2022 2023 2022 2023 2022 2023 2022
Project-driven:
Products $ 235,080 $ 189,842 $ - $ - $ - $ - $ 235,080 $ 189,842
Services 112,742 98,968 - - - - 112,742 98,968
Total project-driven 347,822 288,810 - - - - 347,822 288,810
Military and other products 33,889 33,560 - - - - 33,889 33,560
Short-cycle:
Products - - - - 149,581 162,161 149,581 162,161
Services - - 242,633 231,189 8,358 21,986 250,991 253,175
Total short-cycle - - 242,633 231,189 157,939 184,147 400,572 415,336
$ 381,711 $ 322,370 $ 242,633 $ 231,189 $ 157,939 $ 184,147 $ 782,283 $ 737,706
By destination:
Offshore and international $ 346,657 $ 297,472 $ 48,509 $ 46,977 $ 30,948 $ 31,277 $ 426,114 $ 375,726
U.S. land 35,054 24,898 194,124 184,212 126,991 152,870 356,169 361,980
$ 381,711 $ 322,370 $ 242,633 $ 231,189 $ 157,939 $ 184,147 $ 782,283 $ 737,706
Cost of Revenues (exclusive of Depreciation and Amortization Expense). Our consolidated total cost of revenues (exclusive of depreciation and amortization expense) increased $28.3 million, or 5%, in 2023 compared to 2022.
Consolidated product costs in 2023 increased $21.4 million, or 7%, compared to 2022 due primarily to the reported revenue growth as well as higher material, transportation, labor and other costs. Consolidated service costs in 2023 increased $6.9 million, or 3%, compared to 2022, due primarily to the impact of higher revenue levels and increased labor and other costs.
Selling, General and Administrative Expense. Selling, general and administrative expense was $94.2 million in 2023, which included $0.6 million of legal and other costs associated with enforcing certain of our patents. Excluding these patent defense costs, selling, general and administrative costs decreased $2.4 million, or 3%, from 2022, due primarily to reductions in short-term incentive compensation and bad debt expenses.
Depreciation and Amortization Expense. Depreciation and amortization expense decreased $6.6 million, or 10%, in 2023 compared to the prior-year period, due to certain intangible assets reaching the end of their economic life coupled with reduced capital investments made in our Completion and Production Services segment in recent years. Note 14, “Segments and Related Information,” to our Consolidated Financial Statements included in this Annual Report on Form 10-K presents depreciation and amortization expense by segment.
Other Operating Income, Net. In 2023, other operating income, net included gains on disposals of assets totaling $4.1 million, partially offset by charges of $2.5 million recognized in connection with our ongoing consolidation of certain manufacturing and service locations within our Offshore Manufactured Products segment. Other operating income, net for 2022 included a gain of $6.1 million recognized in connection with the settlement of outstanding litigation against certain service providers within our Offshore Manufactured Products segment.
Operating Income. Our consolidated operating income was $23.2 million in 2023, which included the $2.5 million in facility consolidation charges reported within other operating income, net and the $0.6 million in patent defense costs reported within selling, general and administrative expense. This compares to a consolidated operating income of $2.9 million in 2022, which included the $6.1 million gain (discussed above) recognized within other operating income, net. Excluding these charges and prior-year litigation gain, operating income increased $29.4 million year-over-year.
Interest Expense, Net. Net interest expense totaled $8.2 million in 2023, which compares to $10.3 million in 2022. Interest expense as a percentage of total debt outstanding was approximately 7% in 2023, compared to 6% in 2022.
Income Tax. For 2023, our income tax provision was $2.9 million, which included the impact of certain non-deductible expenses, discrete tax items and reductions in valuation allowances recorded against deferred tax assets, on pre-tax income of $15.8 million. This compares to an income tax provision of $5.5 million, which included the impact of certain non-deductible expenses and discrete tax items, on a pre-tax loss of $4.1 million for 2022.
Other Comprehensive Income (Loss). Reported comprehensive income (loss) is the sum of reported net income (loss) and other comprehensive income (loss). Other comprehensive income was $9.0 million in 2023 compared to a comprehensive loss of $12.9 million in 2022 due to fluctuations in foreign currency exchange rates compared to the U.S. dollar for certain of the international operations of our operating segments. For 2023 and 2022, currency translation adjustments recognized as a component of other comprehensive income (loss) were primarily attributable to the United Kingdom and Brazil. During 2023, the exchange rates for the British pound and the Brazilian real strengthened compared to the U.S. dollar. In 2022, the exchange rate for the British pound weakened compared to the U.S. dollar, while the Brazilian real strengthened compared to the U.S. dollar.
Segment Operating Results
Offshore Manufactured Products
Revenues. Our Offshore Manufactured Products segment revenues increased $59.3 million, or 18%, in 2023 compared to 2022 due primarily to increased demand for international and offshore-project driven products and services.
Operating Income. Our Offshore Manufactured Products segment reported operating income of $56.3 million in 2023, which included the $2.5 million in facility consolidation charges discussed above. This compares to operating income of $35.7 million in 2022, which included a $6.1 million gain recognized in connection with the settlement of outstanding litigation. Excluding the facility consolidation charges and 2022 litigation gain, operating income increased $29.2 million year-over-year due primarily to the Offshore Manufactured Products segment’s reported revenue growth and lower bad debt expense, partially offset by the impact of higher material, transportation, labor and other costs.
Backlog. Backlog in our Offshore Manufactured Products segment totaled $327 million as of December 31, 2023 compared to $300 million as of December 31, 2022. Bookings during 2023 totaled $414 million, yielding a year-to-date book-to-bill ratio of 1.1x.
Completion and Production Services
Revenues. Our Completion and Production Services segment revenues increased $11.4 million, or 5%, in 2023 compared to 2022, driven primarily by higher U.S. customer activity levels during the first half of 2023.
Operating Income. Our Completion and Production Services segment reported operating income of $13.9 million in 2023, compared to operating income of $4.9 million in 2022. Excluding the 2023 patent defense costs, the Completion and Production Services segment’s operating results improved $9.6 million from the prior-year period, due to the reported revenue growth and a $3.2 million decrease in depreciation and amortization expense, partially offset by increased labor, material and other costs.
Downhole Technologies
Revenues. Our Downhole Technologies segment revenues decreased $26.2 million, or 14%, in 2023 from 2022 due primarily to lower U.S. customer demand for perforating and completion products.
Operating Loss. Our Downhole Technologies segment reported an operating loss of $5.9 million in 2023, compared to operating income of $2.9 million reported in 2022. This year-over-year decrease in operating results is due primarily to the reported decrease in the Downhole Technologies segment’s revenue, $1.1 million in incremental non-cash provisions for excess and obsolete inventory as well as higher labor, material and other costs.
Corporate
Operating Loss. Corporate expenses in 2023 increased $0.6 million, or 1%, from 2022, with the impact of higher personnel and marketing costs partially offset by lower short-term incentive compensation and professional service expenses.
Liquidity, Capital Resources and Other Matters
Our primary liquidity needs are to fund operating and capital expenditures, new product development and general working capital needs. In addition, capital has been used to repay debt, fund share repurchases and fund strategic business acquisitions. Our primary sources of funds are cash flow from operations, asset sales and proceeds from borrowings under our ABL Facility and, less frequently, capital markets transactions.
Operating Activities
Cash flows from operations totaled $45.9 million during 2024, compared to $56.6 million generated by operations during 2023.
During 2024, $10.7 million was used to fund net working capital increases, primarily due to a decrease in accounts payable and accrued short- and long-term cash incentive compensation as well as an activity-driven increase in inventories, partially offset by the favorable impact of an increase in deferred revenue and a decrease in accounts receivable. During 2023, $21.0 million was used to fund net working capital increases, primarily due to increases in inventories as well as decreases in accounts payable, accrued liabilities and deferred revenue, partially offset by a decrease in accounts receivable.
Investing Activities
Within our Offshore Manufactured Products segment, we completed the consolidation of certain facilities in Houston, Texas during 2023 and strategically relocated our Asian manufacturing and service operations from Singapore to Batam, Indonesia. With these consolidations, facilities classified as held for sale within prepaid expenses and other current assets as of December 31, 2023 were sold during 2024 for net proceeds of $35.1 million.
Given these and other sales proceeds, net cash of $2.7 million was provided by investing activities during 2024, compared to $25.6 million used in investing activities during 2023.
Capital expenditures totaled $37.5 million and $30.7 million during 2024 and 2023, respectively. These investments were offset by proceeds from the sale of property, equipment and asset held for sale of $40.7 million and $5.3 million during 2024 and 2023, respectively.
Including investments associated with the continuing construction of a new facility in Batam, we expect to invest approximately $25 million in capital expenditures during 2025. We plan to fund our capital expenditures with available cash, internally generated funds and, if necessary, borrowings under our ABL Facility discussed below.
Financing Activities
During 2024, net cash of $29.5 million was used in financing activities, which included the repurchase of $14.2 million of our common stock and the purchase of $11.5 million principal amount of our outstanding 2026 Notes for $10.8 million in cash. This compares to $26.7 million of cash used in financing activities during 2023, which included the repayment of the $17.3 million principal amount outstanding under our 2023 Notes and the repurchase of $6.9 million of our common stock.
As of December 31, 2024, we had cash and cash equivalents totaling $65.4 million, which compared to $47.1 million as of December 31, 2023.
As of December 31, 2024, we had no borrowings outstanding under our ABL Facility, $123.5 million principal amount of our 2026 Notes outstanding and other debt of $2.8 million. Our reported interest expense included amortization of deferred financing costs of $1.5 million during 2024. For 2024, our contractual cash interest expense was $7.3 million, or approximately 6% of the average principal balance of debt outstanding.
We believe that cash on-hand, cash flow from operations and borrowing capacity available under our ABL Facility will be sufficient to meet our liquidity needs in the coming twelve months. If our plans or assumptions change, or are inaccurate, we may need to raise additional capital. Our ability to obtain capital for additional projects to implement our growth strategy over the longer term will depend upon our future operating performance, financial condition and, more broadly, on the availability of equity and debt financing. Capital availability will be affected by prevailing conditions in our industry, the global economy, the global banking and financial markets, stakeholder scrutiny of ESG matters and other factors, many of which are beyond our control. For companies like ours that support the energy industry, disruptions affecting the availability of capital have in the past and may in the future negatively impact the value of our common stock and may reduce our ability to access capital in the bank and capital markets or result in such capital being available on less favorable terms, which could negatively affect our liquidity.
On March 6, 2024, the SEC finalized rules relating to the disclosure of a range of climate-related information (the “Rules”). The Rules were temporarily stayed by the SEC on April 4, 2024 pending judicial review. While subject to ongoing litigation, these new disclosure requirements are currently effective for us beginning with the year ending December 31, 2026, phased in over a five-year period. The ultimate impact on our business is uncertain but we and our customers may incur increased compliance costs related to the assessment and disclosure of climate-related risks. We may also face increased litigation risks related to disclosures made pursuant to the Rules if finalized as proposed. In addition, enhanced climate disclosure requirements could accelerate the trend of certain stakeholders and lenders in restricting access to capital or seeking more stringent conditions with respect to their investments in us, our customers and other companies like ours that support the energy industry. For more information on our risks related to climate change, see the risk factors in “Part I, Item 1A. Risk Factors” included in this Annual Report on Form 10-K titled, “Our and our customers’ operations are subject to a series of risks arising out of the threat of climate change that could result in increased operating costs, limit the areas in which oil and natural gas production may occur, and reduce demand for the products and services we provide,” “The Inflation Reduction Act of 2022 could accelerate the transition to a low carbon economy and could impose new costs on our customers’ operations” and “Increasing attention to ESG matters may impact our business.”
Stock Repurchase Program. In February 2023, our Board of Directors authorized $25.0 million for repurchases of our common stock, par value $0.01 per share, through February 2025. On October 24, 2024, our Board of Directors terminated our existing common stock repurchase program and replaced it with a new $50.0 million common stock repurchase authorization, which expires in October 2026. Subject to applicable securities laws, such purchases will be at such times and in such amounts as we deem appropriate.
During the year ended December 31, 2024, $14.2 million in repurchases of common stock were made under these programs. The amount remaining under our new share repurchase authorization as of December 31, 2024 was $41.3 million.
Revolving Credit Facility. Our senior secured credit facility provides for a $125.0 million asset-based revolving credit facility (as amended, the “ABL Facility”) under which credit availability is subject to a borrowing base calculation. On February 16, 2024, we amended the ABL Facility to extend the maturity date to February 16, 2028.
The ABL Facility is governed by a credit agreement, as amended, with Wells Fargo Bank, National Association, as administrative agent and the lenders and other financial institutions from time to time party thereto (as amended, the “ABL Agreement”). The ABL Agreement matures on February 16, 2028 with a springing maturity 91 days prior to the maturity of any outstanding indebtedness with a principal amount in excess of $17.5 million. See Note 7, “Long-term Debt,” to the Consolidated Financial Statements included in this Annual Report on Form 10-K for further information regarding the ABL Agreement.
As of December 31, 2024, we had $15.9 million of outstanding letters of credit, but no borrowings outstanding under the ABL Agreement. The total amount available to be drawn as of December 31, 2024 was $57.2 million, calculated based on the then-current borrowing base less outstanding letters of credit.
2026 Notes. We issued $135.0 million aggregate principal amount of the 2026 Notes pursuant to an indenture, dated as of March 19, 2021 (the “2026 Indenture”), between us and Computershare Trust Company, National Association, as successor trustee. As of December 31, 2024, we have purchased a cumulative $11.5 million principal amount of the 2026 Notes for $10.8 million in cash, with $123.5 million principal amount outstanding. The outstanding 2026 Notes will mature on April 1, 2026, unless earlier repurchased, redeemed or converted.
The 2026 Indenture contains certain events of default, including certain defaults by us with respect to other indebtedness of at least $40.0 million. See Note 7, “Long-term Debt,” to the Consolidated Financial Statements included in this Annual Report on Form 10-K for further information regarding the 2026 Notes. As of December 31, 2024, none of the conditions allowing holders of the 2026 Notes to convert, or requiring us to repurchase the 2026 Notes, had been met.
2023 Notes. On February 15, 2023, our 2023 Notes matured and the outstanding $17.3 million in principal amount was repaid in full.
Our total debt represented 16% of our combined total debt and stockholders’ equity as of December 31, 2024 and December 31, 2023.
Contractual Obligations. As discussed above, we believe that cash on-hand, cash flow from operations and borrowing capacity under our ABL facility will be sufficient to meet our liquidity needs in the coming twelve months. The following summarizes our more significant contractual obligations as of December 31, 2024, and the effect such obligations are expected to have on our liquidity and cash flow over the next five years (in thousands):
Payments due by year
Total 2025
2026 and 2027
2028 and 2029
After 2029
Contractual obligations
ABL Facility(1)
$ - $ - $ - $ - $ -
2026 Notes(2)
132,299 5,866 126,433 - -
Other debt and finance lease obligations 2,782 633 1,193 704 252
Operating lease liabilities(3)
29,352 8,797 12,519 6,707 1,329
Purchase obligations(4)
93,202 89,633 3,569 - -
Total contractual cash obligations $ 257,635 $ 104,929 $ 143,714 $ 7,411 $ 1,581
____________________
(1)As of December 31, 2024, we had no borrowings outstanding under our ABL Facility. The total amount available to be drawn as of December 31, 2024 was $57.2 million.
(2)Amount represents the full principal amount of the 2026 Notes together with cash interest payments due semi-annually.
(3)Amount represents payment obligations (including implied interest) for operating leases with an initial term of greater than twelve months. Operating lease obligations are recorded in the consolidated balance sheet as operating lease liabilities while the right-of-use assets are included within operating lease assets.
(4)Our purchase obligations primarily relate to open purchase orders.
Contingencies and Other Obligations. We are a party to various pending or threatened claims, lawsuits and administrative proceedings seeking damages or other remedies concerning our commercial operations, products, employees and other matters.
See Note 15, “Commitments and Contingencies,” to the Consolidated Financial Statements included in this Annual Report on Form 10-K for additional discussion.
Availability and Cost of Products. We use a variety of domestically produced and imported raw materials and component products, including steel, in the manufacture of our products. In 2018, the United States imposed tariffs on a variety of imported products, including steel and aluminum. In response to the U.S. tariffs on steel and aluminum, the European Union and several other countries, including Canada and China, have threatened and/or imposed retaliatory tariffs. In addition, in response to Russia’s invasion of Ukraine, governments in the European Union, the United States, the United Kingdom, Switzerland and other countries have enacted sanctions against Russia and Russian interests. In early 2025, the Trump Administration, after taking office, proposed increases to existing U.S. tariffs as well as the imposition of certain new tariffs. The effect of these sanctions and tariffs and the application and interpretation of existing trade agreements and customs, anti-dumping and countervailing duty regulations continue to evolve, and we continue to monitor these matters. While we cannot predict with certainty the impact of any new or increased tariffs, or the impact of any retaliatory tariffs, if we encounter difficulty in procuring these raw materials and component products, or if the prices we have to pay for these products increase and we are unable to pass corresponding cost increases on to our customers, our financial position, cash flows and results of operations could be adversely affected. Furthermore, uncertainty with respect to potential costs in the drilling and completion of oil and gas wells could cause our customers to delay or cancel planned projects which, if this occurred, would adversely affect our financial position, cash flows and results of operations.
Tax Matters. See Note 2, “Summary of Significant Accounting Policies,” and Note 10, “Income Taxes,” to the Consolidated Financial Statements included in this Annual Report on Form 10-K for additional information with respect to tax matters.
Off-Balance Sheet Arrangements. As of December 31, 2024, we had no off-balance sheet arrangements.
Critical Accounting Policies
Our Consolidated Financial Statements included in this Annual Report on Form 10-K have been prepared in accordance with accounting principles generally accepted in the United States (“GAAP”), which require that we make numerous estimates and assumptions. Actual results could differ from those estimates and assumptions, thus impacting our reported results of operations and financial position. The critical accounting policies and estimates described in this section are those that are most
important to the depiction of our financial condition and results of operations and the application of which requires our most subjective judgments in making estimates about the effect of matters that are inherently uncertain. We describe our significant accounting policies more fully in Note 2, “Summary of Significant Accounting Policies,” to the Consolidated Financial Statements included in this Annual Report on Form 10-K.
Revenue and Cost Recognition
Our revenue contracts may include one or more promises to transfer a distinct good or service to the customer, which is referred to as a “performance obligation,” and to which revenue is allocated. We recognize revenue and the related cost when, or as, the performance obligations are satisfied. The majority of our significant contracts for custom engineered products have a single performance obligation as no individual good or service is separately identifiable from other performance obligations in the contracts. For contracts with multiple distinct performance obligations, we allocate revenue to the identified performance obligations in the contract. Our product sales terms do not include significant post-performance obligations.
Our performance obligations may be satisfied at a point in time or over time as work progresses. Revenues from goods and services transferred to customers at a point in time accounted for approximately 33%, 34% and 35% of consolidated revenues for the years ended December 31, 2024, 2023 and 2022, respectively. The majority of our revenue recognized at a point in time is derived from short-term contracts for standard products offered by us. Revenue on these contracts is recognized when control over the product has transferred to the customer. Indicators we consider in determining when transfer of control to the customer occurs include: right to payment for the product, transfer of legal title to the customer, transfer of physical possession of the product, transfer of risk and customer acceptance of the product.
Revenues from products and services transferred to customers over time accounted for approximately 67%, 66% and 65% of consolidated revenues for the years ended December 31, 2024, 2023 and 2022, respectively. The majority of our revenue recognized over time is for services provided under short-term contracts, with revenue recognized as the customer receives and consumes the services provided by our segments. In addition, we manufacture certain products to individual customer specifications under short-term contracts for which control passes to the customer as the performance obligations are fulfilled and for which revenue is recognized over time.
For significant project-related contracts involving custom engineered products within the Offshore Manufactured Products segment (also referred to as “project-driven products”), revenues are typically recognized over time using an input measure such as the percentage of costs incurred to date relative to total estimated costs at completion for each contract (cost-to-cost method). Contract costs include labor, material and overhead. We believe this method is the most appropriate measure of progress on large contracts. Billings on such contracts in excess of costs incurred and estimated profits are classified as a contract liability (deferred revenue). Costs incurred and estimated profits in excess of billings on these contracts are recognized as a contract asset (a component of accounts receivable).
Contract estimates for project-related contracts involving custom engineered products are based on various assumptions to project the outcome of future events that may span several years. Changes in assumptions that may affect future project costs and margins include production efficiencies, the complexity of the work to be performed and the availability and costs of labor, materials and subcomponents.
As a significant change in one or more of these estimates could affect the profitability of our contracts, contract-related estimates are reviewed regularly. We recognize adjustments in estimated profit on contracts under the cumulative catch-up method. Under this method, the impact of the adjustment on profit recorded to date is recognized in the period the adjustment is identified. Revenue and profit in future periods of contract performance are recognized using the adjusted estimate. If at any time the estimate of contract profitability indicates an anticipated loss will be incurred on the contract, the loss is recognized in the period it is identified.
Cost of goods sold includes all direct material and labor costs and those costs related to contract performance, such as indirect labor, supplies, tools and repairs. As presented on our consolidated statements of operations, costs of goods sold excludes depreciation and amortization expense. Selling, general and administrative costs are charged to expense as incurred.
Taxes assessed by a governmental authority that are both imposed on and concurrent with a specific revenue-producing transaction, that we collect from a customer, are excluded from revenue. Shipping and handling costs associated with outbound freight after control over a product has transferred to a customer are accounted for as a fulfillment cost and are included in cost of products.
Long-Lived Tangible and Intangible Assets
Our long-lived tangible assets totaled $286.4 million, representing 29% of our total assets as of December 31, 2024, and our long-lived intangible assets totaled $125.9 million, representing 13% of our total assets. The remainder of our assets largely consisted of cash, accounts receivable, inventories and goodwill.
An assessment for impairment of long-lived tangible and intangible assets is conducted at the asset group level whenever changes in facts and circumstances indicate that the carrying value of such asset group may not be recoverable based on estimated undiscounted future cash flows. Indicators of impairment might include strategic management actions, persistent negative economic trends affecting the markets we serve, recurring losses or lowered expectations of future cash flows to be generated by our assets. When necessary, the amount of impairment is determined based on the excess of carrying value over fair value of the asset group, using quoted market prices, if available, or our judgment as to the future operating cash flows to be generated from these assets throughout their estimated useful lives.
During 2024, in response to further reductions in customer activity in the United States, we made strategic decisions to exit our underperforming flowback and well testing service offering and sell the related equipment and inventory. We also decided to exit eight leased facilities. As a result of these events and actions, we recorded non-cash intangible asset (customer relationships and tradenames) impairment charges of $10.8 million associated with the exit of this service offering and operating lease impairments of $3.8 million related to facility closures.
Events and circumstances in 2024 also indicated that the long-lived tangible and intangible assets of an asset group within our Downhole Technologies segment (totaling $146.7 million as of December 31, 2024) may not be recoverable. We assessed the carrying value of the long-lived assets of this group by comparing our estimates of undiscounted future cash flows to the carrying value of the assets. This assessment indicated that the asset group’s long-lived assets were recoverable. Accordingly, no additional long-lived asset impairment losses were recorded in 2024. However, management actions, competitive market conditions or industry cyclicality and downturns may result in future changes to our estimates of projected cash flows, or their timing, and could potentially cause future impairment to the values of our long-lived assets, including finite-lived intangible assets.
Recent Accounting Pronouncements
From time to time, new accounting pronouncements are issued by the Financial Accounting Standards Board (the “FASB”), which are adopted by us as of the specified effective date. We believe that the impact of recently issued standards, which are not yet effective, will not have a material impact on our consolidated financial statements upon adoption.
In 2024, we retrospectively expanded our reportable segment disclosures provided in Note 14, “Segments and Related Information,” to our Consolidated Financial Statements included in this Annual Report in accordance with the FASB guidance (“Accounting Standards Update 2023-07”) issued in November 2023.

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ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Item 7A. Quantitative and Qualitative Disclosures about Market Risk
Market risk refers to the potential losses arising from changes in interest rates, foreign currency exchange rates, equity prices and commodity prices, including the correlation among these factors and their volatility.
Our principal market risks are our exposure to changes in interest rates and foreign currency exchange rates. We enter into derivative instruments only to the extent considered necessary to meet risk management objectives and do not use derivative contracts for speculative purposes.
Interest Rate Risk. We have a revolving credit facility that is subject to the risk of higher interest charges associated with increases in interest rates. As of December 31, 2024, we had no floating-rate obligations outstanding under our ABL Facility. The use of floating-rate obligations would expose us to the risk of increased interest expense in the event of increases in short-term interest rates.
Foreign Currency Exchange Rate Risk. Our operations are conducted in various countries around the world and we receive revenue from these operations in a number of different currencies. As such, our earnings are subject to movements in foreign currency exchange rates when transactions are denominated in (i) currencies other than the U.S. dollar, which is our functional currency, or (ii) the functional currency of our subsidiaries, which is not necessarily the U.S. dollar. In order to mitigate the effects of foreign currency exchange rate risks in areas outside of the United States (primarily in our Offshore Manufactured Products segment), we generally pay a portion of our expenses in local currencies and a substantial portion of our
contracts provide for collections from customers in U.S. dollars. During 2024, our reported foreign currency exchange losses were $0.2 million and are included in “other operating income, net” in the consolidated statements of operations.
Accumulated other comprehensive loss, reported as a component of stockholders’ equity, primarily relates to fluctuations in currency exchange rates against the U.S. dollar as used to translate certain of the international operations of our operating segments. Our accumulated other comprehensive loss increased $9.5 million from $70.0 million as of December 31, 2023 to $79.5 million as of December 31, 2024, due to changes in currency exchange rates. During the year ended December 31, 2024, the exchange rates for the British pound and the Brazilian real weakened by 1% and 22%, respectively, compared to the U.S. dollar.

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ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Item 8. Financial Statements and Supplementary Data
Our Consolidated Financial Statements and supplementary data begin on page 55 of this Annual Report on Form 10-K and are incorporated by reference into this Item 8.

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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
There were no changes in or disagreements on any matters of accounting principles or financial statement disclosure between us and our independent registered public accounting firm during our two most recent fiscal years or any subsequent interim period.

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ITEM 9A. CONTROLS AND PROCEDURES
Item 9A. Controls and Procedures
(i) Evaluation of Disclosure Controls and Procedures
As of the end of the period covered by this Annual Report on Form 10-K, we carried out an evaluation, under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e)) of the Exchange Act. Our disclosure controls and procedures are designed to provide reasonable assurance that the information required to be disclosed by us in reports that we file under the Exchange Act is accumulated and communicated to our management, including our Chief Executive Officer and Chief Financial Officer, as appropriate, to allow timely decisions regarding required disclosure and is recorded, processed, summarized and reported within the time periods specified in the rules and forms of the SEC. Based upon that evaluation, our Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of December 31, 2024 at the reasonable assurance level.
Pursuant to section 906 of The Sarbanes-Oxley Act of 2002, our Chief Executive Officer and Chief Financial Officer have provided certain certifications to the SEC. These certifications accompanied this report when filed with the SEC, but are not set forth herein.
(ii) Internal Control over Financial Reporting
(a) Management’s annual report on internal control over financial reporting.
Our management is responsible for establishing and maintaining adequate internal control over financial reporting as defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act. Our internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of consolidated financial statements for external purposes in accordance with GAAP. Our internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with GAAP, and that our receipts and expenditures are being made only in accordance with authorizations of management and our directors; and (iii) 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 Consolidated Financial Statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate. Accordingly, even effective internal control over financial reporting can only provide reasonable assurance of achieving their control objectives.
Under the supervision and with the participation of our management, including our Chief Executive Officer and Chief Financial Officer, an assessment of the effectiveness of our internal control over financial reporting as of December 31, 2024 was conducted. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”) in Internal Control-Integrated Framework (2013 Framework). Based on our assessment we believe that, as of December 31, 2024, our internal control over financial reporting is effective based on those criteria.
The effectiveness of Oil States’ internal control over financial reporting as of December 31, 2024 has been audited by Ernst & Young LLP, an independent registered public accounting firm, as described below.
(b) Attestation report of the registered public accounting firm.
The attestation report of Ernst & Young LLP, our independent registered public accounting firm, on our internal control over financial reporting is set forth in this Annual Report on Form 10-K on page 58 and is incorporated herein by reference.
(c) Changes in internal control over financial reporting.
There have been no changes in our internal control over financial reporting (as that term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that occurred during our fourth fiscal quarter ended December 31, 2024, that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting.

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ITEM 9B. OTHER INFORMATION
Item 9B. Other Information
During the three months ended December 31, 2024, no director or executive officer adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement” (as each is defined in Item 408 of Regulation S-K) related to securities of our company.
PART III

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ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Item 10. Directors, Executive Officers and Corporate Governance
(1)Information concerning directors, including our audit committee financial experts, is incorporated by reference to our Definitive Proxy Statement for the 2025 Annual Meeting of Stockholders, under “Election of Directors.”
(2)Information with respect to executive officers is incorporated by reference to our Definitive Proxy Statement for the 2025 Annual Meeting of Stockholders, under “Executive Officers.”
(3)Information concerning Section 16(a) beneficial ownership reporting compliance is incorporated by reference to our Definitive Proxy Statement for the 2025 Annual Meeting of Stockholders, under “Section 16(a) Beneficial Ownership Reporting Compliance,” to the extent such disclosure is required.
(4)Information concerning corporate governance and our code of ethics is incorporated by reference to our Definitive Proxy Statement for the 2025 Annual Meeting of Stockholders, under “Corporate Governance.”
(5)Information concerning our insider trading policy is incorporated by reference to our Definitive Proxy Statement for the 2025 Annual Meeting of Stockholders, under “Compensation Discussion and Analysis.” A copy of our insider trading policy is filed with this Annual Report on Form 10-K as Exhibit 19.1.

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ITEM 11. EXECUTIVE COMPENSATION
Item 11. Executive Compensation
The information required by Item 11 hereby is incorporated by reference to such information as set forth in our Definitive Proxy Statement for the 2025 Annual Meeting of Stockholders.

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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 Item 12 hereby is incorporated by reference to such information as set forth in our Definitive Proxy Statement for the 2025 Annual Meeting of Stockholders.

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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 Item 13 hereby is incorporated by reference to such information as set forth in our Definitive Proxy Statement for the 2025 Annual Meeting of Stockholders.

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ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
Item 14. Principal Accounting Fees and Services
Information concerning principal accounting fees and services and the audit committee’s preapproval policies and procedures is incorporated by reference to our Definitive Proxy Statement for the 2025 Annual Meeting of Stockholders, under “Audit Fee Disclosure.”
PART IV

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ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
Item 15. Exhibits, Financial Statement Schedules
(a) Index to Financial Statements, Financial Statement Schedules and Exhibits
(1) Financial Statements: Reference is made to the index set forth on page 55 of this Annual Report on Form 10-K.
(2) Financial Statement Schedules: No schedules have been included herein because the information required to be submitted has been included in the Consolidated Financial Statements or the Notes thereto, or the required information is inapplicable.
(3) Index of Exhibits: See Index of Exhibits, below, for a list of those exhibits filed herewith, which index also includes and identifies management contracts or compensatory plans or arrangements required to be filed as exhibits to this Annual Report on Form 10-K by Item 601 of Regulation S-K.
(b) Index of Exhibits
Exhibit No. Description
3.1
- Amended and Restated Certificate of Incorporation (incorporated by reference to Exhibit 3.1 to the Company's Quarterly Report on Form 10-Q for the quarter ended June 30, 2023, as filed with the SEC on July 27, 2023 (File No. 001-16337)).
3.2
- Fifth Amended and Restated Bylaws of Oil States International, Inc. (incorporated by reference to Exhibit 3.2 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2022, as filed with the SEC on February 17, 2023 (File No. 001-16337)).
4.1
- Form of common stock certificate (incorporated by reference to Exhibit 4.1 to the Company’s Registration Statement on Form S-1, as filed with the SEC on November 7, 2000 (File No. 333-43400)).
4.3
- Indenture, dated March 19, 2021, by and among Oil States International, Inc. and Wells Fargo Bank, National Association, as trustee, relating to the 4.75% Convertible Senior Notes due 2026 (incorporated by reference to Exhibit 4.1 to the Company’s Current Report on Form 8-K, as filed with the Commission on March 22, 2021 (File No. 001-16337)).
4.4
- Description of Common Stock (incorporated by reference to Exhibit 4.4 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2019, as filed with the SEC on February 21, 2020 (File No. 001-16337)).
10.1+
- Amended and Restated Equity Participation Plan of Oil States International, Inc. (incorporated by reference to Exhibit 4.4 to the Company’s Registration Statement on Form S-8, as filed with the SEC on May 28, 2021 (File No. 333-2565777)).
10.2
- Form of Deferred Stock Award Election under the Company’s Amended and Restated Equity Participation Plan. (incorporated by Reference to Exhibit 10.2 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2021, as filed with the SEC on February 22, 2022 (File No. 001-16337)).
10.3
- Form of Deferred Stock Grant Notice and Agreement under the Company’s Amended and Restated Equity Participation Plan. (incorporated by Reference to Exhibit 10.3 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2021, as filed with the SEC on February 22, 2022 (File No. 001-16337)).
10.4+
- Deferred Compensation Plan effective January 1, 2012 (incorporated by reference to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2013, as filed with the SEC on April 25, 2013 (File No. 001-16337)).
10.5+
- Annual Incentive Compensation Plan, dated January 1, 2017 (incorporated by reference to Exhibit 10.4 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2016, as filed with the SEC on February 17, 2017 (File No. 001-16337)).
10.6+
- Executive Agreement between Oil States International, Inc. and Cindy B. Taylor (incorporated by Reference to Exhibit 10.9 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2000, as filed with the SEC on March 30, 2001 (File No. 001-16337)).
10.7+
- Form of Change of Control Severance Plan for Selected Members of Management (incorporated by reference to Exhibit 10.11 of the Company’s Registration Statement on Form S-1, as filed with the SEC on December 12, 2000 (File No. 333-43400)).
10.8
- Asset-based Credit Agreement, dated as of February 10, 2021, among Oil States International, Inc., as Borrower, the Lenders from time to time party thereto, and Wells Fargo Bank, National Association as Agent (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K, as filed with the SEC on February 12, 2021 (File No. 001-16337)).
10.9
- Second Amendment to Credit Agreement, dated December 13, 2022, among Oil States International, Inc., as Borrower, the Lenders from time to time hereto, and Wells Fargo Bank, National Association as Agent (incorporated by reference to Exhibit 10.9 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2022, as filed with the SEC on February 17, 2023 (File No. 001-16337)).
10.10
- Third Amendment to Credit Agreement, dated February 16, 2024, among Oil States International, Inc., as Borrower, the Lenders from time to time hereto, and Wells Fargo Bank, National Association as Agent (incorporated by reference to Exhibit 10.10 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2013, as filed with the SEC on February 21, 2014 (File No. 001-16337)).
10.11
- Form of Indemnification Agreement (incorporated by reference to Exhibit 10.14 to the Company’s Quarterly Report on Form 10-Q for the quarter ended September 30, 2004, as filed with the SEC on November 5, 2004 (File No. 001-16337)).
10.12+
- Form of Director Stock Option Agreement under the Company’s 2001 Equity Participation Plan (incorporated by reference to Exhibit 10.18 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2004, as filed with the SEC on March 2, 2005 (File No. 001-16337)).
10.13+
- Form of Employee Nonqualified Stock Option Agreement under the Company’s Amended and Restated Equity Participation Plan (incorporated by reference to Exhibit 4.7 to the Company’s Registration Statement on Form S-8, as filed with the SEC on May 28, 2021 (File No. 333-2565777)).
10.14+
- Form of Restricted Stock Agreement under the Company’s Amended and Restated Equity Participation Plan (incorporated by reference to Exhibit 4.5 to the Company’s Registration Statement on Form S-8, as filed with the SEC on May 28, 2021 (File No. 333-2565777)).
10.15+
- Form of Performance Award Agreement under the Company’s Amended and Restated Equity Participation Plan (incorporated by reference to Exhibit 10.1 to the Company's Quarterly Report on Form 10-Q for the quarter ended March 31, 2024, as filed with the SEC on April 26, 2024 (File No. 001-16337)).
10.16+
- Form of Cash Award Agreement (incorporated by reference to Exhibit 10.4 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2021, as filed with the SEC on April 29, 2021 (File No. 001-16337)).
10.17+
- Non-Employee Director Compensation Summary (incorporated by reference to Exhibit 10.21 to the Company’s Report on Form 8-K as filed with the SEC on November 15, 2006 (File No. 001-16337)).
10.18+
- Form of Non-Employee Director Restricted Stock Agreement under the Company’s Amended and Restated Equity Participation Plan (incorporated by reference to Exhibit 4.6 to the Company’s Registration Statement on Form S-8, as filed with the SEC on May 28, 2021 (File No. 333-2565777)).
10.19+
- Amendment to the Executive Agreement of Cindy Taylor, effective January 1, 2009 (incorporated by reference to Exhibit 10.21 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2008, as filed with the SEC on February 20, 2009 (File No. 001-16337)).
10.20+
- Executive Agreement between Oil States International, Inc. and named executive officer (Lloyd A. Hajdik) effective December 9, 2013 (incorporated by reference to Exhibit 10.31 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2013, as filed with the SEC on February 25, 2014 (File No. 001-16337)).
10.21+
- Executive Agreement between Oil States International, Inc. and named executive officer (Philip S. Moses) effective July 1, 2015 (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K, as filed with the SEC on July 8, 2015 (File No. 001-16337)).
10.22+
- Executive Agreement between Oil States International, Inc. and named executive officer (Brian E. Taylor) effective May 10, 2022 (incorporated by reference to Exhibit 10.1 to the Company’s Current Report on Form 8-K, as filed with the SEC on May 13, 2022 (File No. 001-16337)).
10.23+
- Annual Incentive Compensation Plan, dated January 1, 2020 (incorporated by reference to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2020, as filed with the SEC on May 1, 2020 (File No. 001-16337)).
19.1*
- Oil States International, Inc. Insider Trading Policy
21.1*
- List of subsidiaries of the Company.
23.1*
- Consent of Independent Registered Public Accounting Firm.
24.1*
- Powers of Attorney for Directors.
31.1*
- Certification of Chief Executive Officer of Oil States International, Inc. pursuant to Rules 13a-14(a) or 15d-14(a) under the Securities Exchange Act of 1934.
31.2*
- Certification of Chief Financial Officer of Oil States International, Inc. pursuant to Rules 13a-14(a) or 15d-14(a) under the Securities Exchange Act of 1934.
32.1**
- Certification of Chief Executive Officer of Oil States International, Inc. pursuant to Rules 13a-14(b) or 15d-14(b) under the Securities Exchange Act of 1934.
32.2**
- Certification of Chief Financial Officer of Oil States International, Inc. pursuant to Rules 13a-14(b) or 15d-14(b) under the Securities Exchange Act of 1934.
97.1
- Incentive-Based Compensation Recoupment Policy (incorporated by reference to Exhibit 97.1 to the Company’s Annual Report on Form 10-K for the year ended December 31, 2023, as filed with the SEC on February 21, 2024 (File No. 001-16337)).
101.INS* - XBRL Instance Document
101.SCH* - XBRL Taxonomy Extension Schema Document
101.CAL* - XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF* - XBRL Taxonomy Extension Definition Linkbase Document
101.LAB* - XBRL Taxonomy Extension Label Linkbase Document
101.PRE* - XBRL Taxonomy Extension Presentation Linkbase Document
104.1* - Cover Page Interactive Data File (embedded within the Inline XBRL document)
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* Filed herewith.
** Furnished herewith.
+ Management contracts or compensatory plans or arrangements.