Nine Energy Service, Inc. [NINE] Filings

10-K 1 nine-20231231.htm 10-K nine-20231231

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

______________________________________________________________________________________

FORM 10-K

_____________________________________________________________________________________

(Mark One)


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

FOR THE FISCAL YEAR ENDED DECEMBER 31, 2023


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

FOR THE TRANSITION PERIOD FROM TO

Commission File Number: 001-38347

_____________________________________________________________________________________

Nine Energy Service, Inc.

(Exact name of registrant as specified in its charter)

_____________________________________________________________________________________


Delaware			80-0759121
(State or other jurisdiction of incorporation or organization)			(I.R.S. Employer Identification No.)

2001 Kirby Drive, Suite 200

Houston, TX 77019

(Address of principal executive offices)

(281) 730-5100

(Registrant’s telephone number, including area code)

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


Title of each class	Trading Symbol(s)	Name of each exchange on which registered
Common Stock, par value $0.01 per share	NINE	New York Stock Exchange

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

_____________________________________________________________________________________

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

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

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

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

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

Large accelerated filer

Accelerated filer

☒

Non-accelerated filer

Smaller reporting company

☒

Emerging growth company

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

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

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

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

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

The aggregate market value of the registrant’s common stock held by non-affiliates of the registrant on the last business day of the registrant’s most recently completed second fiscal quarter (based on the closing sales price on the New York Stock Exchange on June 30, 2023) was $92,875,087.

The number of shares of the registrant’s common stock outstanding at March 4, 2024 was 35,324,861.

DOCUMENTS INCORPORATED BY REFERENCE

Information called for in Part III of this Annual Report on Form 10-K is incorporated by reference to the registrant’s Definitive Proxy Statement for its 2024 Annual Meeting of Stockholders.

TABLE OF CONTENTS

Unresolved Staff Comments

Mine Safety Disclosures

PART II

Item 5.

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

Item 6.

[Reserved]

Item 7.

Management’s Discussion and Analysis of Financial Condition and Results of Operations

Item 7A.

Quantitative and Qualitative Disclosures About Market Risk

Item 8.

Financial Statements and Supplementary Data

Item 9.

Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

Item 9A.

Controls and Procedures

Item 9B.

Other Information

Item 9C.

Disclosure Regarding Foreign Jurisdictions that Prevent Inspections

PART III

Item 10.

Directors, Executive Officers and Corporate Governance

Item 11.

Executive Compensation

Item 12.

Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters

Item 13.

Certain Relationships and Related Transactions, and Director Independence

Item 14.

Principal Accountant Fees and Services

PART IV

Item 15.

Exhibit and Financial Statement Schedules

Item 16.

Form 10-K Summary

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Annual Report on Form 10-K (this “Annual Report”) contains forward-looking statements that are subject to a number of risks and uncertainties, many of which are beyond our control. All statements, other than statements of historical fact, regarding our strategy, future operations, financial position, estimated revenues and losses, projected costs, prospects, plans, and objectives of management are forward-looking statements. When used in this Annual Report, the words “could,” “believe,” “anticipate,” “intend,” “estimate,” “expect,” “may,” “continue,” “predict,” “potential,” “project,” and similar expressions are intended to identify forward-looking statements, although not all forward-looking statements contain such identifying words.

All forward-looking statements speak only as of the date of this Annual Report; we disclaim any obligation to update these statements unless required by law, and we caution you not to place undue reliance on them. Although we believe that our plans, intentions, and expectations reflected in or suggested by the forward-looking statements we make in this Annual Report are reasonable, we can give no assurance that these plans, intentions, or expectations will be achieved.

We disclose important known factors that could cause our actual results to differ materially from our expectations under “Risk Factors” in Item 1A of Part I and in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Item 7 of Part II of this Annual Report. Additional risks or uncertainties that are not currently known to us, that we currently deem to be immaterial, or that could apply to any company could also materially adversely affect our business, financial condition, or future results.

These cautionary statements qualify all forward-looking statements attributable to us or persons acting on our behalf.

SUMMARY OF PRINCIPAL RISK FACTORS

Our business is subject to a number of risks and uncertainties. The following is a summary of the principal risk factors that could materially adversely affect our business, financial condition, and results of operations. A more complete statement of those risks and uncertainties is set forth in “Risk Factors” in Item 1A of Part I of this Annual Report.

•Our business is cyclical and depends on capital spending and well completions by the onshore oil and natural gas industry, and the level of such activity is volatile and strongly influenced by current and expected oil and natural gas prices. If the prices of oil and natural gas decline, our business, financial condition, results of operations, cash flows, and prospects may be materially and adversely affected. Significant factors that are likely to affect near-term commodity prices include actions by the members of the Organization of the Petroleum Exporting Countries (“OPEC”) and other oil exporting nations; U.S. energy, monetary, and trade policies; the pace of economic growth in the U.S. and throughout the world; and geopolitical and economic developments in the U.S. and globally, including conflicts, instability, acts of war, and terrorism, particularly in Russia, Ukraine, and the Middle East.

•Inflation may adversely affect our financial position and operating results; in particular, cost inflation with labor or materials could offset any price increases for our products and services.

•If we are unable to attract and retain key employees, technical personnel, and other skilled and qualified workers, our business, financial condition, or results of operations could suffer.

•We may be unable to maintain existing prices or implement price increases on our products and services, and intense competition in the markets for our dissolvable plug products may lead to pricing pressures, reduced sales, or reduced market share.

•Our substantial debt obligations could have significant adverse consequences on our business and future prospects, and restrictions in our debt agreements could limit our growth and our ability to engage in certain activities.

•Our current and potential competitors may have longer operating histories, significantly greater financial or technical resources, and greater name recognition than we do.

•Our operations are subject to conditions inherent in the oilfield services industry, such as equipment defects, liabilities arising from accidents or damage involving our fleet of trucks or other equipment, explosions and uncontrollable flows of gas or well fluids, and loss of well control.

•If we are unable to accurately predict customer demand, including that of our international customers, or if customers cancel their orders on short notice, we may hold excess or obsolete inventory, which would reduce gross margins. Conversely, insufficient inventory would result in lost revenue opportunities and potentially loss of market share and damaged customer relationships.

•We are dependent on customers in a single industry. The loss of one or more significant customers, including certain of our customers outside of the U.S., could adversely affect our financial condition, prospects, and results of operations. Sales to customers outside of the U.S. also exposes us to risks inherent in doing business internationally, including political, social, and economic instability and disruptions, export controls, economic sanctions, embargoes or trade restrictions, and fluctuations in foreign currency exchange rates.

•We may be subject to claims for personal injury and property damage or other litigation, which could materially adversely affect our financial condition, prospects, and results of operations.

•We are subject to federal, state, and local laws and regulations regarding issues of health, safety, and protection of the environment. Under these laws and regulations, we may become liable for penalties, damages, or costs of remediation or other corrective measures. Any changes in laws or government regulations could increase our costs of doing business.

•Our success may be affected by the use and protection of our proprietary technology as well as our ability to enter into license agreements. There are limitations to our intellectual property rights and, thus, our right to exclude others from the use of our proprietary technology.

•Our success may be affected by our ability to implement new technologies and services.

•If our systems for protecting against cybersecurity risks prove not to be sufficient, we could be adversely affected by, among other things, loss or damage of intellectual property, proprietary information, customer or business data; interruption of business operations; or additional costs to prevent, respond to, or mitigate cybersecurity attacks.

•Our future financial condition and results of operations could be adversely impacted by asset impairment charges.

•Increased scrutiny of sustainability matters could have an adverse effect on our business and damage our reputation.

•Increased attention to climate change and conservation measures may reduce oil and natural gas demand, and we face various risks associated with increased activism and related litigation against oil and natural gas exploration and development activities.

•Seasonal and adverse weather conditions adversely affect demand for our products and services.

PART I

Item 1. Business

Overview

Nine Energy Service, Inc. (either individually or together with its subsidiaries, as the context requires, the “Company,” “Nine,” “we,” “us,” and “our”) is a Delaware corporation that was formed in February 2013 through a combination of three service companies owned by SCF Partners, L.P. or its affiliates. Nine is a leading completion services provider that targets unconventional oil and gas resource development across North American basins and abroad. We partner with our exploration and production (“E&P”) customers to design and deploy downhole solutions and technology to prepare horizontal, multistage wells for production. We focus on providing our customers with cost-effective and comprehensive completion solutions designed to maximize their production levels and operating efficiencies. We believe our success is a product of our culture, which is driven by our intense focus on performance and wellsite execution as well as our commitment to forward-leaning technologies that aid us in the development of smarter, customized applications that drive efficiencies.

We provide our comprehensive completion solutions across a diverse set of well-types, including on the most complex, technically demanding unconventional wells. Modern, high-intensity completion techniques are a more effective way for our customers to maximize resource extraction from horizontal oil and gas wells. These completion techniques provide improved estimated ultimate recovery per lateral foot and a superior return on investment by decreasing cycle time, which make them attractive to operators. We compete for the most intricate and demanding projects, which are characterized by extended reach horizontal laterals, increased stage counts per well, multi-well pad development, and increased proppant loading per lateral foot. As stage counts per well and wells per pad increase, so do our operating leverage and returns, as we are able to complete more jobs and stages with the same number of units and crews. Service providers for these demanding projects are selected based on their technical expertise and ability to execute safely and efficiently. As our customers continue to improve operational efficiencies in completions design, increasing its complexity and difficulty, oilfield service selection becomes much more critical and selective.

We offer a variety of completion applications and technologies to match customer needs across the broadest addressable completions market. Our comprehensive well solutions range from cementing the well at the initial stages of the completion, preparing the well for stimulation, isolating all the stages of an extended reach lateral, and the drilling out of isolation tools. Our completion techniques are specifically tailored to the customer and geology of each well. At the initial stage of a well completion, our lab facilities produce customized cementing slurries used to secure the production casing to ensure well integrity throughout the life of the well. Once the casing is in place, we utilize our proprietary tools at the toe (end) of the well, often called stage one, to prepare for the well stimulation process. Following stage one, we perform plug-and-perf completions using a wireline or electric wireline truck and reel, as well as our composite or dissolvable frac plugs. Through our wireline units, we provide plug-and-perf services that, when combined with our fully-composite or dissolvable frac plugs, create perforations to isolate and divert the fracture to the correct stage. Our completion tool technology focuses on composite and dissolvable frac plugs that isolate stages in a completion but also includes a number of other patented technologies sold in North America and abroad. Our equipment also includes large-diameter coiled tubing units that are capable of reaching the farthest depths for the removal of plugs and cleaning of the wellbore to prepare for production.

Our website is located at https://nineenergyservice.com, and our investor relations website is located at https://investor.nineenergyservice.com. The information posted on our website is not incorporated into this Annual Report. Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, and amendments to reports filed or furnished pursuant to Sections 13(a) and 15(d) of the Securities Exchange Act of 1934, as amended (the “Exchange Act”), are available free of charge on our investor relations website as soon as reasonably practicable after we electronically file such material with, or furnish it to, the Securities and Exchange Commission (the “SEC”). You may also access all of our public filings through the SEC’s website at www.sec.gov. Investors and other interested parties should note that we use our investor relations website to publish important information about us, including information that may be deemed material to investors. We encourage investors and other interested parties to review the information we may publish through our investor relations website, in addition to our SEC filings, press releases, conference calls, and webcasts.

Our Services

We derive revenue by providing services integral to the completion of unconventional wells through a full range of tools and methodologies. The following is a description of our primary service offerings and deployment methods:

Cementing Services: Our cementing services consist of blending high-grade cement and water with various solid and liquid additives to create a cement slurry that is pumped between the casing and the wellbore of the well. We currently operate

four high-quality laboratory facilities capable of designing and testing all of the current industry cement designs. The laboratory facilities operate twenty-four hours a day and are fully staffed by qualified technicians with the latest equipment and modeling software. Additionally, our technicians and engineers ensure that all tests are performed to American Petroleum Institute specifications and results are delivered to customers promptly. Our cement slurries are designed to achieve the proper cement thickening time, compressive strength, and fluid loss control. Our slurries can be modified to address a wide range of downhole needs of our E&P customers, including varying well depths, downhole temperatures, pressures, and formation characteristics.

We deploy our slurries by using our customized design twin-pumping units, which are fully redundant, containing two pumps, two hydraulic systems, two mixing pumps, and two electrical systems. This customized design significantly decreases our risk of downtime due to mechanical failure and eliminates the necessity of having an additional cementing unit on standby. We have invested in the highest quality cementing equipment.

From January 2018 through December 2023, we completed approximately 22,000 cementing jobs, with an on-time rate of approximately 89%. Punctuality of service is one of the primary metrics that E&P operators use to evaluate the cementing services they receive. Key contributors to our 89% on-time rate include our lab capabilities, personnel, close proximity to our customers’ acreage, dual-sided bulk loading plants, and our service-driven culture.

Completion Tools: We provide downhole solutions and technology used for multistage completions. Our comprehensive completion service offerings are mostly comprised of composite and dissolvable frac plugs in a variety of sizes to isolate stages during plug-and-perf operations. We have coupled patented tool designs with proprietary materials for our dissolvable offering, enabling us to serve the entire addressable plug market. With this ability, we have traditional and long-range plugs to address every type of wellbore situation. Our frac plug technology is complemented by our unconventional open hole and cemented completion tool products, such as liner hangers and accessories, fracture isolation packers, frac sleeves, stage one prep tools, casing flotation tools, specialty open hole float equipment, disk subs, composite cement retainers, and centralizers. Our tool portfolio also includes a multi-cycle barrier valve to address the international, conventional markets.

Our systems provide completion efficiencies at the wellsite by reducing our customers’ equipment needs and stimulation time and allowing for specific zonal treatment. Our dissolvable frac plugs help operators reduce cycle times to bring production online faster, decrease the amount of equipment and people needed on location, and significantly reduce carbon emissions compared to a traditional composite plug completion. Through these reductions in cycle time, our dissolvable plugs can help increase our customers’ internal rate of return and provide a safer and more efficient working environment. From January 2018 through December 2023, we deployed approximately 470,600 isolation, stage one, and casing flotation tools.

Wireline Services: Our wireline services involve the use of a wireline or electric wireline unit equipped with a spool of wireline that is unwound and lowered into oil and gas wells to convey specialized tools or equipment for well completion, well intervention, or pipe recovery. We operate a fleet of modern and “fit-for-purpose” cased hole wireline units designed for operating in unconventional completion operations. Our operation is equipped with the latest technology utilized to service long lateral completions, including head tension tools, ballistic release tools, and addressable switches. We have converted several of our hydraulic wireline units to electric, which significantly reduces carbon emissions and the use of diesel. We currently have wireline units equipped with Coated Line, which is a coated wireline that significantly reduces injector oil use. Offering a lower dynamic coefficient of friction, Coated Line wireline requires less pump down fluid to operate and is more conducive for reaching further depths in longer laterals.

The majority of our wireline work consists of plug-and-perf completions, which is a multistage well completion technique for cased-hole wells that consists of deploying perforating guns to a specified depth. We deploy proprietary specialized tools like our fully-composite and dissolvable frac plugs through our wireline units. From January 2018 through December 2023, we completed approximately 163,600 wireline stages with a success rate of approximately 99%.

Coiled Tubing Services: Coiled tubing services perform wellbore intervention operations utilizing a continuous steel pipe that is transported to the wellsite wound on a large spool in lengths of up to 30,000 feet. Coiled tubing provides a cost-effective solution for well work due to the ability to deploy efficiently and safely into a live well using specialized well-control equipment. The live well work capability limits the customer’s risk of formation damage associated with “killing” a well (the temporary placement of heavy fluids in a wellbore to keep reservoir fluids in place) while allowing for safer operations due to minimal equipment handling. Coiled tubing facilitates a variety of services in both new and old wells, such as milling, drilling, fishing, production logging, artificial lift, cementing, and stimulation.

Our coiled tubing units carry data acquisition and dissemination technology, allowing our customers to monitor jobs via a web interface. Our “extended reach” units are capable of reaching the toe of wells with total measured depths of 27,000 feet and beyond, including lateral lengths in excess of 12,500 feet, keeping pace with the industry’s most challenging downhole environments. While we specialize in larger-diameter (2 3/8” and 2 5/8”) coiled tubing units, we also offer 2” and 1 1/4”

diameter solutions to our customers. From January 2018 through December 2023, we have performed approximately 7,100 jobs and deployed more than 191 million running feet of coiled tubing, with a success rate of over 99%.

Geographic Areas of Operation

We operate in all major onshore basins in the U.S., including the Permian Basin, Marcellus and Utica Shales, Eagle Ford Shale, DJ Basin, SCOOP/STACK Formation, Bakken Formation, and Haynesville Formation as well as the Western Canada Sedimentary Basin in Canada. We provide our services through strategically placed operating facilities located in-basin throughout the U.S. This local presence allows us to quickly respond to customer demands and operate efficiently. Additionally, through our extensive footprint, we are able to track and implement best practices around completion trends and technology across all divisions and geography.

A portion of completion tool revenue is generated from outside of North America, and international completion tools are an important part of our revenue stream.

We believe that our strategic geographic diversity will benefit us as activity increases or decreases in select basins by helping to mitigate basin and commodity-risk. Our broad geographic footprint provides us with exposure to potential increases in drilling and completion activity and will allow us to opportunistically pursue new business in basins with the most active drilling environments.

Seasonality

Our operations are subject to seasonal factors, and our overall financial results reflect seasonal variations. Specifically, we typically have experienced a pause by our customers around the holiday season in the fourth quarter, which may be compounded as our customers exhaust their annual capital spending budgets towards year end.

Additionally, our operations are directly affected by weather conditions. During the winter months (portions of the first and fourth quarters) and periods of heavy snow, ice, or rain, particularly in the northeastern U.S., North Dakota, Rocky Mountains, and western Canada, our customers may delay operations or we may not be able to operate or move our equipment between locations. Also, during the spring thaw, which normally starts in late March and continues through June, some areas, primarily in western Canada, impose transportation restrictions to prevent damage caused by the spring thaw. Throughout the year, heavy rains adversely affect activity levels because well locations and dirt access roads can become impassible in wet conditions. Weather conditions may also negatively affect our customers’ activity levels.

Sales and Marketing

Our sales activities are conducted through a network of sales representatives and business development personnel, which provides us coverage at both the corporate and field level of our customers. We have a technical sales organization with expertise and focus within our specific service lines. Sales representatives work closely with local operations managers to target potential opportunities through strategic focus and planning. Customers are identified as targets based on their drilling and completion activity, geographic location, and economic viability. Our marketing activities are performed internally with input and guidance from a third-party marketing agency. Our strategy is based on building a strong brand though multiple media outlets including our website, select social media accounts, print and online advertisements, billboard advertisements, press releases and various industry-specific conferences, publications, and lectures.

Customers

Our customer base includes a broad range of integrated and independent E&P companies. For the year ended December 31, 2023, our top five customers collectively accounted for approximately 21% of our revenues.

Demand for our services and products is cyclical and substantially dependent upon activity levels in the oil and gas industry, particularly our customers’ willingness to spend capital on the exploration for and development of oil and natural gas. Our customers’ spending plans are generally based on their outlook for near-term and long-term commodity prices. As a result, the demand for our services and products is highly sensitive to current and expected commodity prices.

Competition

We provide our services and products across the U.S., Canada, and abroad, and we compete against different companies in each service and product line we offer. Our competition includes many large and small oilfield service companies, including the largest integrated oilfield services companies. We believe that the principal competitive factors in the markets we serve are technology offerings, wellsite execution, service quality, technical expertise, equipment capacity, work force

competency, efficiency, safety record, reputation, and experience. Additionally, projects are often awarded on a bid basis, which tends to create a highly competitive environment. We seek to differentiate our company from our competitors by delivering the highest-quality services, technology, and equipment possible, coupled with superior execution and operating efficiency in a safe working environment. By focusing on cultivating our existing customer relationships and maintaining our high standard of customer service, technology, safety, performance, and quality of crews, equipment, and services, we believe we are differentiated in a competitive market.

Our major competitors include Halliburton Company, Schlumberger Limited, NCS Multistage, Patterson-UTI Energy, KLX Energy Services Holdings, Innovex, and a significant number of private and locally-oriented businesses.

Suppliers

We purchase a wide variety of raw materials, parts, and components that are manufactured and supplied for our operations from various suppliers. While we are not dependent on any single supplier for those materials, parts, or components, certain product lines depend on a limited number of third-party suppliers and vendors. During the year ended December 31, 2023, no supplier of the materials used in our services provided over 10% of our materials or equipment as a percentage of overall costs.

To date, we have generally been able to obtain the equipment, parts, and supplies necessary to support our operations on a timely basis. While we believe that we will be able to make satisfactory alternative arrangements in the event of any interruption in the supply of these materials and/or products by one of our suppliers, we may not always be able to make alternative arrangements. In addition, certain materials for which we do not currently have long-term supply agreements could experience shortages and significant price increases in the future. As a result, we may be unable to mitigate any future supply shortages, and our results of operations, prospects, and financial condition could be adversely affected.

Research & Technology, Intellectual Property

Our sales and earnings are influenced by our ability to successfully introduce new or improved products and services to the market. We believe we have become a “go-to” provider for piloting new technologies because of our service quality and offering, execution at the wellsite, and geographic footprint.

Our engineering and technology efforts are focused on providing efficient and cost-effective solutions to maximize production for our customers across major North American onshore basins and abroad. We have dedicated resources focused on internally developing new technology and equipment and evolving our existing proprietary tools, as well as resources focused on sourcing and commercializing new technologies through mergers and acquisitions and strategic partnerships, to stay ahead of industry trends and achieve lower completion and production costs for our customers.

We have developed a suite of proprietary downhole tools, products, and techniques through both internal resources, as well as mergers and acquisitions and strategic partnerships with manufacturers and engineering companies looking for a reliable and expansive channel to market. In these partnerships, we have exclusive rights to market and sell technology unavailable to any other service providers in the designated regions, and we sell the technology directly to the customer and order from the manufacturer on an as-needed basis, with no minimum volume requirements and without having to hold excess inventory. These strategic partnerships provide us and our customers with access to unique downhole technology from independent innovators while allowing us to minimize exposure to potential technology adoption risks and the significant costs associated with developing and implementing research and development internally.

Although in the aggregate our patents, licenses, and strategic partnerships are important to us, we do not regard any single patent, license, or strategic partnership as critical or essential to our business as a whole. In general, we depend on our technological capabilities, customer service-oriented culture, and application of our know-how to distinguish ourselves from our competitors, rather than our right to exclude others through patents or exclusive licenses. We also consider the quality and timely delivery of our products, the service we provide to our customers, and the technical knowledge and skill of our personnel to be more important than our registered intellectual property in our ability to compete.

Risk Management and Insurance

Our operations are subject to hazards inherent in the oil and natural gas industry, including, but not limited to, accidents, blowouts, explosions, craterings, fires, oil spills, and hazardous materials spills. These conditions can cause personal injury or loss of life; damage to, or destruction of, property, the environment, and wildlife; and the suspension of our or our customers’ operations.

In addition, claims for loss of oil and gas production and damage to formations can occur in the oilfield services industry. If a serious accident were to occur at a location where our equipment and services are being used, it could result in us being named as a defendant in lawsuits asserting large claims.

Because our business involves the transportation of heavy equipment and materials, we may also experience traffic accidents which may result in spills, property damage, and personal injury.

Despite our efforts to maintain high safety standards, from time to time, we have suffered accidents, and there is a risk that we will experience accidents in the future. In addition to the property and personal losses from these accidents, the frequency and severity of these incidents affect our operating costs, insurability, and relationships with customers, employees, and regulatory agencies. In particular, in recent years many of our large customers have placed an increased emphasis on the safety records of their service providers. Any significant increase in the frequency or severity of these incidents, or the general level of compensatory payments, could adversely affect the cost of, or our ability to obtain, workers’ compensation and other forms of insurance and could have other material adverse effects on our financial condition and results of operations.

We maintain insurance coverage of types and amounts that we believe to be customary in the industry including workers’ compensation, employer’s liability, claims-based pollution, umbrella, comprehensive commercial general liability, business automobile, and property. Our insurance coverage may be inadequate to cover our liabilities. In addition, we may not be able to maintain adequate insurance in the future at rates we consider reasonable and commercially justifiable or on terms as favorable as our current arrangements.

We endeavor to allocate potential liabilities and risks between the parties in our Master Service Agreements (“MSAs”). We retain the risk for any liability not indemnified by our customers in excess of our insurance coverage. These MSAs delineate our and our customers’ respective warranty and indemnification obligations with respect to the services we provide. We endeavor to negotiate MSAs with our customers that provide, among other things, that we and our customers assume (without regard to fault) liability for damages to our respective personnel and property. For catastrophic losses, we endeavor to negotiate MSAs that include industry-standard carve-outs from the knock-for-knock indemnities. Additionally, our MSAs often provide carve-outs to the “without regard to fault” concept that would permit, for example, us to be held responsible for events of catastrophic loss only if they arise as a result of our gross negligence or willful misconduct. Our MSAs typically provide for industry-standard pollution indemnities, pursuant to which we assume liability for surface pollution associated with our equipment and originating above the surface (without regard to fault), and our customer assumes (without regard to fault) liability arising from all other pollution, including, without limitation, underground pollution and pollution emanating from the wellbore as a result of an explosion, fire, or blowout. This description of our MSAs is a summary of the material terms of the typical MSA that we have in place and does not reflect every MSA that we have entered into or may enter into in the future, some of which may contain indemnity structures and risk allocations between our customers and us that are different than those described here.

Employees

As of December 31, 2023, we had 1,157 employees, all of which were full-time. We are not a party to any collective bargaining agreements.

Regulatory Matters

Our operations are subject to numerous stringent and complex laws and regulations at the U.S. federal, state, and local levels governing the discharge of materials into the environment, environmental protection, and health and safety aspects of our operations. In addition, due to our operations in Canada, we are subject to Canadian environmental statutes and regulations as well as Canada’s new anti-forced labor law. Failure to comply with these laws and regulations or to obtain or comply with permits may result in the assessment of administrative, civil, and criminal penalties, imposition of remedial or corrective action requirements, and the imposition of injunctions or other orders to prohibit certain activities, restrict certain operations, or force future compliance with environmental requirements.

There is inherent risk of incurring significant environmental costs and liabilities in the performance of our operations due to our handling of petroleum hydrocarbons, other hazardous substances, and wastes, as a result of air emissions and wastewater discharges related to our operations, and because of historical operations and waste disposal practices. Spills or other releases of regulated substances, including such spills and releases that occur in the future, could expose us to material losses, expenditures, and liabilities under applicable environmental laws and regulations. Under certain of such laws and regulations, we could be held strictly and jointly and severally liable for the removal or remediation of previously released materials or property contamination, regardless of whether we were responsible for the release or contamination and even if our operations met previous standards in the industry at the time they were conducted.

The following is a summary of some of the existing laws, rules, and regulations to which we are subject.

Hazardous Substances and Waste Handling

The Resource Conservation and Recovery Act (“RCRA”) and comparable state statutes regulate the management, generation, transportation, treatment, storage, disposal, and cleanup of hazardous and non-hazardous wastes. Under the guidance issued by the U.S. Environmental Protection Agency (the “EPA”), the individual states administer some or all of the provisions of RCRA, sometimes in conjunction with their own, more stringent requirements. We are required to manage the disposal of hazardous and non-hazardous wastes in compliance with RCRA and analogous state laws. RCRA currently exempts many E&P wastes from classification as hazardous waste if properly handled. Specifically, RCRA excludes from the definition of hazardous waste drilling fluids, produced waters, and most of the other wastes intrinsically associated with the exploration, development, or production of crude oil and natural gas and, instead, these fluids, waters, and wastes are regulated under RCRA’s less stringent non-hazardous waste provisions, state laws, or other federal laws. However, it is possible that certain oil and natural gas E&P wastes now classified as non-hazardous could be classified as hazardous waste in the future. Stricter regulation of wastes generated during our or our customers’ operations could result in increased costs for our operations or the operations of our customers, which could in turn reduce demand for our services and adversely affect our business.

Comprehensive Environmental Response, Compensation, and Liability Act

The Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”), also known as the Superfund law, and comparable state laws impose joint and several liability, without regard to fault or legality of conduct, on classes of persons who are considered to be responsible for the release of a hazardous substance into the environment. These persons include the current and former owner or operator of the site where the release occurred and anyone who transported or disposed or arranged for the transport or disposal of a hazardous substance released at the site. Persons who are or were responsible for releases of hazardous substances under CERCLA and any state analogs may be subject to joint and several and strict liability for the costs of cleaning up the hazardous substances that have been released into the environment and for damages to natural resources and for the costs of certain health studies. We currently own, lease, or operate numerous properties that have been used for manufacturing and other operations for many years. These properties and the substances disposed or released on them may be subject to CERCLA and analogous state laws. Under such laws, we could be required to remove previously disposed substances and wastes, remediate contaminated property, or perform remedial operations to prevent future contamination. In addition, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury and property damage allegedly caused by the hazardous substances released into the environment.

Worker Health and Safety

We are subject to a number of federal and state laws and regulations, including the federal Occupational Safety and Health Act (“OSHA”) and comparable state laws, establishing requirements to protect the health and safety of workers. 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 maintenance of information about hazardous materials used or produced in operations and provision of this information to employees, state and local government authorities, and citizens. Additionally, the Federal Motor Carrier Safety Administration (the “FMCSA”) regulates and provides safety oversight of commercial motor vehicles, the EPA establishes requirements to protect human health and the environment, and the federal Bureau of Alcohol, Tobacco, Firearms and Explosives establishes requirements for the safe use and storage of explosives. The federal Nuclear Regulatory Commission establishes requirements for the possession and use of radioactive materials, while most states have entered into agreements that allow them to assume licensing and oversight activities for specified classes of such materials. State agencies typically regulate other sources of ionizing and non-ionizing radiation. Substantial fines and penalties can be imposed, and orders or injunctions limiting or prohibiting certain operations may be issued, in connection with any failure to comply with these laws and regulations.

Transportation Safety and Compliance

At December 31, 2023, we operated a fleet in excess of 590 commercial motor vehicles. As such, we are subject to regulation as a motor carrier by the U.S. Department of Transportation (the “DOT”) and analogous state agencies and their applicable federal and state laws and regulations, including the Federal Motor Carrier Safety Regulations and Hazardous Materials Regulations for interstate travel promulgated by the FMCSA under the DOT and comparable state regulations for intrastate travel. These regulatory authorities exercise broad powers, governing activities such as the authorization to engage in motor carrier operations, regulatory safety, equipment testing, driver requirements and specifications, and insurance requirements. In connection with these rules, substantial fines and penalties can be imposed and orders or injunctions limiting or prohibiting certain operations may be issued in connection with any failure to comply with laws and regulations relating to the safe operation of commercial motor vehicles.

Water Discharges

The Federal Water Pollution Control Act (the “Clean Water Act”) and analogous state laws impose restrictions and strict controls with respect to the discharge of pollutants, including spills and leaks of oil and other substances, into waters of the United States (“WOTUS”) and state waters. The discharge of pollutants into, and other impacts to, regulated waters, including jurisdictional wetlands, is prohibited, except in accordance with the terms of a permit issued by the EPA, the U.S. Army Corps of Engineers (the “Corps”) or an analogous state agency. The scope of federal jurisdictional reach over waters of the United States has been subject to substantial revision in recent years. In 2015, the EPA and the Corps issued a rule defining the scope of federal jurisdiction over WOTUS, which never took effect before being replaced by the Navigable Waters Protection Rule (the “NWPR”) in 2020. A coalition of states and cities, environmental groups, and agricultural groups challenged the NWPR, which was vacated by a federal district court in August 2021. In January 2023, the EPA and the Corps issued a final rule that based the definition of WOTUS on the pre-2015 definition. Separately, in May 2023, the U.S. Supreme Court’s decision in Sackett v. EPA narrowed federal jurisdiction over wetlands to “traditional navigable waters” and wetlands or other waters that have a “continuous surface connection” with, or are otherwise indistinguishable from, traditional navigable waters. In September 2023, the EPA and the Corps published a direct-to-final rule that conforms the regulatory definition of WOTUS to the Supreme Court’s May 2023 decision in Sackett. However, litigation opposing the September 2023 final rule remains ongoing and substantial uncertainty exists with respect to future implementation of the September 2023 rule and the scope of the Clean Water Act’s jurisdiction more generally. To the extent a future rule or court decision expands the range of properties subject to the Clean Water Act’s jurisdiction, certain energy companies could face increased costs and delays with respect to obtaining permits for dredge and fill activities in wetland areas, which in turn could reduce demand for our services. The process for obtaining permits has the potential to delay our operations and those of our customers. Spill prevention, control, and countermeasure requirements of federal laws require appropriate containment berms and similar structures to help prevent the contamination of navigable waters by a petroleum hydrocarbon tank spill, rupture, or leak. In addition, the Clean Water Act and analogous state laws require individual permits or coverage under general permits for discharges of wastewater and storm water runoff from certain types of facilities. Federal and state regulatory agencies can impose administrative, civil, and criminal penalties as well as other enforcement mechanisms for non-compliance with discharge permits or other requirements of the Clean Water Act and analogous state laws and regulations. The Clean Water Act and analogous state laws provide for administrative, civil, and criminal penalties for unauthorized discharges and, together with the Oil Pollution Act of 1990, impose rigorous requirements for spill prevention and response planning, as well as substantial potential liability, such as strict liability and natural resources damages liability, for the costs of removal, remediation, and damages in connection with any unauthorized discharges.

Air Emissions

Through the federal Clean Air Act, as amended (“CAA”), and comparable state and local laws and regulations, the EPA regulates emissions of various air pollutants through the issuance of permits and the imposition of other requirements. The EPA has developed, and continues to develop, stringent regulations governing emissions of air pollutants at specified sources. New facilities may be required to obtain permits before work can begin, and modified and existing facilities may be required to obtain additional permits.

In June 2016, the EPA finalized regulations establishing New Source Performance Standards, known as Subpart OOOOa, for methane and volatile organic compounds from new and modified oil and natural gas production and natural gas processing and transmission facilities. In September 2020, the EPA finalized two sets of amendments to the 2016 Subpart OOOOa standards. The first, known as the 2020 Technical Rule, reduced the 2016 rule’s fugitive emissions monitoring requirements and expanded exceptions to pneumatic pump requirements, among other changes. The second, known as the 2020 Policy Rule, rescinded the methane-specific requirements for certain oil and natural gas sources in the production and processing segments. On January 20, 2021, President Biden issued an Executive Order directing the EPA to rescind the 2020 Technical Rule by September 2021 and consider revising the 2020 Policy Rule. On June 30, 2021, President Biden signed a Congressional Review Act (the “CRA”) resolution passed by Congress that revoked the 2020 Policy Rule. The CRA resolution did not address the 2020 Technical Rule.

In December 2023, the EPA issued a final rule, under the CAA’s New Source Performance Standards, intended to reduce methane emissions from new and existing oil and gas sources. The new rule makes the existing regulations in Subpart OOOOa more stringent and creates a Subpart OOOOb to expand reduction requirements for new, modified, and reconstructed oil and gas sources that commenced construction, modification, or reconstruction after December 6, 2022, including standards focusing on certain source types that have never been regulated under the CAA (including intermittent vent pneumatic controllers, associated gas, and liquids unloading facilities). The new rule phases out flaring through Subpart OOOOb, which prohibits routine flaring from new oil wells after the phase-in period, and through a new Subpart OOOOc, which prohibits flaring absent a showing of technical infeasibility for existing wells with documented methane emissions of 40 tons per year or

more. In addition, the final rule establishes “Emissions Guidelines” in Subpart OOOOc, which requires states to develop plans to reduce methane emissions from existing sources that must be at least as effective as presumptive standards set by EPA. The final rule gives states, along with federal tribes that wish to regulate existing sources, two years to develop and submit their plans for reducing methane emissions from existing sources. The final emissions guidelines under Subpart OOOOc provide three years from the plan submission deadline for existing sources (i.e., sources constructed prior to December 6, 2022) to comply.

Although there may be an adverse financial impact (including compliance costs, potential permitting delays and increased regulatory requirements) associated with these regulatory changes, the extent and magnitude of impacts cannot be reliably or accurately estimated due to the present uncertainty regarding any additional measures and how they will be implemented. Any new regulations implementing stricter permitting requirements could delay or impair our or our customers’ ability to obtain air emission permits, and result in increased expenditures for pollution control equipment, the costs of which could be significant. Federal and state regulatory agencies can impose administrative, civil, and criminal penalties, as well as injunctive relief, for non-compliance with air permits or other requirements of the CAA and associated state laws and regulations.

Climate Change

Numerous reports from scientific and governmental bodies, such as the Sixth Assessment Report of the Intergovernmental Panel on Climate Change, have expressed heightened concerns about the impacts of human activity, especially fossil fuel combustion, on the global climate. In turn, governments and civil society are increasingly focused on limiting the emissions of greenhouse gases (“GHGs”), including emissions of carbon dioxide from the use of oil and natural gas. The EPA has determined that emissions of GHGs, including carbon dioxide and methane, present a danger to public health and the environment because emissions of such gases are, according to the EPA, contributing to warming of the Earth’s atmosphere and other climatic changes. The EPA has established GHG emission reporting requirements for sources in the oil and gas sector and has also promulgated rules requiring certain large stationary sources of GHGs to obtain preconstruction permits under the CAA and follow “best available control technology” requirements. Although we are not likely to become subject to GHG emissions permitting and best available control technology requirements because none of our facilities are presently major sources of GHG emissions, such requirements could become applicable to our customers and could have an adverse effect on their costs of operations or financial performance, thereby adversely affecting demand for our products and services and our business, financial condition, and results of operations.

In December 2015, the 21st Conference of the Parties of the United Nations Framework Convention on Climate Change resulted in nearly 200 countries, including the U.S., coming together to develop the Paris Agreement, which calls for the parties to undertake “ambitious efforts” to limit the average global temperature. In February 2021, the United States rejoined the Paris Agreement and announced that it was setting a target to reduce U.S. GHG emissions by 50-52% by the year 2030 as compared with 2005 levels and agreed to provide periodic updates on its progress. In addition, in September 2021, President Biden publicly announced the Global Methane Pledge, a pact that commits its signatories to the collective goal of reducing global methane emissions at least 30% below 2020 levels by 2030, including “all feasible reductions” in the energy sector. Since its formal launch at the United Nations 26th Conference of the Parties, over 150 countries have joined the pledge. At the 27th Conference of the Parties, President Biden announced the EPA’s supplemental proposed rule to reduce methane emissions from existing oil and gas sources and agreed, in conjunction with the European Union and a number of other partner countries, to develop standards for monitoring and reporting methane emissions to help create a market for low methane-intensity natural gas. At the 28th Conference of the Parties, member countries agreed to the first “global stocktake,” which calls on countries to contribute to global efforts, including a tripling of renewable energy capacity and doubling energy efficiency improvements by 2030, accelerating efforts toward the phase-down of unabated coal power, phasing out inefficient fossil fuel subsidies, and transitioning away from fossil fuels in energy systems. The impacts of these orders, pledges, agreements, and any legislation, regulation, regulatory initiatives, changes to existing regulation or executive actions cannot be predicted at this time.

While the Biden Administration has pursued executive actions to address climate change, the U.S. Congress has from time to time considered adopting legislation to reduce emissions of GHGs, but no new comprehensive federal laws regulating the emission of GHGs or directly imposing a price of carbon have been adopted in recent years. However, such legislation has periodically been introduced in the U.S. Congress and may be proposed or adopted in the future, and energy legislation and other regulatory initiatives have been proposed that are relevant to GHG emissions issues. For example, the Inflation Reduction Act of 2022, which appropriates significant funding for renewable energy initiatives and, for the first time, imposes a fee on GHG emissions from certain oil and gas facilities, was signed into law in August 2022. The Inflation Reduction Act amends the CAA to include a Methane Emissions and Waste Reduction Incentive Program, which requires the EPA to impose a “waste emissions charge” on certain natural gas and oil sources that are already required to report under the EPA’s Greenhouse Gas Reporting Program. To implement the program, the Inflation Reduction Act requires revisions to GHG reporting regulations for

petroleum and natural gas systems (Subpart W) by 2024. In July 2023, the EPA proposed to expand the scope of the Greenhouse Gas Reporting Program for petroleum and natural gas facilities, as required by the Inflation Reduction Act. Among other things, the proposed rule would expand the emissions events that are subject to reporting requirements to include “other large release events” and apply reporting requirements to certain new sources and sectors. The rule is expected to be finalized in the spring of 2024 and become effective on January 1, 2025, in advance of the deadline for GHG reporting for 2024 (March 2025). In January 2024, the EPA proposed a rule implementing the Inflation Reduction Act’s methane emissions charge. The proposed rule includes potential methodologies for calculating the amount by which a facility’s reported methane emissions are below or exceed the waste emissions thresholds and contemplates approaches for implementing certain exemptions created by the Inflation Reduction Act. The methane emissions charge imposed under the Methane Emissions and Waste Reduction Incentive Program for 2024 would be $900 per ton emitted over annual methane emissions thresholds and would increase to $1,200 in 2025 and $1,500 in 2026. The emissions fee and funding provisions of the law could increase operating costs within the oil and gas industry and accelerate the transition away from fossil fuels, which could in turn adversely affect our and our customers’ business and results of operations. In addition, many U.S. state and local governments have intensified or stated their intent to intensify efforts to support international climate commitments and treaties, in addition to developing programs that are aimed at tracking and reducing GHG emissions by means of carbon taxes, policies or incentives to encourage the use of renewable energy or alternative low-carbon fuels, the development of GHG inventories, and cap-and-trade programs that typically require major sources of GHG emissions to acquire and surrender emission allowances in return for emitting GHGs.

The adoption of any new climate change-related legislation or regulation, including any such legislation or regulation that restricts emissions of GHGs from the equipment and operations of our customers or with respect to the oil and natural gas they produce, could adversely affect demand for our products and services. Consequently, legislation and regulatory programs to reduce emissions of GHGs could have an adverse effect on our business, financial condition, and results of operations. Moreover, incentives to conserve energy or use alternative energy sources, such as policies designed to increase utilization of zero-emissions or electric vehicles, as a means of addressing climate change could reduce demand for the oil and natural gas produced by our customers and, in turn, could adversely affect demand for our products and services. Finally, most scientists have concluded that increasing concentrations of GHGs in the Earth’s atmosphere may produce climate changes that could have significant physical effects, such as increased frequency and severity of storms, droughts, and floods and other climatic events; if such effects were to occur, they could have an adverse impact on our operations.

Regulations requiring the disclosure of GHG emissions, and other climate-related information or information substantiating climate-related claims, are also increasingly being adopted or proposed at the federal and state level. For example, the SEC issued a proposed rule in March 2022 regarding the enhancement and standardization of mandatory climate-related disclosures for investors. The proposed rule would require registrants to include certain climate-related disclosures in their registration statements and periodic reports, including, but not limited to, information about the registrant’s governance of climate-related risks and relevant risk management processes; climate-related risks that are reasonably likely to have a material impact on the registrant’s business, results of operations, or financial condition and their actual and likely climate-related impacts on the registrant’s business strategy, model, and outlook; climate-related targets, goals and transition plan (if any); certain climate-related financial statement metrics in a note to their audited financial statements; Scope 1 and Scope 2 GHG emissions; and Scope 3 GHG emissions and intensity, if material, or if the registrant has set a GHG emissions reduction target, goal or plan that includes Scope 3 GHG emissions. Although the proposed rule’s ultimate date of effectiveness and the final form and substance of these requirements is not yet known and the ultimate scope and impact on our business is uncertain, compliance with the proposed rule, if finalized, may result in increased legal, accounting, and financial compliance costs, make some activities more difficult, time-consuming, and costly, and place strain on our personnel, systems, and resources.

Hydraulic Fracturing

Our businesses are dependent on hydraulic fracturing and horizontal drilling activities. Hydraulic fracturing is an important and common practice that is used to stimulate production of hydrocarbons, particularly natural gas, from tight formations, including shales. The process, which involves the injection of water, sand, and chemicals under pressure into formations to fracture the surrounding rock and stimulate production, is typically regulated by state oil and natural gas commissions. However, federal agencies have asserted regulatory authority over certain aspects of the process. For example, the EPA has asserted federal regulatory authority pursuant to the federal Safe Drinking Water Act over certain hydraulic fracturing activities involving the use of diesel fuels in fracturing fluids and has issued permitting guidance that applies to such activities.

There is considerable uncertainty surrounding regulation of the emissions of methane, which may be released during hydraulic fracturing. In addition to the EPA’s new Subpart OOOO regulations discussed above, other federal agencies have promulgated rules regulating methane. In November 2022, the U.S. Bureau of Land Management (the “BLM”) proposed new regulations to reduce the waste of natural gas during the production of oil and gas on federal and tribal lands. The proposed rule

would require new and existing operators to submit waste minimization plans with all applications for permits to drill oil wells and includes a number of specific affirmative obligations that operators must take to avoid wasting oil or gas through venting, flaring, and leaks. A final rule was expected by January 2024 but has not been issued to date, and such final rule, once published, may face challenges and legal scrutiny. As a result, future implementation of methane rules by the BLM is uncertain at this time. However, given the long-term trend towards increasing regulation, future federal regulation of methane and other GHG emissions from the oil and gas industry remains a possibility.

The EPA has also issued effluent limitation guidelines that prohibit the discharge of wastewater from hydraulic fracturing operations to publicly owned wastewater treatment plants. Also, from time to time, legislation has been introduced, but not enacted, in Congress to provide for federal regulation of hydraulic fracturing and to require disclosure of the chemicals used in the hydraulic fracturing process. It is unclear how any additional federal regulation of hydraulic fracturing activities may affect our operations, but additional regulatory burdens on our customers could ultimately result in decreased demand for our services.

Various studies analyzing the potential environmental impacts of hydraulic fracturing have also been performed. For example, the EPA issued a report on the potential impacts of hydraulic fracturing on drinking water resources, which concluded that “water cycle” activities associated with hydraulic fracturing may impact drinking water resources “under some circumstances,” noting that the following hydraulic fracturing water cycle activities and local- or regional-scale factors are more likely than others to result in more frequent or more severe impacts: water withdrawals for fracturing in times or areas of low water availability; surface spills during the management of fracturing fluids, chemicals or produced water; injection of fracturing fluids into wells with inadequate mechanical integrity; injection of fracturing fluids directly into groundwater resources; discharge of inadequately treated fracturing wastewater to surface waters; and disposal or storage of fracturing wastewater in unlined pits. As described elsewhere in this Annual Report, these risks are regulated under various state, federal, and local laws.

Some states, counties, and municipalities have implemented, or are considering, increased regulatory oversight of hydraulic fracturing through additional permit requirements, operational restrictions, disclosure requirements, well construction, and temporary or permanent bans on hydraulic fracturing in certain areas. For example, some states have banned the use of high-volume hydraulic fracturing, and others have adopted regulations that impose new or more stringent permitting, disclosure, disposal, and well construction requirements on hydraulic fracturing operations. Alternatively, some municipalities are, or have considered, zoning and other ordinances, the conditions of which could impose a de facto ban on drilling and/or hydraulic fracturing operations. Further, some states, counties, and municipalities are closely examining water use issues, such as permit and disposal options for processed water, which could have a material adverse impact on our financial condition, prospects, and results of operations if such additional permitting requirements are imposed upon our industry. If new laws or regulations that significantly restrict hydraulic fracturing are adopted, such laws could reduce demand for our business by making it more difficult or costly for certain customers to perform fracturing to stimulate production from tight formations. In addition, if hydraulic fracturing becomes regulated at the federal level as a result of federal legislation or regulatory initiatives by the EPA, the business and operations of our customers could be subject to additional permitting requirements, attendant permitting delays, increased operating and compliance costs and process prohibitions, which could have an adverse effect on our business, financial condition, and results of operations.

In light of concerns about seismic activity being triggered by the injection of produced waters into underground wells, certain regulators have also implemented or are considering implementing additional requirements related to seismic safety for hydraulic fracturing activities. A 2015 U.S. Geological Survey report identified eight states, including Texas, with areas of increased rates of induced seismicity that could be attributed to fluid injection or oil and gas extraction. Any regulation that restricts the ability of our customers to dispose of produced waters or increases their cost of doing business could cause them to curtail operations, which in turn could decrease demand for our services and have a material adverse effect on our business.

National Environmental Policy Act

Businesses and operations of our customers that are carried out on federal lands may be subject to the National Environmental Policy Act (“NEPA”), which requires federal agencies, including the Department of the Interior (the “DOI”), to evaluate major agency actions having the potential to significantly impact the human environment. In the course of such evaluations, an agency will evaluate the potential direct, indirect, and cumulative impacts of a proposed project and, if necessary, will prepare a detailed Environmental Impact Statement that must be made available for public review and comment. In July 2020, the Council on Environmental Quality revised NEPA’s implementing regulations in an effort to streamline approvals for projects. In October 2021, the Council on Environmental Quality announced its Phase 1 rule, the first of two planned rules to roll back the 2020 rule, which was finalized in April 2022. The Phase 1 final rule generally restores certain regulatory provisions that were in effect prior to the 2020 rule. In July 2023, the Council on Environmental Quality proposed a Phase 2 rule that would accelerate NEPA reviews while maintaining consideration of relevant environmental, climate change,

and environmental justice effects. The final rule is expected in April 2024. To the extent that our customers’ current activities, as well as proposed plans, on federal lands require governmental permits that are subject to the requirements of NEPA, this process has the potential to delay or impose additional conditions upon the development of oil and natural gas projects.

Endangered Species Act and Migratory Bird Treaty Act

The Endangered Species Act was established to protect endangered and threatened species. Pursuant to that act, if a species is listed as threatened or endangered, restrictions may be imposed on activities adversely affecting that species or its habitat. The U.S. Fish and Wildlife Service (the “FWS”) must also designate the species’ critical habitat and suitable habitat as part of the effort to ensure survival of the species. A critical habitat or suitable habitat designation could result in further material restrictions to land use and may materially delay or prohibit land access for oil and natural gas development. Similar protections are offered to migratory birds under the Migratory Bird Treaty Act (the “MBTA”), which makes it illegal to, among other things, hunt, capture, kill, possess, sell, or purchase migratory birds, nests, or eggs without a permit. This prohibition covers most bird species in the U.S. In January 2021, the DOI finalized a rule limiting application of the MBTA; however, the DOI revoked the rule in October 2021 and issued an advance notice of proposed rulemaking seeking comment on the DOI’s plan to develop regulations that authorize incidental take under certain prescribed conditions. The notice of proposed rulemaking was anticipated in November 2023, with final action expected in April 2024, but the FWS instead announced in November 2023 that it had received additional technical comments that need further review. As a result, future amendments to the MBTA are uncertain. If our customers were to have areas within their business and operations designated as critical or suitable habitat for a protected species, it could decrease demand for our services and have a material adverse effect on our business. There is also increasing interest in nature-related matters beyond protected species, such as general biodiversity, which may similarly require us or our customers to incur costs or take other measures that may adversely impact our business or operations.

Item 1A. Risk Factors

We face many challenges and risks in the industry in which we operate. You should carefully consider each of the following risk factors and all of the other information set forth in this Annual Report, including under the section titled “Cautionary Note Regarding Forward-Looking Statements.” The risks and uncertainties described are not the only ones we face. Additional risk factors not presently known to us or which we currently consider immaterial may also adversely affect our business, financial condition, or future results. If any of these risks were actually to occur, our business, financial condition, or results of operations could be materially adversely affected. In that case, the trading price of our common stock could decline, and a stockholder could lose all or part of its investment.

Risks Related to Our Industry

Our business is cyclical and depends on capital spending and well completions by the onshore oil and natural gas industry, and the level of such activity is volatile. Our business has been, and may continue to be, adversely affected by industry and financial market conditions that are beyond our control.

Our business is cyclical, and we depend on our customers’ willingness to make operating and capital expenditures to explore for, develop, and produce oil and natural gas, which, in turn, largely depends on prevailing industry and financial market conditions that are influenced by numerous factors beyond our control, including:

•the level of prices, and expectations about future prices, for oil and natural gas;

•the domestic and foreign supply of, and demand for, oil and natural gas and related products;

•the level of global and domestic oil and natural gas production;

•the supply of, and demand for, hydraulic fracturing and other oilfield services and equipment;

•governmental regulations, including the policies of governments regarding the exploration for and production and development of their oil and natural gas reserves;

•the cost of exploring for, developing, producing, and delivering oil and natural gas;

•available pipeline, storage, and other transportation capacity;

•worldwide political, military, and economic conditions;

•lead times associated with acquiring equipment and products and availability of qualified personnel;

•the discovery rates of new oil and natural gas reserves;

•federal, state, and local regulation of hydraulic fracturing and other oilfield service activities, as well as E&P activities, including public pressure on governmental bodies and regulatory agencies to regulate our industry;

•economic and political conditions in oil and natural gas producing countries;

•actions of OPEC, its members, and other state-controlled oil companies relating to oil price and production levels, including announcements of potential changes to such levels;

•advances in exploration, development, and production technologies or in technologies affecting energy consumption;

•activities by non-governmental organizations to restrict the exploration, development, and production of oil and natural gas so as to minimize emissions of carbon dioxide, a GHG;

•the price and availability of alternative fuels and energy sources;

•global weather conditions and natural disasters, including those related to the physical effects of climate change; and

•uncertainty in capital and commodities markets and the ability of oil and natural gas producers to access capital.

A decline in oil and natural gas commodity prices may adversely affect the demand for our products and services and the rates we are able to charge.

Our business depends, to a significant extent, on the level of unconventional resource development activity and corresponding capital spending of oil and natural gas companies, which are strongly influenced by current and expected oil and natural gas prices. Volatility or weakness in oil and natural gas commodity prices (or the perception that oil and natural gas commodity prices will decrease) affects the spending patterns of our customers and may result in the drilling of fewer new wells or lower production spending on existing wells. Historically, oil and natural gas commodity prices have been extremely volatile. During the five years ending December 31, 2023, the posted price for West Texas Intermediate (“WTI”) oil has ranged from a low of $(36.98) per barrel in April 2020 to a high of $123.64 per barrel in March 2022, and the Henry Hub spot market price of gas has ranged from a low of $1.33 per MMBtu in September 2020 to a high of $23.86 per MMBtu in February 2021. Moreover, the theme of capital discipline for E&P operators in the energy industry has led to a disconnect between commodity prices and market activity. The average WTI price for 2023 was $77.58, an increase of 36% over the average WTI price in 2019; however, the average rig count decreased by 27% over that same period. If prices of oil and natural gas decline or our customers do not increase capex and activity levels, our business, financial condition, results of operations, cash flows, and prospects may be materially and adversely affected.

Significant factors that are likely to affect near-term commodity prices include actions of members of OPEC and other oil exporting nations, including Russia, relating to oil export prices and production levels; the effect of U.S. energy, monetary, and trade policies; the pace of economic growth in the U.S. and throughout the world, including the potential for macro weakness; geopolitical and economic developments in the U.S. and globally, including conflicts, instability, acts of war or terrorism in oil producing countries or regions, particularly Russia, the Middle East, South America and Africa; changes to energy and EPA policies; and overall North American natural gas supply and demand fundamentals, including the pace at which export capacity grows. For additional information, please see “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Overview – Industry Trends and Outlook” in Item 7 of Part II of this Annual Report.

The products and services we provide are, to a substantial extent, deferrable in the event oil and natural gas companies reduce capital expenditures. As a result, we may experience lower utilization of, and may be unable to increase rates or be forced to lower our rates for, our equipment and services in weak oil and natural gas commodity price environments. Even with supportive oil and natural gas prices, E&P operator activity may not materially increase, as they remain focused on operating within their capital plans. Moreover, any substantial and unexpected drop in commodity prices in the future, even if the drop is relatively short-lived, or expectations of such a drop or of prolonged weak oil and natural gas commodity price environments, could similarly affect our customers’ expectations and capital spending, which could result in a material adverse effect on our business, financial condition, results of operations, cash flows, and prospects.

Reduced discovery rates of new oil and natural gas reserves in our market areas as a result of decreased capital spending may also have a negative long-term impact on our business, even in an environment of stronger oil and natural gas prices, to the extent the reduced number of wells for us to service more than offsets increasing completion activity and intensity.

Our business could be adversely affected by a decline in general economic conditions or a weakening of the broader energy industry, and inflation may adversely affect our financial position and operating results.

A prolonged economic slowdown or recession, adverse events relating to the energy industry, or regional, national, or global economic conditions and factors, particularly a slowdown in the E&P industry, could negatively impact our operations and therefore adversely affect our results. The risks associated with our business are more acute during periods of economic slowdown or recession because such periods may be accompanied by decreased exploration and development spending by our customers, decreased demand for oil and natural gas, and decreased prices for oil and natural gas.

Inflationary factors, such as increases in the labor costs, material costs, and overhead costs, may also adversely affect our financial position and operating results. Like others in our industry, we faced, and we continue to face, cost inflation with both labor and materials, which could offset any price increases for our products and services.

Increased attention to climate change and conservation measures may expose us to climate-related transition risks, including evolving climate change legislation, fuel conservation measures, technological advances, and negative shift in market perception towards the oil and natural gas industry, which could result in reduced demand for oil and natural gas.

Increased attention to climate change from governmental and regulatory bodies, investors, consumers, industry and other stakeholders, changes in consumer behavior and related demand for alternatives to oil and natural gas, societal expectations on companies to address climate change, preferences and attitudes with respect to the generation and consumption of energy, the use of hydrocarbons, and the use of products manufactured with, or powered by, hydrocarbons, may result in the

enactment of climate change-related regulations, policies and initiatives (at the government, regulator, corporate and/or investor community levels), including alternative energy requirements, new fuel consumption standards, energy conservation and emissions reductions measures and responsible energy development, technological advances with respect to the generation, transmission, storage and consumption of energy, and increased availability and competitiveness of alternative energy sources (such as wind, solar geothermal, tidal, fuel cells, and biofuels). These developments could reduce demand for oil and natural gas and therefore our products and services, which would lead to a reduction in our revenues and have a material adverse effect on our business, financial condition, results of operations, cash flows, and prospects.

In addition, the enactment of climate change-related regulations, policies, and initiatives (at the government, corporate and/or investor community levels) may in the future result in increases in our compliance costs and other operating costs and have other adverse effects (e.g., greater potential for governmental investigations or litigation). For further discussion regarding the risks posed to us by climate change-related regulations, policies, and initiatives and by negative public perception of the oil and gas industry, see the discussions below in “Negative public perception of the oil and gas industry could adversely affect our operations and our ability raise debt and equity capital” and “Existing or future laws and regulations related to GHGs and climate change could have a negative impact on our business and may result in additional compliance obligations with respect to the release, capture, and use of GHGs that could have a material adverse effect on our business, results of operations, prospects, and financial condition.”

Negative public perception of the oil and gas industry could adversely affect our operations and our ability to raise debt and equity capital.

Opposition toward the oil and natural gas industry has been growing globally and is particularly pronounced in the United States. Companies in the oil and natural gas industry are often the target of activist efforts from both individuals and non-governmental organizations or subject to pressure from other stakeholders regarding safety, human rights, climate change and other environmental matters, sustainability, and business practices. Anti-development activists are working to, among other things, reduce access to federal and state government lands and delay or cancel certain operations such as drilling and development. Any such activism against oil and natural gas exploration and development may cause operational delays or restrictions, increased operating costs, additional regulatory burdens, and increased risk of litigation.

In addition, some parties have initiated public nuisance claims under federal or state common law against certain companies involved in the production of oil and natural gas, or claims alleging that the companies have been aware of the adverse effects of climate change for some time but failed to adequately disclose such impacts to their investors or customers. Although our business is not a party to any such litigation, we could be named in actions making similar allegations, which could lead to costs and materially impact our financial condition in an adverse way.

Negative perceptions regarding our industry and reputational risks may also in the future adversely affect our ability to successfully carry out our business strategy by adversely affecting our access to capital. Certain segments of the investor community have developed negative sentiment towards investing in our industry. Parties concerned about the potential effects of climate change have directed their attention at sources of financing for energy companies, including by promoting divestment of fossil fuel equities and pressuring lenders to limit funding and insurance underwriters to limit coverage to companies engaged in the extraction of fossil fuel reserves, which has resulted in certain financial institutions, funds, and other capital providers restricting or eliminating their investment in oil and natural gas activities. In addition, some investors, including investment advisors and certain sovereign wealth funds, pension funds, university endowments, and family foundations, have stated policies to disinvest in the oil and gas sector based on their social and environmental considerations. Further, certain investment banks and asset managers based both domestically and internationally have announced that they are adopting climate change guidelines for their banking and investing activities. Certain other stakeholders have also pressured commercial and investment banks to stop financing oil and gas production and related infrastructure projects. Institutional lenders who provide financing to energy companies have also become more attentive to sustainable lending practices, and some may elect not to provide traditional energy producers or companies that support such producers with funding. Such developments, including environmental activism, investment policies and initiatives, and related litigation aimed at limiting climate change and reducing air pollution, could result in downward pressure on the stock prices of oil and gas companies, including ours. These developments may also potentially result in a reduction of available capital funding for potential development projects, impacting our future financial results.

Increased scrutiny of sustainability matters could have an adverse effect on our business and damage our reputation.

In recent years, companies across all industries are facing increasing scrutiny from a variety of stakeholders, including investor advocacy groups, proxy advisory firms, certain institutional investors and lenders, investment funds and other influential investors and rating agencies, related to their environmental, social and governance (“ESG”) and sustainability practices. If we do not adapt to or comply with investor or other stakeholder expectations and standards on ESG matters (or

meet sustainability goals and targets that we have set) as they continue to evolve, or if we are perceived to have not responded appropriately or quickly enough to growing concern for ESG and sustainability issues, regardless of whether there is a regulatory or legal requirement to do so, we may suffer from reputational damage and our business, financial condition and/or stock price could be materially and adversely affected.

In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings processes for evaluating companies on their approach to ESG matters. Such ratings are used by some investors to inform their investment and voting decisions. Unfavorable ESG ratings could lead to increased negative investor sentiment toward us and our industry and to the diversion of investment to other industries, which could have a negative impact on our stock price and our access to and costs of capital.

Risks Related to Our Indebtedness

Our substantial debt obligations could have significant adverse consequences on our business and future prospects.

At December 31, 2023, we had $300.0 million of 13.000% Senior Secured Notes due 2028 (the “2028 Notes”) outstanding, and we had $57.0 million of borrowings under the ABL Credit Facility (as defined and described in “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources” in Item 7 of Part II of this Annual Report) outstanding. Subject to the restrictions in the ABL Credit Agreement (as defined and described in “Management’s Discussion and Analysis of Financial Condition and Results of Operations – Liquidity and Capital Resources” in Item 7 of Part II of this Annual Report) and the indenture governing the 2028 Notes, we may incur substantial additional indebtedness (including secured indebtedness) in the future. Our current or future level of indebtedness could have significant adverse consequences on our business and future prospects, including in the following ways:

•requiring us to dedicate a substantial portion of our cash flow from operations to service our existing debt, thereby reducing the cash available to finance our operations and other business activities;

•limiting management’s discretion in operating our business and our flexibility in planning for, or reacting to, changes in our business and the industry in which we operate;

•increasing our vulnerability to downturns and adverse developments in our business and the economy generally;

•limiting our ability to access the capital markets to raise capital on favorable terms or to obtain additional financing for working capital, capital expenditures, or acquisitions or to refinance existing indebtedness;

•placing us at a competitive disadvantage relative to competitors with lower levels of indebtedness in relation to their overall size or less restrictive terms governing their indebtedness; and

•making it more difficult for us to satisfy our obligations under our debt instruments and increase the risk that we may default on our debt obligations.

Additionally, borrowings under the ABL Credit Facility bear interest at variable rates exposing us to interest rate risk. If interest rates increase, our debt service obligations on the variable rate indebtedness would increase even though the amount borrowed remains the same, and our net income and cash available to finance our operations and other business activities would decrease.

We may not be able to generate sufficient cash to service all of our indebtedness.

Our ability to make scheduled payments with respect to our indebtedness depends on our financial condition and operating performance, which are subject to prevailing economic and competitive conditions and certain financial, business, and other factors beyond our control. If our cash flows and capital resources are insufficient to fund debt service obligations, we may be forced to sell assets, seek additional capital, or restructure or refinance indebtedness. These alternative measures may not be successful and may not permit us to meet scheduled debt service obligations. For example, we may not be able to consummate dispositions, and the proceeds of any such disposition may not be adequate to meet any debt service obligations then due. Also, our ability to restructure or refinance indebtedness will depend on the condition of the capital markets and our financial condition at such time. Any refinancing of indebtedness could be at higher interest rates and may require us to comply with more onerous covenants, which could further restrict business operations. In addition, any debt restructuring transactions may involve the issuance of additional equity or convertible debt securities that could result in material dilution to our stockholders, and these securities could have rights superior to holders of our common stock and could contain covenants that will restrict our operations. The terms of existing or future debt instruments may restrict us from adopting some of these

alternatives.

If we are unable to generate sufficient cash flow and are otherwise unable to obtain funds necessary to meet required payments of principal, premium, if any, and interest on our indebtedness, we could be in default under the terms of the agreements governing such indebtedness. An event of default, if not waived, could result in acceleration of the indebtedness outstanding under the applicable agreement and an event of default with respect to, and an acceleration of, the indebtedness outstanding under any other debt agreements to which we are a party. Any such accelerated indebtedness would become immediately due and payable. If that occurs, we may not be able to make all of the required payments. In addition, any failure to make payments on outstanding indebtedness on a timely basis would likely result in a reduction of our credit rating, which could harm our ability to incur additional indebtedness.

Restrictions in our debt agreements could limit our growth and our ability to engage in certain activities.

The ABL Credit Facility and the indenture governing our 2028 Notes have, and future financing agreements could have, restrictive covenants that could restrict our ability to finance future operations or capital needs or to expand or pursue our business activities. For example, our debt agreements contain restrictive covenants that limit our ability to, among other things:

•incur additional indebtedness and guarantee indebtedness;

•pay dividends or make other distributions or repurchase or redeem our capital stock;

•transfer or sell assets;

•make loans and investments;

•incur liens;

•enter into agreements that restrict dividends or other payments from any non-guarantor restricted subsidiaries to us;

•consolidate, merge, or sell all or substantially all of our assets;

•prepay, redeem, or repurchase certain debt;

•issue certain preferred stock or similar equity securities;

•make certain acquisitions and investments;

•engage in transactions with affiliates; and

•create unrestricted subsidiaries.

The restrictions in our debt agreements could also impact our ability to obtain capital to withstand a downturn in our business or the economy in general, or to otherwise conduct necessary corporate activities. We may also be prevented from taking advantage of business opportunities that arise because of the limitations that the restrictive covenants under our debt arrangements may impose on us.

A breach of any covenant in our debt agreements will result in a default under the applicable agreement and an event of default under such agreement if there is no grace period or if such default is not cured during any applicable grace period. An event of default, if not waived, could result in acceleration of the indebtedness outstanding under the applicable agreement and an event of default with respect to, and an acceleration of, the indebtedness outstanding under any other debt agreements to which we are a party. Any such accelerated indebtedness would become immediately due and payable. If that occurs, we may not be able to make all of the required payments or borrow sufficient funds to refinance such indebtedness. Even if new financing were available at that time, it may not be on terms that are acceptable to us.

Competition and Market Risks

We may be unable to maintain existing prices or implement price increases on our products and services.

We periodically seek to increase the prices on our products and services to offset rising costs and to generate higher returns for our stockholders. However, we operate in a very competitive industry and as a result, we are not always successful in raising or maintaining our existing prices. Volatility in oil and natural gas prices can impact our customers’ activity levels,

and current energy prices are important contributors to cash flow for our customers and their actual or perceived ability to fund exploration and development activities, which may limit our ability to increase or maintain prices. Additionally, during periods of increased market demand, a significant amount of new service capacity, including new well service rigs, wireline units, and coiled tubing units, may enter the market, which also puts pressure on the pricing of our services and limits our ability to increase prices.

Even when we are able to increase our prices, we may not be able to do so at a rate that is sufficient to offset rising costs. In periods of high demand for oilfield services, a tighter labor market may result in higher labor costs. During such periods, our labor costs could increase at a greater rate than our ability to raise prices for our services. Also, we may not be able to successfully increase prices without adversely affecting our activity levels. The inability to maintain our pricing and to increase our pricing as costs increase could have a material adverse effect on our business, financial position, results of operations, and cash flows.

Intense competition in the markets for our dissolvable plug products may lead to pricing pressures, reduced sales, or reduced market share.

The completion services industry is intensely competitive. We compete with major domestic and international oilfield services companies, many of which have greater market recognition and substantially greater financial, technical, marketing, distribution, and other resources than we do.

We have experienced pricing declines in certain of our more mature proprietary product lines, primarily due to competitive conditions. Likewise, our customers may seek pricing declines more precipitously than our ability to reduce costs, leaving us unable to achieve or maintain pricing to our customers at a level sufficient to cover our costs. Furthermore, our industry has generally experienced price erosion for new technologies as additional competing products enter the market. We are continuing to work on reducing manufacturing costs of our products, as well as introducing new and differentiated technology to improve profitability; however, there can be no assurance that we will be able to do so in the future. If the amounts we are able to charge customers for our dissolvable plug products decline further or are insufficient to cover our costs, that could have a material adverse effect on our financial condition, results of operations, and cash flows.

Our current and potential competitors may have longer operating histories, significantly greater financial or technical resources, and greater name recognition than we do.

The oilfield services industry is highly competitive and fragmented and includes several large companies that compete in many of the markets we serve, as well as numerous small companies that compete with us on a local basis. The oilfield services industry competes primarily on a regional basis, and the intensity of competition may vary significantly from region to region at any particular time. We believe the principal competitive factors in the market areas we serve include price, equipment quality, supply chains, balance sheet strength and financial condition, product and service quality, safety record, availability of crews and equipment, and technical proficiency.

Many of our existing and potential competitors have substantially greater financial, technical, manufacturing, and other resources than we do. The greater size of many of our competitors provides them with cost advantages as a result of their economies of scale and their ability to obtain volume discounts and purchase raw materials at lower prices. As a result, such competitors may have stronger bargaining power with their suppliers and have an advantage over us in pricing as well as securing a sufficient supply of raw materials during times of shortage. Many of our competitors also have better brand name recognition, stronger presence in more geographic markets, more established distribution networks, larger customer bases, more in-depth knowledge of the target markets, and the ability to provide a much broader array of products and services. Some of our competitors may also be able to devote greater resources to the research and development, promotion, and sale of their products and better withstand the evolving industry standards and changes in market conditions as compared to us. Our operations may be adversely affected if our competitors introduce new products or services with better features, performance, prices, or other characteristics than our products and services or expand into service areas where we operate. Our operations may also be adversely affected if our competitors are able to respond more quickly to new or emerging technologies and services and changes in customer requirements.

Competitive pressures could reduce our market share or require us to reduce the price of our services and products, particularly during industry downturns, either of which would harm our business and operating results. Significant increases in overall market capacity have also caused active price competition and led to lower pricing and utilization levels for our services and products. The competitive environment has intensified since the industry downturn that began in late 2014, which caused an oversupply of, and reduced demand for, oilfield services, and we have seen substantial reductions in the prices we can charge for our services and products. Any significant future increase in overall market capacity for completion services may adversely affect our business, financial condition, and results of operations.

Operational Risks

Our operations are subject to conditions inherent in the oilfield services industry.

Conditions inherent in the oil and natural gas industry can cause personal injury or loss of life, disruption or suspension in operations, damage to geological formations, damage to facilities, substantial revenue loss, business interruption, and damage to, or destruction of, property, equipment, and the environment. Such risks may include, but are not limited to:

•equipment defects;

•liabilities arising from accidents or damage involving our fleet of trucks and other equipment;

•explosions and uncontrollable flows of gas or well fluids;

•unusual or unexpected geological formations or pressures and industrial accidents;

•blowouts;

•fires;

•cratering;

•loss of well control;

•collapse of the borehole; and

•damaged or lost equipment.

Defects or other performance problems in the products that we sell or services that we offer could result in our customers seeking damages from us for losses associated with these defects or other performance problems. In addition, our services could become a source of spills or release of fluids, including chemicals used during hydraulic fracturing activities, at the site where such services are performed, or could result in the discharge of such fluids into underground formations that were not targeted for fracturing or well completion activities, such as potable aquifers, or at third-party properties. These risks could expose us to substantial liability for personal injury, wrongful death, property damage, loss of oil and natural gas production, pollution, and other environmental damages and could result in a variety of claims, losses, and remedial obligations that could have an adverse effect on our business and results of operations. The existence, frequency, and severity of such incidents could affect operating costs, insurability, and relationships with customers, employees, and regulators. In particular, our customers may elect not to purchase our services if they view our safety record as unacceptable or otherwise experience material defects in our products or performance problems, which could cause us to lose substantial revenue. In addition, any litigation or claim, even if fully indemnified or insured, could negatively affect our reputation with our customers and the public, which could cause us to lose customers and substantial revenue, make it more difficult for us to compete effectively, or obtain adequate insurance in the future.

Our assets require capital for maintenance, upgrades, and refurbishment, and we may require capital expenditures for new equipment.

Our equipment requires capital investment in maintenance, upgrades, and refurbishment to maintain their competitiveness. For the years ended December 31, 2023 and 2022, we spent approximately $12.6 million and $13.6 million, respectively, on capital expenditures related to maintenance. Our equipment typically does not generate revenue while it is undergoing maintenance, upgrades, or refurbishment. Any maintenance, upgrade, or refurbishment project for our assets could increase our indebtedness or reduce cash available for other opportunities. Further, such projects may require proportionally greater capital investments as a percentage of total asset value, which may make such projects difficult to finance on acceptable terms. To the extent we are unable to fund such projects, we may have less equipment available for service or our equipment may not be attractive to potential or current customers. Additionally, competition or advances in technology within our industry may require us to update our products and services. Such demands on our capital or reductions in demand and the increase in cost to maintain labor necessary for such maintenance and improvement, in each case, could have a material adverse effect on our business, liquidity position, financial condition, prospects, and results of operations and may increase costs. In addition, although such projects may require material capital expenditures, there is no assurance that they will generate a positive return.

Seasonal and adverse weather conditions and the physical risks arising from climate change may have a negative impact on our business and result of operations, including by impacting operations, increasing costs, and adversely affecting demand for our products and services.

Weather can have a significant impact on demand for our services and products as consumption of energy is seasonal, and any variation from normal weather patterns or cooler or warmer summers and winters can have a significant impact on demand. In addition, adverse weather conditions, such as hurricanes, tropical storms, and severe cold weather, may interrupt or curtail our operations or our customers’ operations, cause supply disruptions, and damage our equipment and facilities, which may or may not be insured. In addition, most scientists have concluded that increasing concentrations of GHGs in the Earth’s atmosphere may produce climate changes that could have significant physical effects, such as increased frequency and severity of storms, droughts, floods, extreme temperatures, and other climatic events. If any such effects were to occur, they could adversely affect or delay demand for oil and natural gas, which, in turn, could also reduce the demand for our products and services; cause us to incur significant costs in preparing for or responding to the effects of climatic events themselves, which may not be fully insured; adversely impact our or our customers’ operations, workforce, supply chain or distribution chain; or potentially lead to increased costs for insurance coverages in the aftermath of such effects. Our ability to mitigate the adverse physical impacts of climate change depends in part upon our disaster preparedness and response and business continuity planning. During the winter months (portions of the first and fourth quarters) and periods of heavy snow, ice, or rain, particularly in the northeastern U.S., Michigan, North Dakota, Wyoming, and western Canada, our customers may delay operations, or we may not be able to operate or move our equipment between locations. Also, during the spring thaw, which normally starts in late March and continues through June, some areas, primarily in western Canada, impose transportation restrictions to prevent damage caused by the spring thaw. For both the years ended December 31, 2023 and 2022, we generated approximately 0.3% of our revenue from our operations in western Canada. Lastly, throughout the year heavy rains adversely affect activity levels because well locations and dirt access roads can become impassible in wet conditions.

In addition, we typically have experienced a pause by our customers around the holiday season in the fourth quarter, which may be compounded as our customers exhaust their annual capital spending budgets towards year end.

Risks Related to Our Customers and Suppliers

If we are unable to accurately predict customer demand or if customers cancel their orders on short notice, we may hold excess or obsolete inventory, which would reduce gross margins. Conversely, insufficient inventory would result in lost revenue opportunities and potentially loss of market share and damaged customer relationships.

We often place orders with our suppliers based on forecasts of customer demand. Anticipating customer demand is difficult because our customers face unpredictable demand for their own products and are increasingly focused on cash preservation and tighter inventory management. Our forecasts of customer demand are based on multiple assumptions, each of which may introduce errors into the forecasts. If we overestimate customer demand, we may allocate resources to the purchase of material or manufactured products that we may not be able to sell when we expect to, if at all. As a result, we would hold excess or obsolete inventory, which would reduce gross margin and adversely affect financial results. Conversely, if we underestimate customer demand or if insufficient manufacturing capacity is available, we would miss revenue opportunities and potentially lose market share and damage our customer relationships. In addition, any future significant cancellations or deferrals of orders or the return of previously sold products could materially and adversely affect profit margins, increase inventory obsolescence, and restrict our ability to fund our operations.

We are exposed to the credit risk of our customers, and the deterioration of the financial condition of our customers could adversely affect our financial results.

We are subject to the risk of loss resulting from nonpayment or nonperformance by our customers, many of whose operations are concentrated solely in the domestic and Canadian E&P industry, which, as described above, is subject to volatility and, therefore, credit risk. Our credit procedures and policies may not be adequate to fully reduce customer credit risk. If we are unable to adequately assess the creditworthiness of existing or future customers or unanticipated deterioration in their creditworthiness, any resulting increase in nonpayment or nonperformance by them and our inability to re-market or otherwise use our equipment could have a material adverse effect on our business, financial condition, prospects, and/or results of operations. In the course of our business, we hold accounts receivable from our customers. In the event of the financial distress or bankruptcy of a customer, we could lose all or a portion of such outstanding accounts receivable associated with that customer. Further, if a customer was to enter into bankruptcy, it could also result in the cancellation of all or a portion of our service contracts with such customer at significant expense or loss of expected revenues to us.

In addition, during times when the oil or natural gas markets weaken, our customers are more likely to experience financial difficulties, including being unable to access debt or equity financing, which could result in a reduction in our

customers’ spending for our products and services.

We are dependent on customers in a single industry. The loss of one or more significant customers could adversely affect our financial condition, prospects, and results of operations.

Our customers are engaged in the oil and natural gas E&P business, which has been historically volatile. For the year ended December 31, 2023, our five largest customers collectively accounted for approximately 21% of total revenues. If we were to lose several key alliances over a relatively short period of time or if one of our largest customers fails to pay or delays in paying a significant amount of our outstanding receivables, we could experience an adverse impact on our business, financial condition, results of operations, cash flows, and prospects. Additionally, the E&P industry is characterized by frequent consolidation activity. Changes in ownership of our customers may result in the loss of, or reduction in, business from those customers, which could materially and adversely affect our business, financial condition, results of operations, and prospects.

Certain of our product lines are subject to the risk of supplier concentration, and certain of our product lines are subject to exclusive distribution arrangements, which we may not be able to maintain.

Certain of the product lines depend on a limited number of third-party suppliers and vendors. As a result of this concentration in some supply chains, our business and operations could be negatively affected if certain key suppliers were to experience significant disruptions affecting the price, quality, availability, or timely delivery of their products. The partial or complete loss of any one of those key suppliers, or a significant adverse change in the relationship with any such suppliers, through consolidation or otherwise, may limit our ability to manufacture and sell certain of our product lines.

In addition, we have arrangements with certain technology companies and manufacturers that give us exclusive distribution rights to certain product offerings. In some cases, we are, or may in the future will be, required to meet certain minimum volume or other requirements in order to retain our arrangement. If any of these companies or manufacturers terminate our right to sell some or all of their products, modify or terminate our exclusive distribution arrangement, or change the applicable terms and conditions of sale, our business and results of operations could be adversely affected.

Regulatory, Compliance, and Legal Risks

Oilfield anti-indemnity provisions enacted by many states may restrict or prohibit a party’s indemnification of us.

We typically enter into agreements with our customers governing the provision of our services, which usually include certain indemnification provisions for losses resulting from operations. Such agreements may require each party to indemnify the other against certain claims regardless of the negligence or other fault of the indemnified party; however, many states place limitations on contractual indemnity agreements, particularly agreements that indemnify a party against the consequences of its own negligence. Furthermore, certain states, including Louisiana, New Mexico, Texas, and Wyoming, have enacted statutes generally referred to as “oilfield anti-indemnity acts” expressly prohibiting certain indemnity agreements contained in or related to oilfield services agreements. Such oilfield anti-indemnity acts may restrict or void a party’s indemnification of us, which could have a material adverse effect on our business, financial condition, prospects, and results of operations.

We may be subject to claims for personal injury and property damage or other litigation, which could materially adversely affect our financial condition, prospects, and results of operations.

Our services are subject to inherent risks that can cause personal injury or loss of life, damage to or destruction of property, equipment, or the environment, or the suspension of our operations. As the wells we service continue to become more complex, our exposure to such inherent risks becomes greater as downhole risks increase exponentially with an increase in complexity and lateral length. Our operations are also exposed to risks of labor organizing and risks of claims for alleged employment-related liabilities, including risks of claims related to alleged wrongful termination or discrimination, wage payment practices, retaliation claims, and other human resource related matters. Litigation arising from operations where our facilities are located, or our services are provided, may cause us to be named as a defendant in lawsuits asserting potentially large claims, including claims for exemplary damages. For example, transportation of heavy equipment creates the potential for our trucks to become involved in roadway accidents, which in turn could result in personal injury or property damages lawsuits being filed against us.

We maintain what we believe is customary and reasonable insurance to protect our business against most potential losses, but such insurance may not be adequate to cover our liabilities, especially as the inherent risks in our operations increase with increasing well complexity, and we are not fully insured against all risks, including alleged employment-related liabilities. Further, our insurance has deductibles or self-insured retentions and contains certain coverage exclusions. The current trend in the insurance industry is towards larger deductibles and self-insured retentions. In addition, insurance may not be available in

the future at rates that we consider reasonable and commercially justifiable, compelling us to have larger deductibles or self-insured retentions to effectively manage expenses. As a result, we could become subject to material uninsured liabilities or situations where we have high deductibles or self-insured retentions that expose us to liabilities that could have a material adverse effect on our business, financial condition, prospects, or results of operations.

In recent years, oilfield services companies have been the subject of a significant volume of wage and hour-related litigation, including claims brought under the Fair Labor Standards Act (“FLSA”), in which employee pay practices have been challenged. We have been named as defendants in these lawsuits, and we do not maintain insurance for alleged wage and hour-related litigation. Some of these cases remain outstanding and are in various states of negotiation and/or litigation, and the results or costs of any such cases may have an adverse effect on our business, operating results, and financial condition. The frequency and significance of wage- or other employment-related claims may affect expenses, costs, and relationships with employees and regulators. Additionally, we could become subject to material uninsured liabilities that could have a material adverse effect on our business, financial condition, prospects, or results of operations.

Delays or restrictions in obtaining, or inability to obtain or renew, permits or authorizations by our customers for their operations or by us for our operations could impair our business.

In most states, our operations and the operations of our customers require permits or authorizations from one or more governmental agencies or other third parties to perform drilling and completion and production activities, including hydraulic fracturing. Such permits or approvals are typically required by state agencies, but federal and local governmental permits may also be required. We are also required to obtain federal, state, local, and/or third-party permits and authorizations in some jurisdictions in connection with our wireline services and trucking operations. The requirements for permits or authorizations vary depending on the location where the associated activities will be conducted. As with most permitting and authorization processes, there is a degree of uncertainty as to whether a permit will be granted, the time it will take for a permit or approval to be issued, and the conditions which may be imposed in connection with the granting of the permit. Over the past several years, parts of the country have experienced extreme drought conditions. As a result of these conditions, some rural water districts have begun to impose restrictions on water use and may require permits for water used in drilling and completion activities. In addition, some of our customers’ drilling and completion activities may take place on federal land or Native American lands, requiring leases and other approvals from the federal government or Native American tribes to conduct such drilling and completion activities. Permitting, authorization, or renewal delays, the inability to obtain new permits, or the revocation of current permits could cause a loss of revenue and potentially have a materially adverse effect on our business, financial condition, prospects, or results of operations.

We are subject to federal, state, and local laws and regulations regarding issues of health, safety, and protection of the environment. Under these laws and regulations, we may become liable for penalties, damages, or costs of remediation or other corrective measures. Any changes in laws or government regulations could increase our costs of doing business.

Our operations are subject to stringent federal, state, local, and tribal laws and regulations relating to, among other things, protection of natural resources, clean air and drinking water, wetlands, endangered species, GHGs, air pollution, the environment, occupational health and safety, chemical use and storage, waste management, waste disposal, and transportation of waste and other hazardous and nonhazardous materials. Our operations involve risks of environmental liability, including leakage from an operator’s casing during our operations or accidental spills of hazardous materials onto or into surface or subsurface soils, surface water, or groundwater. Some environmental laws and regulations may impose strict liability, joint and several liability, or both. 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, third parties without regard to whether we caused or contributed to the conditions. Additionally, environmental concerns, including clean air, drinking water contamination, and seismic activity, have prompted investigations that could lead to the enactment of regulations, limitations, restrictions, or moratoria that could potentially have a material adverse impact on our business. Actions arising under these laws and regulations could result in the shutdown of our operations, fines and penalties (administrative, civil, or criminal), revocations of permits to conduct business, expenditures for remediation or other corrective measures, and/or claims for liability for property damage, exposure to hazardous materials, exposure to hazardous waste, nuisance, or personal injuries. Sanctions for noncompliance with applicable environmental laws and regulations may also include the assessment of administrative, civil, or criminal penalties, revocation of permits and temporary or permanent cessation of operations in a particular location, and issuance of corrective action orders. Such claims or sanctions and related costs could cause us to incur substantial costs or losses and could have a material adverse effect on our business, financial condition, prospects, and results of operations. Additionally, an increase in regulatory requirements or limitations, restrictions, or moratoria on oil and natural gas exploration and completion activities at a federal, state, or local level could significantly delay or interrupt our operations, limit the amount of work we can perform, increase our costs of compliance, or increase the cost of our services, thereby possibly having a material adverse impact on our financial condition.

If we do not perform our operations in accordance with government, industry, customer, or our own stringent occupational safety, health, and environmental standards, we could lose business from our customers, many of whom have an increased focus on environmental and safety issues.

We are subject to the oversight of the EPA, the DOT, the U.S. Nuclear Regulation Commission, Bureau of Alcohol, Tobacco, Firearms and Explosives, OSHA, and state regulatory agencies that regulate operations to prevent air, soil, and water pollution or to protect against the effects of ionizing radiation. The energy extraction sector is one of the sectors designated for increased enforcement by the EPA, which will continue to regulate our industry in the years to come, potentially resulting in additional regulations that could have a material adverse impact on our business, prospects, or financial condition.

The EPA regulates air emissions from all engines, including off-road diesel engines that are used by us to power equipment in the field under the CAA Tier 4 emission standards (the “Tier 4” standards). The Tier 4 standards require substantial reductions in emissions of particulate matter and nitrous oxide from off-road diesel engines. Such emission reductions can be achieved through the use of appropriate control technologies. Under these U.S. emission control regulations, we could be limited in the number of certain off-road diesel engines we can purchase if we are unable to find a sufficient number of Tier 4-compliant engines from manufacturers. Further, these emission control regulations could result in increased capital and operating costs.

Changes in environmental laws and regulations could lead to material increases in our costs, and liability exposure, for future environmental compliance and remediation. Additionally, if we expand the size or scope of our operations, we could be subject to regulatory requirements that are more stringent than the requirements under which we are currently allowed to operate or require additional authorizations to continue operations. Compliance with this additional regulatory burden could increase our operating or other costs.

Federal, state, and local legislative and regulatory initiatives relating to hydraulic fracturing could prohibit, restrict, or limit hydraulic fracturing operations, or increase our operating costs.

Our businesses are dependent on hydraulic fracturing and horizontal drilling activities. Hydraulic fracturing is an important and common practice that is used to stimulate production of hydrocarbons, particularly natural gas, from tight formations, including shales. The process, which involves the injection of water, sand, and chemicals under pressure into formations to fracture the surrounding rock and stimulate production, is typically regulated by state oil and natural gas commissions. However, federal agencies have asserted regulatory authority over certain aspects of the process. For more information on existing regulations and regulatory initiatives relating to hydraulic fracturing, see “Regulatory Matters – Hydraulic Fracturing” in Item 1 of Part I of this Annual Report.

If new laws or regulations that significantly restrict hydraulic fracturing are adopted, such laws could reduce demand for our business by making it more difficult or costly for certain customers to perform fracturing to stimulate production from tight formations. In addition, if hydraulic fracturing becomes regulated at the federal level as a result of federal legislation or regulatory initiatives by the EPA, the business and operations of our customers could be subject to additional permitting requirements, and also to attendant permitting delays, increased operating and compliance costs, and process prohibitions, which could have an adverse effect on our business, financial condition, and results of operations.

Existing or future laws and regulations related to GHGs and climate change could have a negative impact on our business and may result in additional compliance obligations with respect to the release, capture, and use of GHGs that could have a material adverse effect on our business, results of operations, prospects, and financial condition.

Changes in environmental requirements related to GHG emissions and climate change may negatively impact demand for our products and services. For example, oil and natural gas E&P may decline as a result of environmental requirements, including land use policies responsive to environmental concerns (e.g., numerous cities, including San Francisco, CA, and Seattle, WA, have banned the use of natural gas in new construction, and other cities, including New York, NY, are considering similar initiatives). Federal, state, and local agencies have been evaluating climate-related legislation and other regulatory initiatives that would restrict emissions of GHGs in areas in which we conduct business. Because our business depends on the level of activity in the oil and natural gas industry, existing or future laws and regulations related to GHGs and climate change, including incentives to conserve energy or use alternative energy sources, could have a negative impact on our business if such laws or regulations reduce demand for oil and natural gas.

Likewise, such restrictions may result in additional compliance obligations with respect to the release, capture, sequestration, and use of GHGs that could have a material adverse effect on our business, results of operations, prospects, and financial condition. Additionally, regulations requiring the disclosure of GHG emissions and other climate-related information are increasingly being adopted or proposed at the federal and state level. For example, the SEC issued a proposed rule in March

2022 that would mandate extensive disclosure of climate-related data, risks, and opportunities, including financial impacts, physical and transition risks, related governance and strategy, and GHG emissions, for certain public companies. We cannot predict the costs of implementation or any potential adverse impacts resulting from the rulemaking. However, to the extent this rulemaking is finalized as proposed, we could incur increased costs relating to the assessment and disclosure of climate-related risks. We may also face increased litigation risks related to disclosures made pursuant to the rule if finalized as proposed. In addition, enhanced climate disclosure requirements could accelerate the trend of certain stakeholders and lenders restricting or seeking more stringent conditions with respect to their investments in certain carbon-intensive sectors. See “Business – Regulatory Matters – Climate Change” for more information on existing and proposed climate change regulation.

Studies by either state or federal agencies demonstrating a correlation between earthquakes and oil and natural gas activities could result in increased regulatory and operational burdens.

In light of concerns about seismic activity being triggered by the injection of produced waters into underground wells, certain regulators have implemented or are considering implementing additional requirements related to seismic safety for hydraulic fracturing activities. A 2015 U.S. Geological Survey report identified eight states, including Texas, with areas of increased rates of induced seismicity that could be attributed to fluid injection or oil and gas extraction. Any regulation that restricts the ability of our customers to dispose of produced waters or increases their cost of doing business could cause them to curtail operation, which in turn could decrease demand for our products and services and have a material adverse effect on our business.

We are subject to complex U.S. and foreign laws and regulations governing anti-corruption and export controls and economic sanctions.

The U.S. Foreign Corrupt Practices Act (the “FCPA”), the U.K. Bribery Act (“UKBA”), Canada’s Corruption of Foreign Public Officials Act (the “CFPOA”), and similar anti-bribery and anti-corruption laws generally prohibit companies and their intermediaries from making improper payments or improperly providing anything of value for the purpose of obtaining or retaining business. We operate and make sales in parts of the world that may be viewed as higher risk for corruption or may have experienced some corruption in the past, and in some instances, strict compliance with the FCPA, UKBA, CFPOA, and similar anti-bribery laws may conflict with local practices. We are also subject to export control and economic sanctions laws and regulations, including those implemented by the U.S. Office of Foreign Assets Control, the U.S. Department of State, the U.S. Department of Commerce, the European Union and its member states, Her Majesty’s Treasury of the United Kingdom, and other relevant sanctions authorities. These measures can prohibit or restrict transactions and dealings with certain designated persons and in certain countries in which we conduct business. Despite efforts to ensure compliance, there can be no assurance that our directors, officers, employees, agents, and third-party intermediaries will comply with such laws and regulations. We can be held liable for violations under such laws and regulations either due to our acts or omissions or due to the acts or omissions of others, including intermediaries working on our behalf.

If we fail to comply with applicable laws and regulations, including those referred to above, we may be subject to criminal and civil penalties or other sanctions, which could harm our reputation and have a material adverse impact on our business, financial condition, results of operations, and prospects. Any investigation of any actual or alleged violations of such laws could also harm our reputation or have an adverse impact on our business, financial condition, results of operations, and prospects. Additionally, we could face other third-party claims by agents, stockholders, debt holders, or other interest holders or constituents of our company. Our customers in relevant jurisdictions could seek to impose penalties or take other actions adverse to our interests, and we may be required to dedicate significant time and resources to investigate and resolve allegations of misconduct, regardless of the merit of such allegations. Furthermore, compliance with this additional regulatory burden could increase our operating or other costs.

Changes in transportation regulations may increase our costs and negatively impact our results of operations.

We are subject to various transportation regulations including as a motor carrier by the DOT and by various federal, state, and tribal agencies, whose regulations include certain permit requirements of highway and safety authorities. These regulatory authorities exercise broad powers over our trucking operations, generally governing such matters as the authorization to engage in motor carrier operations, safety, equipment testing, driver requirements and specifications, and insurance requirements. Certain motor vehicle operators are required to register with the DOT. This registration requires an acceptable operating record. The DOT periodically conducts compliance reviews and may revoke registration privileges based on certain safety performance criteria, and a revocation could result in a suspension of operations. Since 2010, the DOT has pursued its Compliance, Safety, Accountability (“CSA”) program in an effort to improve commercial truck and bus safety. A component of CSA is the Safety Measurement System (“SMS”), which analyzes all safety violations recorded by federal and state law enforcement personnel to determine a carrier’s safety performance. The SMS is intended to allow the DOT to identify carriers with safety issues and intervene to address those problems.

The trucking industry is subject to possible regulatory and legislative changes that may impact our operations, such as changes in fuel emissions limits, hours of service regulations that govern the amount of time a driver may drive or work in any specific period, and limits on vehicle weight and size. For example, in December 2016, the DOT finalized minimum training standards for new drivers seeking a commercial driver’s license; in December 2017, the FMCSA mandated electronic logging devices in all interstate commercial trucks; and in June 2020, the FMCSA revised its Hours-of-Service Rule to modify break requirements for drivers and the number of hours they may drive in adverse conditions. As the federal government continues to develop and propose regulations relating to fuel quality, engine efficiency, and GHG emissions, we may experience an increase in costs related to truck purchases and maintenance, impairment of equipment productivity, a decrease in the residual value of vehicles, unpredictable fluctuations in fuel prices, and an increase in operating expenses. Increased truck traffic may contribute to deteriorating road conditions in some areas where our operations are performed. Our operations, including routing and weight restrictions, could be affected by road construction, road repairs, detours, and state and local regulations and ordinances restricting access to certain roads. Proposals to increase federal, state, or local taxes, including taxes on motor fuels, are also made from time to time, and any such increase would increase our operating costs. Also, state and local regulation of permitted routes and times on specific roadways could adversely affect our operations. We cannot predict whether, or in what form, any legislative or regulatory changes or municipal ordinances applicable to our logistics operations will be enacted and to what extent any such legislation or regulations could increase our costs or otherwise adversely affect our business or operations.

Risks Related to Technology

Our success may be affected by the use and protection of our proprietary technology as well as our ability to enter into license agreements. There are limitations to our intellectual property rights and, thus, our right to exclude others from the use of our proprietary technology.

Our success may be affected by our development and implementation of new product designs and improvements and by our ability to protect, obtain, and maintain intellectual property assets related to these developments. We rely on a combination of patents and trade secret laws to establish and protect this proprietary technology. We have received patents and have filed patent applications with respect to certain aspects of our technology, and we generally rely on patent protection with respect to our proprietary technology, as well as a combination of trade secrets and copyright law, employee and third-party non-disclosure agreements, and other protective measures to protect intellectual property rights pertaining to our products and technologies. In addition, we are a party to and rely on several arrangements with third parties, which give us exclusive distribution rights to certain product offerings with desirable intellectual property assets, and we may enter into similar arrangements in the future. Such measures may not provide meaningful protection of our trade secrets, know-how, or other intellectual property in the event of any unauthorized use, misappropriation, or disclosure. We cannot ensure that competitors will not infringe upon, misappropriate, violate, or challenge our intellectual property rights in the future. Additionally, we cannot ensure that our intellectual property rights will deter or prevent competitors from creating similar purpose products for our customers. If we are not able to adequately protect or enforce our intellectual property rights, such intellectual property rights may not provide significant value to our business, results of operations, or financial condition.

Moreover, our rights in our confidential information, trade secrets, and confidential know-how will not prevent third parties from independently developing similar technologies or duplicating such technologies. Publicly available information (e.g., information in issued patents, published patent applications, and scientific literature) can be used by third parties to independently develop technology, and we cannot provide assurance that this independently-developed technology will not be equivalent or superior to our proprietary technology. In addition, while we have patented some of our key technologies, we do not patent all of our proprietary technology, even when regarded as patentable. The process of seeking patent protection can be long and expensive. There can be no assurance that patents will be issued from currently pending or future applications or that, if patents are issued, they will be of sufficient scope or strength to provide meaningful protection or any commercial advantage to us. Further, with respect to exclusive third-party arrangements, these arrangements could be terminated, which would result in our inability to provide the services and/or products covered by such arrangements.

We may be adversely affected by disputes regarding intellectual property rights, and the value of our intellectual property rights is uncertain.

We may become involved in dispute resolution or litigation proceedings from time to time to protect and enforce our intellectual property rights. In these dispute resolution or litigation proceedings, a third-party defendant may assert that our intellectual property rights are invalid or unenforceable. Third parties from time to time may also initiate dispute resolution or litigation proceedings against us by asserting that our businesses infringe, impair, misappropriate, dilute, or otherwise violate another party’s intellectual property rights. For example, in April 2020, a third party filed a lawsuit asserting that our BreakThru Casing Flotation DeviceTM infringed its intellectual property rights, and in January 2022, a jury in the Western District of Texas, Waco Division, found in the third party’s favor. However, we intend to appeal the jury’s verdict. We may not prevail in such appeal or in any other proceedings relating to intellectual property rights, and our intellectual property rights may be found

invalid or unenforceable or our products and services may be found to infringe, impair, misappropriate, dilute, or otherwise violate the intellectual property rights of others, in which case we may be required to pay damages or other compensation to the other party (which could be costly) and/or cease use of such intellectual property. Also, as a part of resolving such disputes, we may enter into licenses, cross-licenses or other agreements, which could reduce the value of our existing intellectual property rights. The results or costs of any such dispute resolution or litigation proceedings may have an adverse effect on our business, operating results, and financial condition. Any dispute resolution or litigation proceeding concerning intellectual property could be protracted and costly, is inherently unpredictable, and could have an adverse effect on our business, regardless of its outcome.

Our success may be affected by our ability to implement new technologies and services.

Our success may be affected by the ongoing development and implementation of new product designs, methods, and improvements, and our ability to protect, obtain, and maintain intellectual property assets related to these developments. If we are not able to obtain patent or other protection of our technology, it may not be economical for us to continue to develop systems, services, and technologies to meet evolving industry requirements at prices acceptable to our customers. Further, we may face competitive pressure to develop, implement, or acquire certain new technologies at a substantial cost. Although we take measures to ensure that we use advanced technologies, changes in technology or improvements in our competitors’ equipment could make our equipment less competitive or require significant capital investments to keep our equipment competitive.

Our long-term success depends, in part, on our ability to effectively address changing customer demands, as well as government regulation and required disclosure regarding ESG. These demands and regulations include, but are not limited to, the creation of ESG-related policies and procedures, the quantification of our greenhouse gas emissions and evaluation of risk and opportunities. These customer preferences and government requirements could cause us to continue to adapt our equipment and technology offerings, as well as increase internal costs to address changes in ESG requirements. If ESG-related requirements change faster than anticipated or in a manner we do not anticipate, demand for our services could be adversely affected.

Some of our competitors are large national and multinational companies that may be able to devote greater financial, technical, manufacturing, and marketing resources to research and development of new systems, services, and technologies and may have a larger number of manufacturers for their products or ability to manufacture their own products. As competitors and others use or develop new or comparable technologies in the future, we may lose market share or be placed at a competitive disadvantage if we are not able to develop and implement new technologies or products on a timely basis or at an acceptable cost. If we are unable to compete effectively given these risks, our business and results of operations could be affected.

We rely on a limited number of manufacturers to produce the proprietary products used in the provision of our services, which exposes us to risks.

We currently rely on a limited number of manufacturers for production of the proprietary products used in the provision of our products and services. Termination of the manufacturing relationship with any of these manufacturers could affect our ability to provide such products and services to our customers. Although we believe other alternate sources of supply for our proprietary products exist, we would need to establish relationships with new manufacturers, which could potentially involve significant expense, delay, and potential changes to certain product components. Any protracted curtailment or interruptions of the supply of any of our key products, whether or not as a result of termination of our manufacturing relationships or patent infringement claims, could have a material adverse effect on our financial condition, business, and results of operations.

Our operations are subject to cybersecurity risks that could have a material adverse effect on our results of operations and financial condition.

The efficient operation of our business is dependent on our information technology (“IT”) systems. Accordingly, we rely upon the capacity, reliability, and security of our IT hardware and software infrastructure and our ability to expand and update this infrastructure in response to our changing needs. Our IT systems are subject to possible breaches and other threats that could cause us harm. If our systems for protecting against cybersecurity risks prove not to be sufficient, we could be adversely affected by, among other things, loss or damage of intellectual property, proprietary information, customer or business data; interruption of business operations; or additional costs to prevent, respond to, or mitigate cybersecurity attacks. These risks could have a material adverse effect on our business, financial condition, and results of operations and could lead to litigation or regulatory action against us.

Risks Related to Certain Significant Stockholders

Significant ownership of our common stock by certain stockholders could adversely affect our other stockholders.

SCF VII, L.P. and SCF-VII(A), L.P. (collectively, “SCF”) owned approximately 26% of our outstanding common stock as of December 31, 2023. In addition, certain of our directors are currently employed by SCF. Consequently, SCF is able to strongly influence all matters that require approval by our stockholders, including the election and removal of directors, changes to our organizational documents, and approval of acquisition offers and other significant corporate transactions. In addition, another one of our stockholders beneficially owned approximately 8% of our outstanding common stock as of December 31, 2023. This concentration of ownership by a small group of stockholders will limit other stockholders’ ability to influence corporate matters, and as a result, actions may be taken that other stockholders may not view as beneficial. For example, this concentration of ownership could have the effect of delaying or preventing a change in control or otherwise discouraging a potential acquirer from attempting to obtain control of us, which in turn could cause the market price of our common stock to decline or prevent our stockholders from realizing a premium over the market price for their shares of our common stock. This concentration of stock ownership may also adversely affect the trading price of our common stock to the extent investors perceive a disadvantage in owning stock of a company with significant stockholders.

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

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

Certain of our directors may have conflicts of interest because they are also affiliates of SCF. The resolution of these conflicts of interest may not be in our or other stockholders’ best interests.

Andrew L. Waite, one of our directors, is currently an officer of SCF’s ultimate general partner. In addition, Mr. Waite is a director of National Energy Reunited Corp., a corporation in which SCF owns an approximate 9% equity interest as of December 31, 2023. These positions may conflict with such individuals’ duties as one of our directors regarding business dealings and other matters between SCF and us. The resolution of these conflicts may not always be in our or our other stockholders’ best interest.

SCF and its affiliates are not limited in their ability to compete with us, and the corporate opportunity provisions in our charter could enable SCF to benefit from corporate opportunities that may otherwise be available to us.

SCF and its affiliates have investments in other oilfield service companies that may compete with us, and SCF and its affiliates may invest in such other companies in the future. SCF, its other affiliates, and its other portfolio companies are referred to herein as the “SCF Group.” Conflicts of interest could arise in the future between us, on the one hand, and the SCF Group, on the other hand, concerning among other things, potential competitive business activities or business opportunities.

Our charter provides that, to the fullest extent permitted by applicable law, we renounce any interest or expectancy in any business opportunity that involves any aspect of the energy equipment or services business or industry and that may be from time to time presented to SCF or any of our directors or officers who is also an employee, partner, member, manager, officer, or director of any SCF Group entity, even if the opportunity is one that we might reasonably have pursued or had the ability or desire to pursue if granted the opportunity to do so. Our charter further provides that no such person or party shall be liable to us by reason of the fact that such person pursues any such business opportunity or fails to offer any such business opportunity to us. As a result, any of our directors or officers who is also an employee, partner, member, manager, officer, or director of any SCF Group entity may become aware, from time to time, of certain business opportunities, such as acquisition opportunities, and may direct such opportunities to other businesses in which they have invested, in which case we may not become aware of or otherwise have the ability to pursue such opportunity. Further, such businesses may choose to compete with us for these opportunities. As a result, by renouncing our interest and expectancy in any business opportunity that may be from time to time presented to any member of an SCF Group entity or any of our directors or officers who is also an employee, partner, member, manager, officer, or director of any SCF Group entity, our business or prospects could be adversely affected if attractive business opportunities are procured by such parties for their own benefit rather than for ours. Our charter provides that any amendment to or adoption of any provision inconsistent with our charter’s provisions governing the renouncement of business opportunities must be approved by the holders of at least 80% of the voting power of the outstanding stock of the corporation entitled to vote thereon. Any actual or perceived conflicts of interest with respect to the foregoing could have an

adverse impact on the trading price of our common stock.

Risks Related to Human Capital

Our executive officers and certain key personnel are critical to our business, and these officers and key personnel may not remain with us in the future.

Our future success depends in substantial part on our ability to hire and retain our executive officers and other key personnel. In particular, we are highly dependent on certain of our executive officers, particularly our President and Chief Executive Officer, Ann G. Fox, and the Chief Operating Officer, David Crombie. These individuals possess extensive expertise, talent, and leadership, and they are critical to our success. The diminution or loss of the services of these individuals, or other integral key personnel affiliated with entities that we acquire in the future, could have a material adverse effect on our business. Furthermore, we may not be able to enforce all of the provisions in any employment agreement we have entered into with certain of our executive officers, and such employment agreements may not otherwise be effective in retaining such individuals. In addition, we may not be able to retain key employees of entities that we acquire in the future, which may impact our ability to successfully integrate or operate the assets we acquire.

We may be unable to employ, or maintain the employment of, a sufficient number of key employees, technical personnel, and other skilled and qualified workers.

The delivery of our services and products requires personnel with specialized skills and experience, including personnel who can perform physically demanding work, and our success depends, in large part, upon our ability to employ and retain key employees, technical personnel, and other skilled and qualified workers. To attract and retain qualified employees, we must compensate them at market levels. If we are unable to continue to attract and retain qualified employees, or do so at rates necessary to maintain our liquidity and competitive position, our business, financial condition, or results of operations could suffer. Workers may choose to pursue employment with our competitors or in fields that offer a more desirable work environment as a result of the volatility in the oilfield service industry and the demanding nature of our work. There has been a reduction of the available skilled labor force to service the energy industry. To the extent that there is an increase in demand for our products or services, there is no assurance that the availability of skilled labor will improve. If we are unable to employ and retain skilled workers, our capacity and profitability could be diminished, and our growth potential could be impaired.

Other Material Risks

We do not intend to pay dividends on our common stock, and our debt agreements place restrictions on our ability to do so. Consequently, a stockholder’s only opportunity to achieve a return on his investment is if the price of our common stock appreciates.

We do not plan to declare dividends on shares of our common stock in the foreseeable future. Additionally, our debt agreements place restrictions on our ability to pay cash dividends. Consequently, currently, a stockholder’s only opportunity to achieve a return on his investment in us will be by selling his common stock at a price greater than the stockholder paid for it. There is no guarantee that the price of our common stock that will prevail in the market will ever exceed the price at which a stockholder purchased his shares of our common stock.

The market price of our common stock could be adversely affected by, and our stockholders may experience dilution as a result of, sales of substantial amounts of common stock in the public or private markets, including sales by the Company or other large holders.

The sale of a substantial number of shares of our common stock by the Company or a holder of a substantial number of shares of our common stock in the public markets could have a material adverse effect on the price of our common stock and dilute our stockholders. In November 2023, we entered an equity distribution agreement (the “Equity Distribution Agreement”) with Piper Sandler & Co. (the “Agent”). Pursuant to the Equity Distribution Agreement, we may, from time to time, sell, shares of our common stock having an aggregate offering price of up to $30.0 million through the Agent acting as the Company’s sales agent (the “ATM Program”). Under the Equity Distribution Agreement, we will set the parameters for the sale of the shares thereunder, including the number of shares to be sold, the time period during which sales are requested to be made and any price below which sales may not be made. Subject to the terms and conditions of the Equity Distribution Agreement and such parameters, the Agent may sell the shares by any method deemed to be an “at the market offering” as defined by Rule 415 under the Securities Act of 1933, as amended (the “Securities Act”), including sales made directly on or through the New York Stock Exchange. The Agent may also sell shares in negotiated transactions at market prices prevailing at the time of sale or at prices related to such prevailing market prices and/or any other method permitted by law, subject to our prior written consent.

In addition to any shares issued through the ATM Program, we may issue shares of our common stock or equity securities senior to our common stock in the future for a number of reasons, including to finance our operations and growth plans or to adjust our ratio of debt-to-equity. We cannot predict the size of future issuances or sales of our common stock or the effect, if any, that future issuances and sales of shares of our common stock could have on the market price of our common stock.

We have operated at a loss in the past, and there is no assurance of our profitability in the future.

We have in the past experienced periods of low demand for our products and services and have incurred operating losses. In the future, we may not be able to reduce our costs, increase our revenues, or reduce our debt service obligations sufficiently to achieve or maintain profitability and generate positive operating income. Under such circumstances, we may incur operating losses and experience negative operating cash flow.

Our future financial condition and results of operations could be adversely impacted by long-lived assets or other asset impairment charges.

Determining whether an impairment exists and the amount of the potential impairment involves quantitative data and qualitative criteria that are based on estimates and assumptions requiring significant management judgment, such as those relating to revenue growth rates, future cash flows, and future market conditions. Future events or new information, including regarding the general economic environment, E&P activity levels, our financial performance and trends, and our strategies and business plans, may change management’s valuation of long-lived assets, other intangible assets, or other assets in a short amount of time. In particular, prolonged periods of decreased demand, low utilization, changes in technology or market conditions, or sales and other dispositions of assets for amounts less than their carrying value may cause us to recognize impairment charges relating to our long-lived assets, other intangible assets, or other assets that reduce our net income.

While we believe our estimates and assumptions used in impairment tests are reasonable, we cannot provide assurance that additional impairment charges in the future will not be required, especially if an economic downturn occurs and continues for a lengthy period or becomes severe or if our acquisitions and investments fail to achieve expected returns. Significant impairment charges as a result of a decline in market conditions or otherwise could have a material adverse effect on our financial condition or results of operations in future periods.

A terrorist attack or armed conflict could harm our business.

The occurrence or threat of terrorist attacks in the U.S. or other countries, anti-terrorist efforts, and other armed conflicts involving the U.S. or other countries, including continued hostilities in the Middle East, may adversely affect the U.S. and global economies and could prevent us from meeting financial and other obligations. We could experience loss of business, delays or defaults in payments from payors, or disruptions of fuel supplies and markets if wells, operations sites, or other related facilities are direct targets or indirect casualties of an act of terror or war. Such activities could reduce the overall demand for oil and natural gas, which, in turn, could also reduce the demand for our products and services. Oil and natural gas-related facilities could be direct targets of terrorist attacks, and our operations could be adversely impacted if infrastructure integral to our customers’ operations is destroyed or damaged. Costs for insurance and other security may increase as a result of these threats, and some insurance coverage may become more difficult to obtain, if available at all. Terrorist activities and the threat of potential terrorist activities and any resulting economic downturn could adversely affect our results of operations, impair our ability to raise capital, or otherwise adversely impact our ability to realize certain business strategies.

A portion of our revenue is derived from sales to customers outside of the U.S., which exposes us to risks inherent in doing business internationally.

In 2023, we derived 4.7% of our revenue from sales to customers outside of the U.S. Sales to customers in countries other than the U.S. are subject to various risks, including:

•volatility in political, social, and economic conditions;

•social unrest, acts of terrorism, war, or other armed conflicts;

•confiscatory taxation or other adverse tax policies;

•deprivation of contract rights;

•trade and economic sanctions or other restrictions imposed by the European Union, the U.S., or other countries;

•exposure under the FCPA or similar legislation, as discussed in the below risk factor; and

•currency exchange controls.

Our charter and bylaws contain provisions that could delay, discourage, or prevent a takeover attempt even if a takeover might be beneficial to our stockholders, and such provisions may adversely affect the market price of our common stock.

Provisions contained in our charter and bylaws could make it more difficult for a third party to acquire us. Our charter and bylaws also impose various procedural and other requirements, which could make it more difficult for stockholders to effect certain corporate actions. For example, our charter authorizes our board of directors to determine the rights, preferences, privileges, and restrictions of unissued series of preferred stock without any vote or action by our stockholders. Thus, our board of directors can authorize and issue shares of preferred stock with voting or conversion rights that could adversely affect the voting or other rights of holders of our capital stock. These rights may have the effect of delaying or deterring a change of control of our company. Additionally, for example, our bylaws (i) establish limitations on the removal of directors and on the ability of our stockholders to call special meetings, (ii) include advance notice requirements for nominations for election to our board of directors and for proposing matters that can be acted upon at stockholder meetings, (iii) provide that our board of directors is expressly authorized to adopt, or to alter or repeal, our bylaws, and (iv) provide for a classified board of directors, consisting of three classes of approximately equal size, each class serving staggered three-year terms, so that only approximately one-third of our directors will be elected each year. These provisions could limit the price that certain investors might be willing to pay in the future for shares of our common stock.

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

Our charter and bylaws provide that, unless we consent in writing to the selection of an alternative forum, the Court of Chancery of the State of Delaware will, to the fullest extent permitted by applicable law, be the sole and exclusive forum for (i) any derivative action or proceeding brought on our behalf, (ii) any action asserting a claim of breach of a fiduciary duty owed by any of our directors, officers, employees, or agents to us or our stockholders, (iii) any action asserting a claim arising pursuant to any provision of the Delaware General Corporation Law (the “DGCL”), our charter or our bylaws, or (iv) any action asserting a claim against us that is governed by the internal affairs doctrine, in each such case subject to such Court of Chancery having personal jurisdiction over the indispensable parties named as defendants therein. These exclusive forum provisions are not intended to apply to actions arising under the Exchange Act or the Securities Act. The Court of Chancery of the State of Delaware has recently held that a Delaware corporation can only use its constitutive documents to bind a plaintiff to a particular forum where the claim involves rights or relationships that were established by or under the DGCL.

Any person or entity purchasing or otherwise acquiring any interest in shares of our capital stock will be deemed to have notice of, and consented to, the forum selection provisions of our charter and bylaws. These choice of forum provisions may limit a stockholder’s ability to bring a claim in a judicial forum that it finds favorable for disputes with us or our directors, officers, employees, or agents, which may discourage such lawsuits against us and such persons. Alternatively, if a court were to find these provisions of our charter or bylaws inapplicable to, or unenforceable in respect of, one or more of the specified types of actions or proceedings, we may incur additional costs associated with resolving such matters in other jurisdictions, which could adversely affect our business, financial condition, or results of operations.

We may not be able to utilize a portion of our net operating loss carry forwards (“NOLs”) to offset future taxable income for U.S. federal or state tax purposes, which could adversely affect our net income and cash flows.

As of December 31, 2023, we had federal and state income tax NOLs of approximately $471.8 million, which will begin to expire between 2024 and 2034. Utilization of these NOLs depends on many factors, including our future taxable income, which cannot be assured. In addition, Section 382 of the Internal Revenue Code of 1986, as amended (“Section 382”), generally imposes an annual limitation on the amount of an NOL that may be used to offset taxable income when a corporation has undergone an “ownership change” (as determined under Section 382). Determining the limitations under Section 382 is technical and highly complex. An ownership change generally occurs if one or more shareholders (or groups of shareholders) who are each deemed to own at least 5% of the corporation’s stock increase their ownership by more than 50 percentage points over their lowest ownership percentage within a rolling three-year period. In the event that an ownership change has occurred, or were to occur, with respect to a corporation following its recognition of an NOL, utilization of such NOL would be subject to an annual limitation under Section 382, generally determined by multiplying the value of the corporation’s stock at the time of the ownership change by the applicable long-term tax-exempt rate as defined in Section 382. However, this annual limitation would be increased under certain circumstances by recognized built-in gains of the corporation existing at the time of the ownership change. In the case of an NOL that arose in a taxable year beginning before January 1, 2018, any unused annual

limitation with respect to an NOL generally may be carried over to later years, subject to the expiration of such NOL 20 years after it arose.

The issuance of additional stock in our initial public offering in 2018, combined with ownership shifts over the rolling three-year period, resulted in an ownership change under Section 382, and we may be prevented from fully utilizing our NOLs prior to their expiration. Future changes in our stock ownership or future regulatory changes could also limit our ability to utilize our NOLs. To the extent we are not able to offset future taxable income with our NOLs, our net income and cash flows may be adversely affected.

Item 1B. Unresolved Staff Comments

None.

Item 1C. Cybersecurity

Risk Management and Strategy

Identifying, assessing, and managing cybersecurity risks is an important component of our overall enterprise risk management program. Our cybersecurity programs have been developed based on the National Institute of Standards and Technology Cybersecurity Framework and seek to protect the Company against cybersecurity risks. Among other things, these programs generally involve maturity evaluations and assessments by third parties, vulnerability scanning, employee testing and training, technical and business team-focused tabletop exercises, business continuity planning, incident response planning and data security assessments of third-party service providers as a part of vendor management.

Identified Risks

As of the date of this Annual Report, we are not aware of any cybersecurity threats that have materially affected or are reasonably likely to materially affect us, including our business strategy, results of operations, or financial condition. However, we face certain ongoing risks from cybersecurity threats that, if realized, may, among other things, cause material disruptions to our operations, which may materially affect us, including our business strategy, results of operations and/or financial condition. For more information about these risks, see the risk factor titled “Our operations are subject to cybersecurity risks that could have a material adverse effect on our results of operations and financial condition” under Item 1A of Part I of this Annual Report.

Board Oversight and Management’s Role

Our Board considers cybersecurity risk as part of its risk oversight function and has assigned oversight of cybersecurity risk management to the Audit Committee. The Audit Committee regularly receives reports from our management, including the SC (defined below) and our senior IT leadership, and third parties on cybersecurity matters. The Audit Committee reports to the full Board regarding its activities, including those related to cybersecurity. In addition, the Board receives reports addressing cybersecurity as part of our overall enterprise risk management program and to the extent cybersecurity matters are addressed therein, in regular business updates.

We have established a Security Committee (the “SC”), comprised of senior departmental leadership including our Chief Financial Officer, Senior Vice President and General Counsel, Vice President – IT, Vice President – Internal Audit, and Vice President – Corporate Operations, each of whom has between 10 to 20 years of experience managing risks at the Company and at similar companies, including risks arising from cybersecurity threats. The SC meets quarterly to discuss and review cybersecurity concerns that arise during the year. The SC also identifies areas that should be addressed and reviews and updates security policies, as necessary. The SC has primary management oversight responsibility for assessing and managing risks from cybersecurity threats.

Our senior IT leadership is responsible for the day-to-day management and development of appropriate cybersecurity programs, including as may be required by applicable law or regulation. Our senior IT leadership monitors the prevention, detection, mitigation, and remediation of cybersecurity incidents as part of the cybersecurity programs described above, works closely with the SC, and reports regular updates to the Audit Committee. Our IT team is led by our Vice President – IT, who has over 12 years of experience managing global IT operations, including strategy, applications, infrastructure, information security, support, and execution.

Item 2. Properties

The following table describes the material facilities owned or leased by us as of December 31, 2023.

Location

Basin/Region

Leased or Owned

Principal/Most Significant Use

Houston, TX

—

Leased

Corporate Headquarters/Administrative

Athens, TX

—

Leased

Operations

Baker, MT

Bakken

Owned

Operations/Administrative

Bergen, Norway

—

Leased

Operations

Charleroi, PA

Marcellus/Utica

Leased

Operations

Corpus Christi, TX

—

Leased

Operations/Administrative

Corpus Christi, TX

—

Leased

Administrative

Dickinson, ND

Bakken

Leased

Operations/Administrative

El Reno, OK

SCOOP/STACK

Leased

Operations

Fort Worth, TX

—

Leased

Administrative

Hobbs, NM

Permian

Leased

Operations

Jacksboro, TX

Barnett

Leased

Operations

Jacksboro, TX

Barnett

Leased

Operations

Kilgore, TX

Haynesville

Leased

Operations

Lacombe, AB, Canada

WCSB

Leased

Operations/Administrative

Longview, TX

Haynesville

Owned

Operations

Marietta, OH

Marcellus/Utica

Leased

Operations/Administrative

Mead, CO

Rockies

Leased

Operations

Midland, TX

Permian

Leased

Operations/Administrative

Monahans, TX

Permian

Leased

Operations/Administrative

Oklahoma City, OK

SCOOP/STACK

Leased

Operations

Pleasanton, TX

Eagle Ford

Leased

Operations

Poolville, TX

—

Owned

Operations

Sweetwater, TX

Permian

Leased

Operations

Tyler, TX

Haynesville

Leased

Operations

Ulster, PA

Marcellus/Utica

Leased

Operations

Williston, ND

Bakken

Owned

Operations/Administrative

Item 3. Legal Proceedings

From time to time, we have various claims, lawsuits, and administrative proceedings that are pending or threatened with respect to personal injury, workers’ compensation, contractual matters, and other matters. Although no assurance can be given with respect to the outcome of these claims, lawsuits, or proceedings or the effect such outcomes may have, we believe any ultimate liability resulting from the outcome of such claims, lawsuits, or administrative proceedings, to the extent not otherwise provided for or covered by insurance, will not have a material adverse effect on our business, operating results, or financial condition. For additional information related to legal proceedings, see Note 12 – Commitments and Contingencies included in Item 8 of Part II of this Annual Report.

Item 4. Mine Safety Disclosures

Not applicable.

PART II

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

Market Information

Nine Energy Service, Inc.’s common stock is traded on the New York Stock Exchange under the symbol “NINE.”

Holders

As of March 4, 2024, we had 59 stockholders of record. The number of record holders does not include persons who held shares of our common stock in nominee or “street name” accounts through brokers.

Dividend Policy

We do not anticipate declaring or paying any cash dividends to holders of our common stock in the foreseeable future. We currently intend to retain future earnings, if any, to fund our operations and to develop and grow our business. Our future dividend policy is within the discretion of our board of directors and will depend upon various factors our board of directors deems relevant, including our results of operations, financial condition, capital requirements, and investment opportunities, as well as any restrictions on our ability to pay cash dividends.

Recent Sales of Unregistered Securities

None.

Purchases of Equity Securities by the Issuer and Affiliated Purchasers

None.

Item 6. [Reserved]

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

The following discussion and analysis of our financial condition and results of operations should be read in conjunction with “Financial Statements and Supplementary Data” in Item 8 of Part II of this Annual Report.

This discussion contains forward-looking statements based on our current expectations, estimates, and projections about our operations and the industry in which we operate. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of a variety of risks and uncertainties, including those described under “Risk Factors” in Item 1A of Part I of this Annual Report. We assume no obligation to update any of these forward-looking statements.

Overview

Company Description

We are a leading North American onshore completion services provider that targets unconventional oil and gas resource development. We partner with our E&P customers across all major onshore basins in both the U.S. and Canada as well as abroad to design and deploy downhole solutions and technology to prepare horizontal, multistage wells for production. We focus on providing our customers with cost-effective and comprehensive completion solutions designed to maximize their production levels and operating efficiencies.

Generally, operators have continued to improve operational efficiencies in completions design, increasing the complexity and difficulty, making oilfield service selection more important. This increase in high-intensity, high-efficiency completions of oil and gas wells further enhances the demand for our services. We compete for the most complex and technically demanding wells in which we specialize, which are characterized by extended laterals, increased stage spacing, multi-well pads, cluster spacing, and high proppant loads. These well characteristics lead to increased operating leverage and returns for us, as we are able to complete more jobs and stages with the same number of units and crews. Service providers for these projects are selected based on their technical expertise and ability to execute safely and efficiently.

We provide (i) cementing services, which consist of blending high-grade cement and water with various solid and liquid additives to create a cement slurry that is pumped between the casing and the wellbore of the well, (ii) an innovative portfolio of completion tools, including those that provide pinpoint frac sleeve system technologies as well as a portfolio of completion technologies used for completing the toe stage of a horizontal well and fully-composite, dissolvable, and extended range frac plugs to isolate stages during plug-and-perf operations, (iii) wireline services, the majority of which consist of plug-and-perf completions, which is a multistage well completion technique for cased-hole wells that consists of deploying perforating guns and isolation tools to a specified depth, and (iv) coiled tubing services, which perform wellbore intervention operations utilizing a continuous steel pipe that is transported to the wellsite wound on a large spool in lengths of up to 30,000 feet and which provides a cost-effective solution for well work due to the ability to deploy efficiently and safely into a live well.

We believe our success is a product of our culture, which is driven by our intense focus on performance and wellsite execution as well as our commitment to forward-leaning technologies that aid us in the development of smarter, customized applications that drive efficiencies.

How We Generate Revenue and the Costs of Conducting Our Business

We generate our revenues by providing completion services to E&P customers across all major onshore basins in both the U.S. and Canada as well as abroad. We primarily earn our revenues pursuant to work orders entered into with our customers on a job-by-job basis. We typically will enter into an MSA with each customer that provides a framework of general terms and conditions of our services that will govern any future transactions or jobs awarded to us. Each specific job is obtained through competitive bidding or as a result of negotiations with customers. The rate we charge is determined by location, complexity of the job, operating conditions, duration of the contract, and market conditions. In addition to MSAs, we have entered into a select number of longer-term contracts with certain customers relating to our wireline and cementing services, and we may enter into similar contracts from time to time to the extent beneficial to the operation of our business. These longer-term contracts address pricing and other details concerning our services, but each job is performed on a standalone basis.

The principal expenses involved in conducting our business include labor costs, materials and freight, the costs of maintaining our equipment, and fuel costs. Our direct labor costs vary with the amount of equipment deployed and the utilization of that equipment. Another key component of labor costs relates to the ongoing training of our field service employees, which improves safety rates and reduces employee attrition.

How We Evaluate Our Operations

We evaluate our performance based on a number of financial and non-financial measures, including the following:

•Revenue: We compare actual revenue achieved each month to the most recent projection for that month and to the annual plan for the month established at the beginning of the year. We monitor our revenue to analyze trends in the performance of our operations compared to historical revenue drivers or market metrics. We are particularly interested in identifying positive or negative trends and investigating to understand the root causes.

•Adjusted Gross Profit (Loss): Adjusted gross profit (loss) is a key metric that we use to evaluate operating performance. We define adjusted gross profit (loss) as revenues less direct and indirect costs of revenues (excluding depreciation and amortization). Costs of revenues include direct and indirect labor costs, costs of materials, maintenance of equipment, fuel and transportation freight costs, contract services, crew cost, and other miscellaneous expenses. For additional information, see “Non-GAAP Financial Measures” below.

•Adjusted EBITDA: We define Adjusted EBITDA as EBITDA (which is net income (loss) before interest, taxes, and depreciation and amortization) further adjusted for (i) goodwill, intangible asset, and/or property and equipment impairment charges, (ii) transaction and integration costs related to acquisitions, (iii) fees and expenses relating to our Units (as defined and described below) offering and other refinancing activities, (iv) loss or gain on revaluation of contingent liabilities, (v) loss or gain on the extinguishment of debt, (vi) loss or gain on the sale of subsidiaries, (vii) restructuring charges, (viii) stock-based compensation and cash award expense, (ix) loss or gain on sale of property and equipment, and (x) other expenses or charges to exclude certain items which we believe are not reflective of ongoing performance of our business, such as legal expenses and settlement costs related to litigation outside the ordinary course of business. For additional information, see “Non-GAAP Financial Measures” below.

•Adjusted Return on Invested Capital (“Adjusted ROIC”): We define Adjusted ROIC as adjusted after-tax net operating profit (loss), divided by average total capital. We define adjusted after-tax net operating profit (loss) as net income (loss) plus (i) goodwill, intangible asset, and/or property and equipment impairment charges, (ii) transaction and integration costs related to acquisitions, (iii) fees and expenses relating to our Units offering and other refinancing activities,(iv) interest expense (income), (v) restructuring charges, (vi) loss (gain) on the sale of subsidiaries, (vii) loss (gain) on the extinguishment of debt, and (viii) the provision (benefit) for deferred income taxes. We define total capital as book value of equity plus the book value of debt less balance sheet cash and cash equivalents. We compute and use the average of the current and prior period-end total capital in determining Adjusted ROIC. Previously, in our SEC filings press releases and other investor materials issued prior to December 31, 2023, we referred to (a) Adjusted ROIC as ROIC and (b) adjusted after-tax net operating profit (loss) as after-tax net operating profit (loss). We have made no changes to the manner in which these measures are calculated and have only revised the titles of these measures to more clearly identify them as non-GAAP measures. For additional information, see “Non-GAAP Financial Measures” below.

•Safety: We measure safety by tracking the total recordable incident rate (“TRIR”), which is reviewed on a monthly basis. TRIR is a measure of the rate of recordable workplace injuries, defined below, normalized and stated on the basis of 100 workers for an annual period. The factor is derived by multiplying the number of recordable injuries in a calendar year by 200,000 (i.e., the total hours for 100 employees working 2,000 hours per year) and dividing this value by the total hours actually worked in the year. A recordable injury includes occupational death, nonfatal occupational illness, and other occupational injuries that involve loss of consciousness, restriction of work or motion, transfer to another job, or medical treatment other than first aid.

Industry Trends and Outlook

Our business depends, to a significant extent, on the level of unconventional resource development activity and corresponding capital spending of oil and natural gas companies. These activity and spending levels are strongly influenced by current and expected oil and natural gas prices. In recent years, oil and natural gas prices have been extremely volatile, and commodity prices continued to be volatile in 2023, with both oil and natural gas prices significantly lower than 2022, leading to lower activity levels, particularly in the natural gas regions. The average WTI price in 2023 declined by approximately 18% versus 2022, and the average natural gas price declined by approximately 61% over that same time period. Since the end of 2022, the U.S. rig count declined by 157 rigs, or approximately 20%, through the end of 2023. With the decline in commodity

prices and overall activity levels in 2023, we received pricing pressure from customers across service lines and basins, impacting both our revenue and margins.

For 2024, most public operators appear to be keeping activity and capital expenditure levels relatively flat year over year, and with where commodity prices are today, private operators are not likely to increase activity. As such, although the market can change quickly, we do not foresee any activity increases in the near-term, and thus far in 2024, we have experienced activity levels and pricing that is generally consistent with that of the last quarter of 2023.

We remain cautiously optimistic on the long-term outlook for the energy sector, and we believe there is potential upside for North American activity levels. OPEC has maintained production cuts, and public U.S. producers remaining committed to capital discipline, rather than increasing drilling, could help lessen the impact of any supply surplus. Additionally, the conflicts between Russia and Ukraine and in the Middle East provide increased uncertainty regarding global supply.

Significant factors that are likely to affect commodity prices moving forward include actions of the members of OPEC and other oil exporting nations that relate to or impact oil production or supply; the effect of energy, monetary, and trade policies of the U.S.; the pace of economic growth in the U.S. and throughout the world, including the potential for macro weakness; geopolitical and economic developments in the U.S. and globally, including conflicts, instability, acts of war or terrorism in oil producing countries or regions, particularly Russia, the Middle East, South America and Africa; changes to energy regulations and policies, including those of the EPA and other governmental bodies; and overall North American oil and natural gas supply and demand fundamentals, including the pace at which export capacity grows. Furthermore, although as noted above, our customers’ activity and spending levels, and thus demand for our services and products, are strongly influenced by current and expected oil and natural gas prices, even with price improvements in oil and natural gas, operator activity may not materially increase, as operators remain focused on operating within their capital plans, and uncertainty remains around supply and demand fundamentals.

Results of Operations


	Year Ended December 31,
	2023		2022		Change		Percentage Change
	(in thousands, except percentage change)
Revenues	$	609,526	$	593,382	$	16,144	3	%
Cost of revenues (exclusive of depreciation and amortization shown separately below)	490,750		457,093		33,657		7	%
Adjusted gross profit	$	118,776	$	136,289	$	(17,513)	(13)	%

General and administrative expenses	$	59,817	$	51,653	$	8,164	16	%
Depreciation	29,141		26,784		2,357		9	%
Amortization of intangibles	11,516		13,463		(1,947)		(14)	%
Loss on revaluation of contingent liability	437		454		(17)		(4)	%
Loss on sale of property and equipment	292		367		(75)		(20)	%
Income from operations	17,573		43,568		(25,995)		(60)	%
Non-operating expenses	49,201		28,629		20,572		72	%
Income (loss) before income taxes	(31,628)		14,939		(46,567)		(312)	%
Provision for income taxes	585		546		39		7	%
Net income (loss)	$	(32,213)	$	14,393	$	(46,606)	(324)	%

Revenues

Revenues increased $16.1 million, or 3%, to $609.5 million in 2023; while the average U.S. rig count remained relatively flat in comparison to 2022, the overall increase in revenues was attributable to a number of factors, including increased activity and changes in product mix. More specifically, wireline revenue increased $9.6 million, or 9%, due to increased activity, as total completed wireline stages increased 4%. In addition, although completion tools stages decreased 6% in comparison to 2022, tools revenue increased $7.2 million, or 5%, due to a significant international sale made to a customer during 2023 that did not occur in 2022, as well as a change in product mix between periods. Coiled tubing revenue also increased $4.0 million, or 3%, due to increased activity, as total days worked increased by 3%. The overall increase was

partially offset with a decrease in cementing revenue (including pump downs) of $4.7 million, or 2%, due to an 11% decrease in total jobs in comparison to 2022.

Cost of Revenues (Exclusive of Depreciation and Amortization)

Cost of revenues increased $33.7 million, or 7%, to $490.8 million in 2023. The increase in comparison to 2022 was primarily driven by increased activity in wireline and coiled tubing, coupled with cost inflation over all lines of service associated with both labor and materials. More specifically, the increase was due to a $16.3 million increase in employee related costs, a $13.8 million increase in materials installed and consumed while performing services, a $3.1 million increase in repairs and maintenance, and a $0.5 million increase in other costs such as vehicle expense and travel, in comparison to 2022.

Adjusted Gross Profit (Loss)

Adjusted gross profit decreased $17.5 million to $118.8 million in 2023 as a result of the factors described above under “Revenues” and “Cost of Revenues.”

General and Administrative Expenses

General and administrative expenses increased $8.2 million to $59.8 million in 2023. The increase was primarily due to $6.4 million in costs associated with the Units offering in 2023 that did not occur in 2022. The increase was also partially attributed to a $1.7 million increase in marketing and communication costs in comparison to 2022.

Depreciation

Depreciation expense increased $2.4 million to $29.1 million in 2023. The increase in comparison to 2022 was primarily due to an increase in capital expenditures over the last two years.

Amortization of Intangibles

Amortization of intangibles, which was primarily comprised of technology and customer relationships, decreased $1.9 million to $11.5 million in 2023. The decrease in comparison to 2022 was due to certain intangible assets being fully amortized over the last twelve months.

(Gain) Loss on Revaluation of Contingent Liability

We recorded a $0.4 million loss on the revaluation of contingent liability in 2023 compared to a $0.5 million loss in 2022. The losses for both periods were related to increases of the value of the earnout associated with our acquisition Frac Technology AS.

(Gain) Loss on Sale of Property and Equipment

We recorded a loss on sale of property and equipment of $0.3 million in 2023 compared to a loss on sale of property and equipment of $0.4 million in 2022. The $0.1 million change was primarily attributed to an increase in certain damaged equipment that was fully disposed of in 2022 in comparison to 2023.

Non-Operating Expenses (Income)

Non-operating expenses increased $20.6 million to $49.2 million in 2023. The increase in comparison to 2022 was primarily due to an increased interest rate on our senior notes (from 8.750% on the 2023 Notes (as defined and described below) to 13.000% on the 2028 Notes). The increase was also partially due to a $2.8 million gain on the extinguishment of debt related to the repurchase of our 2023 Notes in 2022 that did not recur in 2023.

Provision (Benefit) for Income Taxes

Our effective tax rate was (1.8)% for 2023 and 3.7% for 2022. Our tax provision for 2023 is primarily the result of our tax position in state and foreign tax jurisdictions.

Adjusted EBITDA

Adjusted EBITDA decreased $20.8 million to $73.0 million for 2023. The Adjusted EBITDA decrease was primarily due to the changes in revenue and expenses discussed above. See “Non-GAAP Financial Measures” below for further explanation.

Non-GAAP Financial Measures

Adjusted EBITDA

Adjusted EBITDA is a non-GAAP financial measure that is used by management and external users of our financial statements, such as industry analysts, investors, lenders, and rating agencies.

We define Adjusted EBITDA as EBITDA (which is net income (loss) before interest, taxes, depreciation, and amortization) further adjusted for (i) goodwill, intangible asset, and/or property and equipment impairment charges, (ii) transaction and integration costs related to acquisitions, (iii) fees and expenses relating to our Units offering and other refinancing activities, (iv) loss or gain on revaluation of contingent liabilities, (v) loss or gain on the extinguishment of debt, (vi) loss or gain on the sale of subsidiaries, (vii) restructuring charges, (viii) stock-based compensation and cash award expense, (ix) loss or gain on sale of property and equipment, and (x) other expenses or charges to exclude certain items which we believe are not reflective of ongoing performance of our business, such as legal expenses and settlement costs related to litigation outside the ordinary course of business.

Management believes Adjusted EBITDA is useful because it allows us to more effectively evaluate our operating performance and compare the results of our operations from period to period without regard to our financing methods or capital structure and helps identify underlying trends in our operations that could otherwise be distorted by the effect of impairments, acquisitions and dispositions and costs that are not reflective of the ongoing performance of our business. We exclude the items listed above from net income (loss) in arriving at this measure because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures, and the method by which the assets were acquired. This measure should not be considered as an alternative to, or more meaningful than, net income (loss) as determined in accordance with accounting principles generally accepted in the United States of America (“GAAP”) or as an indicator of our operating performance. Certain items excluded from this measure are significant components in understanding and assessing a company’s financial performance, such as a company’s cost of capital and tax structure, as well as the historic costs of depreciable assets, none of which are components of this measure. Our computation of this measure may not be comparable to other similarly titled measures of other companies.

The following table presents a reconciliation of the non-GAAP financial measure of Adjusted EBITDA to the GAAP financial measure of net income (loss):


	Year Ended December 31,
	2023		2022
	(in thousands)
Net income (loss)	$	(32,213)	$	14,393
Interest expense	51,119		32,486
Interest income	(1,270)		(305)
Provision for income taxes	585		546
Depreciation	29,141		26,784
Amortization of intangibles	11,516		13,463
EBITDA	$	58,878	$	87,367
Adjusted EBITDA reconciliation:
EBITDA	$	58,878	$	87,367
Loss on revaluation of contingent liability (1)	437		454
Gain on extinguishment of debt	—		(2,843)
Certain refinancing costs (2)	6,396		—
Restructuring charges	2,027		3,393
Stock-based compensation and cash award expense	4,867		4,914
Loss on sale of property and equipment	292		367
Legal fees and settlements (3)	69		86
Adjusted EBITDA	$	72,966	$	93,738

(1) Amounts relate to the revaluation of contingent liability associated with a 2018 acquisition. The impact is included in our Consolidated Statements of Income and Comprehensive Income (Loss). For additional information on contingent liabilities, see Note 12 – Commitments and Contingencies included Item 8 of Part II of this Annual Report.

(2) Amounts represent fees and expenses relating to our Units offering and other refinancing activities, including cash incentive compensation to employees following the successful completion of the Units offering, that were not capitalized.

(3) Amounts represent fees and legal settlements associated with legal proceedings brought pursuant to the FLSA and/or similar state laws.

Adjusted Return on Invested Capital

Adjusted ROIC is a non-GAAP financial measure. We define Adjusted ROIC as adjusted after-tax net operating profit (loss), divided by average total capital. We define adjusted after-tax net operating profit (loss), which is a non-GAAP financial measure, as net income (loss) plus (i) goodwill, intangible asset, and/or property and equipment impairment charges, (ii) transaction and integration costs related to acquisitions, (iii) fees and expenses relating to our Units offering and other refinancing activities, (iv) interest expense (income), (v) restructuring charges, (vi) loss (gain) on the sale of subsidiaries, (vii) loss (gain) on the extinguishment of debt, and (viii) the provision (benefit) for deferred income taxes. We define total capital as book value of equity (deficit) plus the book value of debt less balance sheet cash and cash equivalents. We compute and use the average of the current and prior period-end total capital in determining Adjusted ROIC. Previously, in our SEC filings press releases and other investor materials issued prior to December 31, 2023, we referred to (a) Adjusted ROIC as ROIC and (b) adjusted after-tax net operating profit (loss) as after-tax net operating profit (loss). We have made no changes to the manner in which these measures are calculated and have only revised the titles of these measures to more clearly identify them as non-GAAP measures.

Management believes Adjusted ROIC is a meaningful measure because it quantifies how well we generate operating income relative to the capital we have invested in our business and illustrates the profitability of a business or project taking into account the capital invested. Management uses Adjusted ROIC to assist them in capital resource allocation decisions and in evaluating business performance. Although Adjusted ROIC is commonly used as a measure of capital efficiency, definitions of Adjusted ROIC differ, and our computation of Adjusted ROIC may not be comparable to other similarly titled measures of other companies.

The following table provides our calculation of Adjusted ROIC for the years ended December 31, 2023 and 2022. The following table also presents ROIC (defined as net income (loss), divided by average total capital) and a reconciliation of the non-GAAP financial measure of adjusted after-tax net operating profit (loss) to the most directly comparable GAAP measure of net income (loss), in each case for the years ended December 31, 2023 and 2022.


	Year Ended December 31,
	2023			2022
	(in thousands)
Net income (loss)	$	(32,213)		$	14,393
Add back:
Interest expense	51,119			32,486
Interest income	(1,270)			(305)
Certain refinancing costs (1)	6,396			—
Restructuring charges	2,027			3,393
Gain on extinguishment of debt	—			(2,843)
Adjusted after-tax net operating income	$	26,059		$	47,124
Total capital as of prior period-end:
Total stockholders’ deficit	$	(23,507)		$	(39,267)
Total debt	341,606			337,436
Less cash and cash equivalents	(17,445)			(21,509)
Total capital as of prior period-end	$	300,654		$	276,660
Total capital as of period-end:
Total stockholders’ deficit	$	(35,630)		$	(23,507)
Total debt	359,859			341,606
Less cash and cash equivalents	(30,840)			(17,445)
Total capital as of period-end	$	293,389		$	300,654
Average total capital	$	297,022		$	288,657

ROIC	(10.8)		%	5.0		%
Adjusted ROIC	8.8		%	16.3		%

(1) Amounts represent fees and expenses relating to our Units offering and other refinancing activities, including cash incentive compensation to employees following the successful completion of the Units offering, that were not capitalized.

Adjusted Gross Profit (Loss)

GAAP defines gross profit (loss) as revenues less cost of revenues and includes depreciation and amortization in costs of revenues. We define adjusted gross profit (loss) as revenues less direct and indirect costs of revenues (excluding depreciation and amortization). This measure differs from the GAAP definition of gross profit (loss) because we do not include the impact of depreciation and amortization, which represent non-cash expenses.

Management uses adjusted gross profit (loss) to evaluate operating performance. We prepare adjusted gross profit (loss) to eliminate the impact of depreciation and amortization because we do not consider depreciation and amortization indicative of our core operating performance. Adjusted gross profit (loss) should not be considered as an alternative to gross profit (loss), operating income (loss), or any other measure of financial performance calculated and presented in accordance with GAAP. Adjusted gross profit (loss) may not be comparable to similarly titled measures of other companies because other companies may not calculate adjusted gross profit (loss) or similarly titled measures in the same manner as we do.

The following table presents a reconciliation of adjusted gross profit (loss) to GAAP gross profit (loss).


	Year Ended December 31,
	2023		2022
	(in thousands)
Calculation of gross profit:
Revenues	$	609,526	$	593,382
Cost of revenues (exclusive of depreciation and amortization shown separately below)	490,750		457,093
Depreciation (related to cost of revenues)	27,101		24,909
Amortization of intangibles	11,516		13,463
Gross profit	$	80,159	$	97,917
Adjusted gross profit reconciliation:
Gross profit	$	80,159	$	97,917
Depreciation (related to cost of revenues)	27,101		24,909
Amortization of intangibles	11,516		13,463
Adjusted gross profit	$	118,776	$	136,289

Liquidity and Capital Resources

Sources and Uses of Liquidity

Historically, we have met our liquidity needs principally from cash on hand, cash flows from operations and, if needed, external borrowings and issuances of debt securities. Our principal uses of cash are to fund capital expenditures, service our outstanding debt, and fund our working capital requirements. Due to our high level of variable costs and the asset-light make-up of our business, we have historically been able to quickly implement cost-cutting measures and will continue to adapt as the market dictates. We have also used cash to make open market repurchases of our debt and may, from time to time, continue to make such repurchases when it is opportunistic to do so to manage our debt maturity profile.

We continually monitor potential capital sources, including equity and debt financing, to meet our investment and target liquidity requirements. Our future success and growth will be highly dependent on our ability to continue to access outside sources of capital.

Although we do not budget for acquisitions, pursuing growth through acquisitions may continue to be a part of our business strategy. Our ability to make significant additional acquisitions for cash will require us to obtain additional equity or debt financing, which we may not be able to obtain on terms acceptable to us or at all.

In 2024, our planned capital expenditure budget, excluding possible acquisitions, is expected to be between $15.0 million to $25.0 million. The nature of our capital expenditures is comprised of a base level of investment required to support our current operations and amounts related to growth and company initiatives. Capital expenditures for growth and company initiatives are discretionary. We continually evaluate our capital expenditures, and the amount we ultimately spend will depend on a number of factors, including expected industry activity levels and company initiatives.

At December 31, 2023, we had $30.8 million of cash and cash equivalents and $28.1 million of availability under the ABL Credit Facility, which resulted in a total liquidity position of $58.9 million. Our liquidity position will continue to be impacted by the semi-annual interest payments ($19.5 million based on amounts outstanding as December 31, 2023) to the holders of the 2028 Notes, which began on August 1, 2023. We believe that, based on our current forecasts, our cash on hand, together with cash flow from operations and borrowings under the ABL Credit Facility, should be sufficient to fund our capital requirements for at least the next twelve months from the issuance date of our consolidated financial statements. However, we can make no assurance regarding our ability to achieve our forecasts, which are materially dependent on our financial performance and the ever-changing market.

ATM Program

On November 6, 2023, we entered into the Equity Distribution Agreement with Piper Sandler & Co., as the Agent, pursuant to which we may, from time to time, sell shares of our common stock having an aggregate offering price of up to $30.0 million through the Agent acting as the Company’s sales agent. The Agent will receive a commission equal to 3.0% of the gross sale price of any shares sold under the Equity Distribution Agreement.

Under the Equity Distribution Agreement, we will set the parameters for the sale of the shares thereunder, including the number of shares to be sold, the time period during which sales are requested to be made and any price below which sales may not be made. During the quarter ended December 31, 2023, no sales were made under the Equity Distribution Agreement.

Units Offering and 2028 Notes

On January 30, 2023, we completed our public offering of 300,000 units with an aggregate stated amount of $300.0 million (the “Units”). Each Unit consisted of $1,000 principal amount of the 2028 Notes and five shares of our common stock (the “Common Stock”). We received proceeds of $279.8 million from the Units offering, after deducting underwriting discounts and commission, which was used to fund a portion of the redemption price of our 8.750% Senior Notes due 2023 (the “2023 Notes”). Each Unit separated into its constituent securities (the 2028 Notes and the shares of our Common Stock) automatically on October 27, 2023.

On January 30, 2023, we, and certain of our subsidiaries entered into an indenture, dated as of January 30, 2023 (the “2028 Notes Indenture”), with U.S. Bank Trust Company, National Association, as the trustee and as notes collateral agent, pursuant to which the 2028 Notes, which formed a part of the Units, were issued. The 2028 Notes will mature on February 1, 2028 and bear interest at an annual rate of 13.000% payable in cash semi-annually in arrears on each of February 1 and August 1, commencing August 1, 2023. The 2028 Notes are our senior secured obligations and are guaranteed on a senior secured basis by each of our current domestic subsidiaries and will be so guaranteed by certain future subsidiaries, subject to agreed guaranty and security principles and certain exclusions.

On each May 15 and November 14, commencing November 14, 2023 (each, an “Excess Cash Flow Offer Date”), we are required to make an offer (an “Excess Cash Flow Offer”) to all holders of the 2028 Notes and, if required by the terms of any Pari Passu Notes Lien Indebtedness (as defined in the 2028 Notes Indenture), to any holders of any Pari Passu Notes Lien Indebtedness to purchase, prepay or redeem, together on a pro-rata basis, the maximum principal amount of the 2028 Notes and any such Pari Passu Notes Lien Indebtedness (plus all accrued interest (including additional interest, if any) on the 2028 Notes and any such Pari Passu Notes Lien Indebtedness and the amount of all fees and expenses, including premiums, incurred in connection therewith) that may be purchased, prepaid or redeemed using an amount of cash equal to the Excess Cash Flow Amount (as defined in the 2028 Notes Indenture and which is 75.0% of Excess Cash Flow (as defined in the 2028 Notes Indenture), as determined immediately prior to the Excess Cash Flow Offer Date), if any, subject to certain exceptions set forth in the 2028 Notes Indenture. The offer price in any such offer will be equal to 100% of the principal amount of the 2028 Notes and any such Pari Passu Notes Lien Indebtedness (or, in respect of any such Pari Passu Notes Lien Indebtedness, such lesser price, if any, as may be provided for by the terms of such Pari Passu Notes Lien Indebtedness), plus accrued and unpaid interest and additional interest, if any, to, but excluding, the date of purchase, prepayment or redemption, subject to the rights of holders of the 2028 Notes or any such Pari Passu Notes Lien Indebtedness on the relevant record date to receive interest due on an interest payment date that is on or prior to the date of purchase, prepayment or redemption, and will be payable in cash. For the Excess Cash Flow Offer Date of November 14, 2023, the Excess Cash Flow Amount was $0 and, as such, no Excess Cash Flow Offer was made.

The 2028 Notes Indenture contains covenants that, among other things and subject to certain exceptions and qualifications, limit our ability and the ability of our restricted subsidiaries to engage in certain activities. We were in compliance with the provision of the 2028 Notes Indenture at December 31, 2023.

For additional information on the Units and the 2028 Notes, see Note 9 – Debt Obligations included in Item 8 of Part II of this Annual Report.

2023 Notes

On October 25, 2018, we issued $400.0 million of 2023 Notes under an indenture, dated as of October 25, 2018 (the “2023 Notes Indenture”), by and among us, including certain of our subsidiaries, and Wells Fargo, National Association, as trustee. The 2023 Notes bore interest at annual rate of 8.750% payable on May 1 and November 1 of each year. The 2023 Notes were senior unsecured obligations and were fully and unconditionally guaranteed on a senior unsecured basis by each of our current domestic subsidiaries.

On February 1, 2023, all of the outstanding 2023 Notes were redeemed at a redemption price of 100.0% of the principal amount thereof ($307.3 million), plus accrued and unpaid interest ($6.7 million), and the 2023 Notes Indenture was discharged as of January 30, 2023.

We repurchased approximately $13.0 million of 2023 Notes at a repurchase price of approximately $10.1 million in cash for the year ended December 31, 2022.

For additional information on the 2023 Notes, see Note 9 – Debt Obligations included in Item 8 of Part II of this Annual Report.

ABL Credit Facility

On October 25, 2018, we entered into a credit agreement dated as of October 25, 2018 (the “2018 ABL Credit Agreement”), that permitted aggregate borrowings of up to $200.0 million, subject to a borrowing base, including a Canadian tranche with a sub-limit of up to $25.0 million and a sub-limit of $50.0 million for letters of credit (the “ABL Credit Facility”). Pursuant to the 2018 ABL Credit Agreement, the ABL Credit Facility was set to mature on October 25, 2023 or, if earlier, on the date that was 180 days before the scheduled maturity date of the 2023 Notes if they had not been redeemed or repurchased by such date.

On January 17, 2023, we entered into the First Amendment to Credit Agreement (the “ABL Facility Amendment”) with JP Morgan Chase Bank, N.A., as administrative agent, and the lender parties thereto, which amends certain terms of the 2018 ABL Credit Agreement (as amended the “ABL Credit Agreement”). The ABL Facility Amendment became effective on January 30, 2023.

the borrowing base (the “Loan Limit”), (b) changed the interest rate benchmark from London Interbank Offered Rate to Term Secured Overnight Financing Rate with a 10 basis point spread adjustment and increased pricing from the existing range of 1.75% to 2.25% to a range of 2.00% to 2.50%, in each case depending on our leverage ratio, (c) modified the financial covenant, enhanced reporting and cash dominion triggers in the ABL Credit Facility from the existing minimum availability threshold of the greater of $18.75 million and 12.5% of the Loan Limit to a minimum availability threshold of (i) $12.5 million from January 30, 2023 until May 31, 2023 and (ii) the greater of $17.5 million and 12.5% of the Loan Limit thereafter, (d) decreased the Canadian tranche sub-limit from $25.0 million to $5.0 million, (e) decreased the letter of credit sub-limit from $50.0 million to $10.0 million and (f) made satisfaction of the Payment Conditions (as defined in the ABL Facility Amendment) a condition to an Excess Cash Flow Offer in addition to a condition to voluntary payments of the 2028 Notes. The Payment Conditions in summary are (A) no default or event of default on a pro forma basis and (B) immediately after and at all times and at all times during the 30 days prior, on a pro forma basis, (1) (x) availability under the ABL Credit Facility shall not be less than the greater of 15% of the Loan Limit and $22.5 million and (y) the fixed charge coverage ratio shall be at least 1.00 to 1.00 or (2) availability under the ABL Credit Facility shall not be less than the greater of 20% of the Loan Limit and $30.0 million.

Pursuant to the ABL Credit Agreement, all of the obligations under the ABL Credit Facility are secured by security interests (subject to permitted liens) in substantially all of the personal property of our domestic subsidiaries, excluding certain assets. The obligations under the Canadian tranche are further secured by security interests (subject to permitted liens) in substantially all of the personal property of Nine Energy Canada, Inc., a corporation organized under the laws of Alberta, Canada, and its restricted subsidiaries, excluding certain assets.

Both the ABL Credit Facility and the Units collateralization were completed within 30 days after closing of the Units offering in accordance with the terms of the ABL Facility Amendment and the 2028 Notes Indenture.

At December 31, 2023, we had $57.0 million of borrowings under the ABL Credit Facility, and our availability under the ABL Credit Facility was approximately $28.1 million, net of outstanding letters of credit of $1.1 million. On February 14, 2024, we repaid approximately $5.0 million of our outstanding borrowings under the ABL Credit Facility.

Cash Flows

Our cash flows for the years ended December 31, 2023, and 2022 are presented below:


	Year Ended December 31,
	2023		2022
	(in thousands)
Operating activities	$	45,509	$	16,672
Investing activities	(23,157)		(25,417)
Financing activities	(8,893)		4,849
Impact of foreign exchange rate on cash	(64)		(168)
Net change in cash and cash equivalents	$	13,395	$	(4,064)

Operating Activities

Net cash provided by operating activities was $45.5 million in 2023 compared to $16.7 million in net cash provided by operating activities in 2022. The $28.8 million increase in net cash provided by operating activities was primarily a result of a $64.9 million increase in cash provided by working capital, including an increase in accounts receivable from increased product and service sales between periods. The increase in net cash provided by operating activities was offset by a $36.1 million decrease in cash flow provided by operations, adjusted for any non-cash items, primarily driven by a decrease in income in comparison to 2022.

Investing Activities

Net cash used in investing activities was $23.2 million in 2023 compared to $25.4 million in net cash used in investing activities in 2022. The $2.2 million decrease was primarily due to a $4.0 million decrease in cash purchases of property and

equipment, partially offset by a $1.7 million decrease in proceeds from the sale of property and equipment (including insurance), in each case, in comparison to 2022.

Financing Activities

Net cash used in financing activities was $8.9 million in 2023 compared to $4.8 million in net cash provided in 2022. The $13.7 million change was primarily attributed to the $307.3 million redemption of the 2023 Notes and $6.3 million in debt issuance costs associated with the Units offering in 2023 that did not occur in 2022. The increase in net cash used was also partly attributed to an $8.0 million increase in payments on the ABL Credit Facility and an increase of $1.3 million in payments on short-term debt, each in comparison to 2022. The overall increase in net cash used was largely offset by $279.8 million in proceeds received from the Units offering in 2023 that did not occur in 2022. The overall increase in net cash used was also partially offset by an increase of $16.0 million in proceeds received in connection with the ABL Credit Facility, a decrease of $1.1 million of payments on finance leases, and a decrease of $0.8 million in the vesting of restricted stock, each in comparison to 2022, as well as $10.1 million of purchases of the 2023 Notes and $1.1 million of payments of the Magnum Promissory Notes (as defined in Note 9 – Debt Obligations) in 2022 that did not recur in 2023.

Critical Accounting Estimates

The discussion and analysis of our financial condition and results of operations are based upon our financial statements, which have been prepared in accordance with GAAP. The preparation of our financial statements requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. We evaluate our estimates and assumptions on a regular basis. We base our estimates on historical experience and various other assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates and assumptions used in preparation of our financial statements.

We consider the significant accounting policies identified below to be “critical accounting estimates” due to the following:

•The policies are dependent on estimates and assumptions made by us about matters that are inherently uncertain.

•The policies involve judgments and uncertainties to such an extent that there is a reasonable likelihood that materially different amounts could have been reported under different conditions, or if different assumptions had been used.

For additional information on our significant accounting policies, see Note 2 – Significant Accounting Policies included in Item 8 of Part II of this Annual Report.

Property and Equipment

Property and equipment is stated at cost and depreciated under the straight-line method over the estimated useful life of the asset. Equipment held under finance leases is stated at the present value of its future minimum lease payments and is depreciated under the straight-line method over the shorter of the lease term or the estimated useful life of the asset. Estimated useful lives requires significant judgment which is influenced by our historical experience in operating property and equipment, technological developments, and expectations of future demand. Should our estimates be too long or too short, we could report a disproportionate amount of losses or gains from sale or retirement.

Valuation of Long-Lived Assets

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. In performing the review for impairment, future cash flows expected to result from the use of the asset and its eventual disposal are estimated. If the undiscounted future cash flows are less than the carrying amount of the assets, there is an indication that the asset may be impaired. The amount of the impairment is measured as the difference between the carrying value and the Level 3 fair value of the asset. The Level 3 fair value is determined either through the use of an external valuation, or by means of an analysis of discounted future cash flows based on expected utilization. Determining fair value requires the use of estimates and assumptions. Such estimates and assumptions include revenue growth rates, operating profit margins, weighted average costs of capital, terminal growth rates, future market share, the impact of new product development, and future market conditions, among others. We believe that the estimates and assumptions used in impairment assessments are reasonable and appropriate. Impairment losses are reflected in “Income (loss) from operations” in our Consolidated Statements of Income and Comprehensive Income (Loss).

Recognition of Provisions for Contingencies

In the ordinary course of business, we are subject to various claims, suits, and complaints. We, in consultation with internal and external advisors, will provide for a contingent loss in the financial statements if it is probable that a liability has been incurred at the date of the financial statements and the amount can be reasonably estimated. Reasonable estimates are based upon an analysis of potential results, assuming a combination of litigation and settlement strategies. The accuracy of these estimates is impacted by, among other things, the complexity of the issues and the amount of due diligence we have been able to perform. If it is determined that the reasonable estimate of the loss is a range and that there is no best estimate within the range, provision will be made for the lower amount of the range. If the actual settlement costs, final judgments, or fines, after appeals, differ from our estimates, there may be a material adverse effect on our future financial results.

Stock-based Compensation and Fair Market Value Determination

We account for awards of stock-based compensation at fair value on the date granted to employees and recognize the compensation expense in the financial statements over the requisite service period. Forfeitures are recorded as they occur. All stock-based compensation expense is recorded using the straight-line method and is included in “General and administrative expenses” in our Consolidated Statements of Income and Comprehensive Income (Loss).

Fair value of all the options outstanding was measured using the Black-Scholes model. Determining the appropriate fair value model and calculating the fair value of options requires the input of highly subjective assumptions, including the expected volatility of the price of our stock, the risk-free rate, the expected term of the options, and the expected dividend yield of our common stock. These estimates involve inherent uncertainties and the application of management’s judgment. If factors change and different assumptions are used, our stock-based compensation expense could be materially different in the future. The Black-Scholes option pricing model requires estimates of key assumptions based on both historical information and management judgment regarding market factors and trends.

Expected Life – The expected term of stock options represents the period the stock options are expected to remain outstanding and is based on the simplified method, which is the weighted average vesting term plus the original contractual term, divided by two.

Expected Volatility – We develop our expected volatility based upon a weighted average volatility of our peer group.

Risk-free Interest Rate – The risk-free interest rates for options granted are based on the average of five year and seven year constant maturity Treasury bond rates whose term is consistent with the expected term of an option from the date of grant.

Expected Term – The expected term is based on the midpoint between the vesting date and contractual term of an option. The expected term represents the period that our stock-based awards are expected to be outstanding.

Expected Dividend Yield – We do not anticipate paying cash dividends on our shares of common stock; therefore, the expected dividend yield is assumed to be zero.

Fair value of the stock-based compensation for all of the performance share units as well as the fair value of the performance cash awards was measured using a Monte Carlo simulation model.

Recent Accounting Pronouncements

For additional information on recent accounting pronouncements, see Note 2 – Significant Accounting Policies included in Item 8 of Part II of this Annual Report.

Smaller Reporting Company Status

We are a “smaller reporting company” as defined by the SEC. As such, we are eligible to comply with the scaled disclosure requirements in several Regulation S-K and Regulation S-X items. Our disclosures in this Annual Report reflect these scaled requirements.

Item 7A. Quantitative and Qualitative Disclosures About Market Risk

As a “smaller reporting company,” as defined under the Exchange Act, we are not required to provide the information required by this Item.

Item 8. Financial Statements and Supplementary Data

Index to Consolidated Financial Statements


Report of Independent Registered Public Accounting Firm (PCAOB ID 238)			F-1
Consolidated Balance Sheets as of December 31, 2023 and 2022			F-3
Consolidated Statements of Income and Comprehensive Income (Loss) for the Years Ended December 31, 2023 and 2022			F-4
Consolidated Statements of Stockholders’ Equity (Deficit) for the Years Ended December 31, 2023 and 2022			F-5
Consolidated Statements of Cash Flows for the Years Ended December 31, 2023 and 2022			F-6
Notes to Consolidated Financial Statements			F-8

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Stockholders of Nine Energy Service, Inc.

Opinions on the Financial Statements and Internal Control over Financial Reporting

We have audited the accompanying consolidated balance sheets of Nine Energy Service, Inc. and its subsidiaries (the “Company”) as of December 31, 2023 and 2022, and the related consolidated statements of income and comprehensive income (loss), of stockholders’ equity (deficit), and of cash flows for the years then ended, including the related notes (collectively referred to as the “consolidated financial statements”). We also have audited the Company’s internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control – Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO).

In our opinion, the consolidated financial statements referred to above present fairly, in all material respects, the financial position of the Company as of December 31, 2023 and 2022, and the results of its operations and its cash flows for the years then ended in conformity with accounting principles generally accepted in the United States of America. Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2023, based on criteria established in Internal Control – Integrated Framework (2013) issued by the COSO.

Basis for Opinions

The Company’s management is responsible for these consolidated financial statements, for maintaining effective internal control over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in Management’s Report on Internal Control Over Financial Reporting appearing under Item 9A. Our responsibility is to express opinions on the Company’s consolidated financial statements and on the Company’s internal control over financial reporting based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) (PCAOB) and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud and whether effective internal control over financial reporting was maintained in all material respects.

Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our audits provide a reasonable basis for our opinions.

Definition and Limitations of Internal Control over Financial Reporting

A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A company’s internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have a material effect on the financial statements.

Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.

F-1

Critical Audit Matters

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

Revenue Recognition

As described in Note 2 to the consolidated financial statements, the Company’s revenue is derived from the sale of products and services which are sold directly to customers or are consumed by customers on their well sites. For product sales, the Company typically recognizes revenue when it meets its performance obligation upon the shipment of the products from its facilities to its customer. The Company recognizes service revenue over the time the service is performed as the customer consumes and benefits from the use of the Company’s products and services for well service. The Company recognized total revenues of $609.5 million for the year ended December 31, 2023.

The principal consideration for our determination that performing procedures relating to revenue recognition is a critical audit matter is a high degree of auditor effort in performing procedures related to the Company’s revenue recognition.

Addressing the matter involved performing procedures and evaluating audit evidence in connection with forming our overall opinion on the consolidated financial statements. These procedures included testing the effectiveness of controls relating to the revenue recognition process, including controls over the recording of revenue upon shipment of the product or completion of the service. These procedures also included, among others, (i) evaluating revenue transactions, on a sample basis, by (a) testing the issuance and settlement of invoices and credit memos; (b) tracing transactions not settled to a detailed listing of accounts receivable; (c) testing revenue transactions recorded but not yet invoiced by obtaining and inspecting proof of service; and (d) testing transactions recorded near period end to evaluate whether they were recorded in the appropriate period; (ii) testing, on a sample basis, outstanding customer invoice balances at year end by obtaining and inspecting source documents, including invoices, proof of service, and subsequent cash receipts, where applicable; and (iii) evaluating terms and conditions within master service agreements, on a sample basis.

/s/ PricewaterhouseCoopers LLP

Houston, Texas

March 7, 2024

We have served as the Company’s auditor since 2011.

F-2

NINE ENERGY SERVICE, INC.

CONSOLIDATED BALANCE SHEETS

(In thousands, except share and per share amounts)


	December 31,
	2023		2022
Assets
Current assets
Cash and cash equivalents	$	30,840	$	17,445
Accounts receivable, net	88,449		105,277
Income taxes receivable	490		741
Inventories, net	54,486		62,045
Prepaid expenses and other current assets	9,368		11,217
Total current assets	183,633		196,725
Property and equipment, net	82,366		89,717
Operating lease right of use assets, net	42,056		36,336
Finance lease right of use assets, net	51		547
Intangible assets, net	90,429		101,945
Other long-term assets	3,449		1,564
Total assets	$	401,984	$	426,834
Liabilities and Stockholders’ Equity (Deficit)
Current liabilities
Accounts payable	$	33,379	$	42,211
Accrued expenses	36,171		28,391
Current portion of long-term debt	2,859		2,267
Current portion of operating lease obligations	10,314		7,956
Current portion of finance lease obligations	31		178
Total current liabilities	82,754		81,003
Long-term liabilities
Long-term debt	320,520		338,031
Long-term operating lease obligations	32,594		29,370
Other long-term liabilities	1,746		1,937
Total liabilities	437,614		450,341
Commitments and contingencies (Note 12)
Stockholders’ equity (deficit)
Common stock (120,000,000 shares authorized at $0.01 par value; 35,324,861 and 33,221,266 shares issued and outstanding at December 31, 2023 and 2022 respectively)	353		332
Additional paid-in capital	795,106		775,006
Accumulated other comprehensive loss	(4,859)		(4,828)
Accumulated deficit	(826,230)		(794,017)
Total stockholders’ equity (deficit)	(35,630)		(23,507)
Total liabilities and stockholders’ equity (deficit)	$	401,984	$	426,834

The accompanying notes are an integral part of these consolidated financial statements.

F-3

NINE ENERGY SERVICE, INC.

CONSOLIDATED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME (LOSS)

(In thousands, except share and per share amounts)


	Year Ended December 31,
	2023		2022
Revenues
Service	$	464,233	$	455,364
Product	145,293		138,018
	609,526		593,382
Cost and expenses
Cost of revenues (exclusive of depreciation and amortization shown separately below)
Service	379,365		350,733
Product	111,385		106,360
General and administrative expenses	59,817		51,653
Depreciation	29,141		26,784
Amortization of intangibles	11,516		13,463
Loss on revaluation of contingent liability	437		454
Loss on sale of property and equipment	292		367
Income from operations	17,573		43,568
Interest expense	51,119		32,486
Interest income	(1,270)		(305)
Gain on extinguishment of debt	—		(2,843)
Other income	(648)		(709)
Income (loss) before income taxes	(31,628)		14,939
Provision for income taxes	585		546
Net income (loss)	$	(32,213)	$	14,393
Earnings (loss) per share
Basic	$	(0.97)	$	0.47
Diluted	$	(0.97)	$	0.45
Weighted average shares outstanding
Basic	33,282,234		30,930,890
Diluted	33,282,234		32,251,398
Other comprehensive loss, net of tax
Foreign currency translation adjustments, net of $0 tax in each period	$	(31)	$	(293)
Total other comprehensive loss, net of tax	(31)		(293)
Total comprehensive income (loss)	$	(32,244)	$	14,100

The accompanying notes are an integral part of these consolidated financial statements.

F-4

NINE ENERGY SERVICE, INC.

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY (DEFICIT)

(In thousands, except share amounts)


	Common Stock			Additional Paid-in		Accumulated Other Comprehensive		Retained Earnings (Accumulated		Total Stockholders’ Equity
	Shares	Amounts		Capital		Income (Loss)		Deficit)		(Deficit)
Stockholders’ equity (deficit) as of December 31, 2021	32,826,325	$	328	$	773,350	$	(4,535)	$	(808,410)	$	(39,267)
Issuance of common stock under stock compensation plan, net of forfeitures	623,328	7		(7)		—		—		—
Stock-based compensation expense	—	—		2,440		—		—		2,440
Vesting of restricted stock and stock units	(228,387)	(3)		(777)		—		—		(780)
Other comprehensive loss	—	—		—		(293)		—		(293)
Net income	—	—		—		—		14,393		14,393
Stockholders’ equity (deficit) as of December 31, 2022	33,221,266	$	332	$	775,006	$	(4,828)	$	(794,017)	$	(23,507)
Issuance of common stock associated with the 2028 Units offering	1,500,000	15		17,939		—		—		17,954
Issuance of common stock under stock compensation plan, net of forfeitures	603,078	6		(6)		—		—		—
Stock-based compensation expense	—	—		2,169		—		—		2,169
Vesting of restricted stock and stock units	517	—		(2)		—		—		(2)
Other comprehensive loss	—	—		—		(31)		—		(31)
Net loss	—	—		—		—		(32,213)		(32,213)
Stockholders’ equity (deficit) as of December 31, 2023	35,324,861	$	353	$	795,106	$	(4,859)	$	(826,230)	$	(35,630)

The accompanying notes are an integral part of these consolidated financial statements.

F-5

NINE ENERGY SERVICE, INC.

CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)


	Year Ended December 31,
	2023		2022
Cash flows from operating activities
Net income (loss)	$	(32,213)	$	14,393
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation	29,141		26,784
Amortization of intangibles	11,516		13,463
Amortization of operating leases	12,524		8,670
Amortization of deferred financing costs	7,413		2,545
Provision for (recovery of) doubtful accounts	333		(166)
Provision for inventory obsolescence	2,320		2,966
Stock-based compensation expense	2,169		2,440
Gain on extinguishment of debt	—		(2,843)
Loss on sale of property and equipment	292		367
Loss on revaluation of contingent liability	437		454
Abandonment of in-process research and development	—		1,000
Changes in operating assets and liabilities
Accounts receivable, net	16,489		(41,114)
Inventories, net	5,219		(22,968)
Prepaid expenses and other current assets	1,148		(818)
Accounts payable and accrued expenses	1,058		19,476
Income taxes receivable/payable	252		655
Operating lease obligations	(12,344)		(8,698)
Other assets and liabilities	(245)		66
Net cash provided by operating activities	45,509		16,672
Cash flows from investing activities
Proceeds from sales of property and equipment	606		2,959
Proceeds from property and equipment casualty losses	840		175
Purchases of property and equipment	(24,603)		(28,551)
Net cash used in investing activities	(23,157)		(25,417)
Cash flows from financing activities
Proceeds from Units offering, net of discount	279,750		—
Redemption of 2023 Notes	(307,339)		—
Cost of debt issuance	(6,290)		—
Proceeds from ABL Credit Facility	40,000		24,000
Payments on ABL Credit Facility	(15,000)		(7,000)
Purchases of 2023 Notes	—		(10,081)
Payments on Magnum Promissory Notes	—		(1,125)
Proceeds from short-term debt	4,733		4,086
Payments of short-term debt	(4,141)		(2,787)
Payments on finance leases	(217)		(1,269)
Payments of contingent liability	(387)		(195)
Vesting of restricted stock and stock units	(2)		(780)
Net cash provided by (used in) financing activities	(8,893)		4,849

F-6


	Year Ended December 31,
	2023		2022
Impact of foreign currency exchange on cash	(64)		(168)
Net increase (decrease) in cash and cash equivalents	13,395		(4,064)
Cash and cash equivalents
Cash and cash equivalents at beginning of period	17,445		21,509
Cash and cash equivalents at end of period	$	30,840	$	17,445

Supplemental disclosures of cash flow information:
Cash paid for interest	$	31,431	$	29,708
Cash paid (refunded) for income taxes	$	563	$	(116)
Supplemental schedule of non-cash activities:
Capital expenditures in accounts payable and accrued expenses	$	1,107	$	3,443
Receivable from property and equipment sale (including insurance)	$	—	$	701

The accompanying notes are an integral part of these consolidated financial statements.

F-7

NINE ENERGY SERVICE, INC.

NOTES TO THE FINANCIAL STATEMENTS

1. Company and Organization

Company Description

Nine Energy Service, Inc. (the “Company” or “Nine”), a Delaware corporation, is an oilfield services business that provides services integral to the completion of unconventional wells through a full range of tools and methodologies. The Company is headquartered in Houston, Texas.

The Company’s chief operating decision maker (the “CODM”), which is its Chief Executive Officer, and its board of directors allocate resources and assess performance based on financial information presented at a consolidated level. Accordingly, the Company determined that it operates as one reportable segment, known as Completion Solutions.

Risks and Uncertainties

The Company’s business depends, to a significant extent, on the level of unconventional resource development activity and corresponding capital spending of oil and natural gas companies. These activity and spending levels are strongly influenced by current and expected oil and natural gas prices. Following an extreme decline in activity levels and pricing in 2020, the Company has been focused on strategically implementing price increases and gaining market share. In 2022, oil and natural gas prices improved, and activity levels increased, compared to 2021, resulting in higher demand for the Company’s products and services, and the Company implemented price increases in most service lines. In 2023, commodity prices were significantly lower compared to 2022, resulting in the rig count declining by over 157 rigs since the end of 2022. Going forward, the Company’s earnings will be affected by its customers’ activity plans (which are strongly influenced by commodity prices), the Company’s ability to maintain current pricing levels, the impact of wage and labor inflation, and labor shortage and supply chain constraints.

2. Significant Accounting Policies

Basis of Presentation

The accompanying consolidated financial statements are prepared in accordance with accounting principles generally accepted in the United States of America (“GAAP”).

Principles of Consolidation

The consolidated financial statements as of December 31, 2023 and 2022, and for the years ended December 31, 2023 and 2022, include the accounts of Nine and its wholly owned subsidiaries. All inter-company balances and transactions have been eliminated in the consolidation.

Use of Estimates

The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the consolidated financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates. These estimates are based on management’s best knowledge of current events and actions that the Company may undertake in the future. Such estimates include fair value assumptions used in analyzing long-lived assets for possible impairment, useful lives used in depreciation and amortization expense, recognition of provisions for contingencies, and stock-based compensation fair value. It is at least reasonably possible that the estimates used will change within the next year.

Reclassifications

Certain reclassifications have been made to prior period amounts to conform to the current period financial statement presentation. These reclassifications relate to presenting “Operating lease obligations” as a separate line item in the Company’s Consolidated Statements of Cash Flows as well as presenting “Canada and other” separately in Note 3 – Revenues.

Revenue Recognition

The Company recognizes revenue under Accounting Standards Codification Topic 606 (“ASC 606”) when products

F-8

are received by a customer’s domestic common carrier at the Company’s facility or, for international sales, when the product is shipped to the customer’s exporter. The Company believes this recognition policy reflects the point at which the customer obtains control of the product as required by ASC 606.

Performance Obligations

A performance obligation is a promise in a contract to transfer a distinct good or service to the customer and is the unit of account in ASC 606. A contract’s transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. The Company excludes sales taxes, value added taxes, and other taxes it collects concurrent with revenue-producing activities from revenue.

The Company’s revenue is derived from the sale of products and services which are sold directly to customers or are consumed by customers on their well sites. For product sales, the Company typically recognizes revenue when it meets its performance obligation upon the shipment of the products from its facilities to its customer. The Company recognizes service revenue over the time the service is performed as the customer consumes and benefits from the use of the Company’s products and services for well service. Service revenues represent revenue recognized over time, as the Company’s customer arrangements typically provide agreed upon hourly or daily fixed-rates, and the Company recognizes service revenue based upon the number of hours or days services have been performed.

Contracts for the Company’s products and services are negotiated on a per-job basis at a regional level. Contracts vary in nature but typically have a duration of less than a month and have a single performance obligation either for a job, a series of distinct jobs, or a period the Company stands ready to provide its services to its client as needed.

The Company’s payment terms vary by the type and location of its customers and type of product and service offered. The Company receives cash equal to the invoice amount for most services and product sales, and payment terms typically range from 30 to 60 days from the date the Company invoices a customer. Since the period between the delivery of the Company’s products and services and the Company’s receipt of customer payment for these products and services is not expected to exceed one year, the Company has elected not to calculate or disclose a financing component for its customer contracts.

Contract Estimates

The Company receives reimbursements from its customers for the purchase of supplies, equipment, personnel services, and other services provided at a customer’s request. Reimbursable revenues are subject to uncertainty as the timing of the receipt of these amounts is dependent on factors outside of the Company’s influence. Accordingly, these revenues are not recognized until the uncertainty is resolved, which typically occurs when the related costs are incurred on behalf of the customer. The Company is considered a principal in these transactions and records the associated revenues at the gross amount billed to the customer.

Changes and modifications to contracts are routine in the performance of the Company’s contracts due to the dynamic nature of well operations and the services the Company provides for its customers. The Company considers contract modifications to exist when the modification either creates a new contract or changes the existing enforceable rights and obligations of a contract. Most of the Company’s contract modifications are for services or goods that are not distinct from existing contracts due to the significant integration provided or significant interdependencies in the context of the contract and are accounted for as if they were part of the original contract.

Contract Balances

Any contract assets are included in “Accounts receivable, net” in the Company’s Consolidated Balance Sheets. Contract assets arise when recorded revenues for a contract exceed the amounts billed under the terms of the contracts. The Company classifies contract liabilities as unearned income which is included in “Accrued expenses” in the Company’s Consolidated Balance Sheets. Such deferred revenue typically results from advance payments received on well service orders prior to performance of the service.

For information regarding the Company’s revenue, see Note 3 – Revenues.

Leases

The Company determines if an arrangement is a lease at its inception. To the extent an arrangement represents a lease, the Company classifies that lease as an operating lease or a finance lease under Accounting Standards Update (“ASU”) 2016-02, Leases (Topic 842) and its related ASUs (“ASC 842”).

F-9

The Company capitalizes operating leases on its Consolidated Balance Sheets through a Right of Use (“ROU”) asset and a corresponding lease liability. ROU assets represent the Company’s right to use an underlying asset for the lease term, and lease liabilities represent the Company’s obligation to make lease payments arising from the operating lease. Operating lease ROU assets and obligations are recognized at the commencement date of an arrangement based on the present value of lease payments over the lease term utilizing an interest rate that the Company would have incurred to borrow over a similar term the funds necessary to purchase the leased asset.

Operating leases are included in “Operating lease right of use assets, net,” “Current portion of operating lease obligations,” and “Long-term operating lease obligations” in the Company’s Consolidated Balance Sheets as of December 31, 2023 and 2022. Lease expense for operating leases is recognized on a straight-line basis over the lease term for 2023 and 2022.

Finance leases are included in the line items “Finance lease right of use assets, net,” “Current portion of finance lease obligations,” and “Long-term finance lease obligations” in the Company’s Consolidated Balance Sheets as of December 31, 2023 and 2022.

For additional information regarding the Company’s leases, see Note 6 – Leases.

Cash and Cash Equivalents

The Company considers all highly liquid debt instruments with a maturity of three months or less when purchased to be cash equivalents. Throughout the year, the Company maintained cash balances that were in excess of their federally insured limits. The Company has not experienced any losses in such accounts.

Cash flows from the Company’s Canadian subsidiary are calculated based on its functional currency. As a result, amounts related to changes in assets and liabilities reported in the Company’s Consolidated Statements of Cash Flows will not necessarily agree to changes in the corresponding balances in the Company’s Consolidated Balance Sheets.

Foreign Currency

The Company’s functional currency is the United States Dollar (“USD”). The financial position and results of operations of the Company’s Canadian subsidiary are measured using the local currency as the functional currency. Revenues and expenses of the subsidiary have been translated into USD at average exchange rates prevailing during the period. Assets and liabilities have been translated at the rates of exchange on the date of the Company’s Consolidated Balance Sheets. The resulting translation gain and loss adjustments have been recorded as a separate component of other comprehensive income (loss) in the Company’s Consolidated Statements of Income and Comprehensive Income (Loss) and its Consolidated Statements of Stockholders’ Equity (Deficit).

Accounts Receivable

The Company extends credit to customers in the normal course of business. Accounts receivable are carried at their estimated collectible amount. Trade credit is generally extended on a short-term basis; thus, receivables do not bear interest, although a finance charge may be applied to amounts past due. The Company maintains an allowance for doubtful accounts for estimated losses that may result from the inability of its customers to make required payments. Such allowances are based upon several factors including, but not limited to, credit approval practices and industry and customer historical experience, as well as the current and projected financial condition of the specific customer. Accounts receivable outstanding longer than contractual terms are considered past due. The Company writes off accounts receivable to the allowance for doubtful accounts when they become uncollectible. Any payments subsequently received on receivables previously written off are credited to bad debt expense.

The Company had $88.4 million and $105.3 million of “Accounts receivable, net” at December 31, 2023 and 2022, respectively. The Company maintains an allowance for doubtful accounts based on the expected collectability of accounts receivable, which is included in “Accounts receivable, net” on the Company’s Consolidated Balance Sheets. The Company had an allowance for doubtful accounts of $0.6 million and $0.2 million at December 31, 2023 and 2022, respectively. Bad debt expense was $0.3 million for the year ended December 31, 2023, and bad debt expense recovery was $0.2 million for the year ended December 31, 2022.

Concentration of Credit Risk

The Company derives a significant portion of its revenues from companies in the exploration and production (“E&P”) industry, and its customer base includes a broad range of integrated and independent domestic E&P companies and international E&P companies operating in the markets that the Company serves. While current energy prices are important

F-10

contributors to positive cash flow for the customers, expectations about future prices and price volatility are generally more important for determining future spending levels. Any prolonged increase or decrease in oil and natural gas prices affects the levels of exploration, development, and production activity as well as the entire health of the oil and natural gas industry and can therefore negatively impact spending by the Company’s customers. No customer accounted for more than 10% of the revenues for the years ended December 31, 2023 and 2022.

Concentration of Supplier Risk

Purchases during the years ended December 31, 2023 and 2022 did not include purchases from any supplier that individually represented more than 10% of total operating purchases.

Property and Equipment

Property and equipment is stated at cost and depreciated under the straight-line method over the estimated useful lives of the assets. Equipment held under finance leases is stated at the present value of its future minimum lease payments and is depreciated under the straight-line method over the shorter of the lease term or the estimated useful life of the asset. When assets are retired or otherwise disposed of, the cost and related accumulated depreciation are removed from the accounts, and any resulting gain or loss is recognized within operating expenses. Normal repair and maintenance costs are charged to operating expense as incurred. Significant renewals and betterments are capitalized.

Valuation of Long-Lived Assets

Long-lived assets are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset may not be recoverable. In performing the review for impairment, future cash flows expected to result from the use of the asset and its eventual disposal are estimated. If the undiscounted future cash flows are less than the carrying amount of the assets, there is an indication that the asset may be impaired. The amount of the impairment is measured as the difference between the carrying value and the Level 3 fair value of the asset. The Level 3 fair value is determined either through the use of an external valuation, or by means of an analysis of discounted future cash flows based on expected utilization. Determining fair value requires the use of estimates and assumptions. Such estimates and assumptions include revenue growth rates, operating profit margins, weighted average costs of capital, terminal growth rates, future market share, the impact of new product development, and future market conditions, among others. The Company believes that the estimates and assumptions used in impairment assessments are reasonable and appropriate. Impairment losses are reflected in “Income (loss) from operations” in the Company’s Consolidated Statements of Income and Comprehensive Income (Loss).

Valuation of Intangible Assets

Intangible assets with definite lives include technology, customer relationships, and non-compete agreements. The Level 3 fair value of technology and the Level 3 fair value of customer relationships are estimated using the income approach, specifically the multi-period excess earnings method. The multi-period excess earnings method consists of isolating the cash flows attributed to the intangible asset, which are then discounted to present value to calculate the Level 3 fair value of the intangible asset. The Level 3 fair value of non-compete agreements is estimated using a with and without scenario where cash flows are projected through the term of the non-compete agreement assuming the non-compete agreement is in place and compared to cash flows assuming the non-compete agreement is not in place.

Intangible assets with definite lives are amortized based on the estimated consumption of the economic benefit over their estimated useful lives. Intangible assets with definite lives are tested for impairment whenever events or changes in circumstances indicate that their carrying amount may not be recoverable.

Intangible assets with indefinite useful lives are not subject to amortization. For intangible assets with indefinite useful lives, an assessment for impairment is performed annually on December 31 or when there is an indication an impairment may have occurred. Intangible assets with indefinite useful lives are reviewed for impairment by comparing the carrying value of the intangible asset to the Level 3 fair value of the intangible asset. The Level 3 fair value of intangible assets with indefinite useful lives is estimated using the relief-from-royalty method of the income approach. This approach is based on the assumption that in lieu of ownership, a company would be willing to pay a royalty in order to exploit the related benefits of this intangible asset. Determining fair value requires the use of estimates and assumptions. Such estimates and assumptions include revenue growth rates, operating profit margins, royalty rates, weighted average costs of capital, terminal growth rates, future market share, the impact of new product development, and future market conditions, among others. The Company believe that the estimates and assumptions used in impairment assessments are reasonable and appropriate. The Company recognizes an indefinite-lived intangible asset impairment charge of the amount by which the carrying value of the intangible asset exceeds the Level 3 fair value of the intangible asset. Impairment losses are reflected in “Income (loss) from operations” in the Company’s Consolidated

F-11

Statements of Income and Comprehensive Income (Loss).

Stock-based Compensation

The Company has stock-based compensation plans for certain of its employees. The Company measures employee stock-based compensation awards at fair value on the date they are granted to employees and recognizes compensation cost in its financial statements over the requisite service period. As a result of the adoption of ASU No. 2016-09, the Company elected to account for stock-based compensation forfeitures as they occur.

Restricted Stock and Restricted Stock Units

Compensation expense is recorded for restricted stock and restricted stock units over the applicable vesting period based on the Company’s closing stock price as of the grant date.

Performance Stock Units and Performance Cash Awards

Performance stock units and performance cash awards are recorded at their fair value and expensed over their performance period. Fair value for performance stock units and performance cash awards is measured using a Monte Carlo simulation model.

Options

Options are issued with an exercise price equal to the fair value of the stock on the date of grant. Compensation expense is recorded for the fair value of the stock options and is recognized over the period of the underlying security’s vesting schedule. Consideration paid on the exercise of stock options is credited to share capital and additional paid-in capital. For options, fair value of the stock-based compensation is measured by use of the Black-Scholes pricing model. The following discusses the assumptions used related to the Black-Scholes pricing model.

•The expected term of stock options represents the period the stock options are expected to remain outstanding and is based on the simplified method, which is the weighted average vesting term plus the original contractual term, divided by two.

•Expected volatility measures the amount that a stock price has fluctuated or is expected to fluctuate during a period. The Company developed its expected volatility based upon a weighted average volatility of its peer group.

•At the time of the issuance of the options, the Company did not plan to pay cash dividends in the foreseeable future. Therefore, a zero expected dividend yield was used in the valuation model.

•The risk-free interest rate is based on U.S. Treasury zero-coupon issues with remaining terms similar to the expected term on the options.

Income Taxes

The Company accounts for income taxes under Accounting Standards Codification 740, Income Taxes (“ASC 740”). Under this method, deferred income tax assets and liabilities are determined based upon temporary differences between the carrying amounts and tax bases of the Company’s assets and liabilities at the balance sheet date and are measured using enacted tax rates and laws that will be in effect when the differences are expected to reverse. The effect on deferred tax assets and liabilities of a change in the tax rates is recognized in income in the period in which the change occurs. The Company records a valuation reserve in each reporting period when management believes that it is more likely than not that any deferred tax asset created will not be realized.

The Company recognizes the financial statement benefit of a tax position only after determining that the relevant tax authority would more likely than not sustain the position following an audit. If a tax position meets the “more likely than not” recognition criteria, the tax position is measured at the largest amount of benefit greater than 50% likely of being realized upon ultimate settlement.

Fair Value of Financial Instruments

The carrying amounts for financial instruments classified as current assets and current liabilities approximate fair value, due to the short maturity of such instruments.

F-12

For financial assets and liabilities disclosed at fair value, fair value is determined as the exit price, or the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The established fair value hierarchy divides fair value measurement into three levels:

•Level 1 – inputs are quoted prices (unadjusted) in active markets for identical assets or liabilities that the reporting entity has the ability to access at the measurement date;

•Level 2 – inputs other than quoted prices included within Level 1 that are observable for the assets or liability, either directly or indirectly; and

•Level 3 – inputs are unobservable for the asset or liability, which reflect the best judgment of management.

Financial assets and liabilities that are disclosed at fair value are categorized in one of the above three levels based on the lowest level input that is significant to the fair value measurement in its entirety. Level 1 provides the most reliable measure of fair value, whereas Level 3 generally requires significant management judgment.

The fair value of the Company’s debt obligations is classified as Level 2 in the fair value hierarchy and is established based on observable inputs in less active markets. For additional information on the fair value of the Company’s debt obligations, see Note 9 – Debt Obligations.

The fair value of the Company’s contingent consideration is classified as Level 3 in the fair value hierarchy and is established on unobservable markets which reflect the best judgment of management. For additional information on the fair value of the Company’s contingent consideration, see Note 12 – Commitments and Contingencies.

Earnings (Loss) Per Share

Basic earnings (loss) per share is calculated by dividing net income (loss) by the weighted average number of common shares outstanding during the period. Diluted earnings (loss) per share is calculated by dividing net income (loss) by the weighted average number of common shares outstanding during the period, taking into effect, if any, the exercise of potentially dilutive stock options assumed to be purchased from the proceeds using the average market price of the Company’s stock for each of the periods presented as well as potentially dilutive restricted stock, restricted stock units, and performance stock units. There was no dilutive effect for the year ended December 31, 2023 as the Company was in a net loss position. For additional information on earnings (loss) per share, see Note 14 – Earnings (Loss) Per Share.

Accounting Pronouncements Recently Adopted

In June 2016, the Financial Accounting Standards Board (“FASB”) issued ASU 2016-13, Financial Instruments – Credit Losses (Topic 326): Measurement of Credit Losses on Financial Instruments which requires a financial asset (or a group of financial assets) measured at amortized cost basis to be presented at the net amount expected to be collected. The amendments in ASU 2016-13 replace the current incurred loss impairment methodology in current GAAP with a methodology that reflects expected credit losses and requires consideration of a broader range of reasonable and supportable information. ASU 2016-13 was effective for Securities and Exchange Commission filers, excluding smaller reporting companies, for fiscal years beginning after December 15, 2019, including interim periods within those fiscal years. As an emerging growth company at the time of adoption, the Company was permitted to adopt the new standard for fiscal years beginning after December 15, 2022, including interim periods within those fiscal years. The adoption of ASU 2016-13 in the first quarter of 2023 did not have a material impact on the Company’s consolidated financial statements included in this Annual Report on Form 10-K.

Accounting Pronouncements Not Yet Adopted

In November 2023, the FASB issued ASU 2023-07, Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures. The new guidance requires disclosures of significant segment expenses provided to the CODM and included in reported measures of segment profit and loss. The guidance requires interim and annual disclosures about a reportable segment’s profit or loss and assets. Additionally, the guidance requires disclosure of other segment items by reportable segment including a description of its composition. The amendments in ASU 2023-07 are effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024, on a retrospective basis. The Company is currently evaluating the impact that this guidance will have on the disclosures within its consolidated financial statements.

In December 2023, the FASB issued ASU 2023-09, Income Taxes (Topic 740): Improvements to Income Tax Disclosures. The amendments require disclosure of specific categories in the rate reconciliation and provide additional information for reconciling items that meet a quantitative threshold and further disaggregation of income taxes paid for

F-13

individually significant jurisdictions. The ASU is effective for fiscal years beginning after December 15, 2024. The Company is currently evaluating the impact that this guidance will have on the disclosures within its consolidated financial statements.

3. Revenues

The Company recognizes revenues from the sales of products at a point in time and revenues from the sales of services over time.

Disaggregation of Revenues

Disaggregated revenue for the years ended December 31, 2023 and 2022 was as follows:


	Year Ended December 31,
	2023		2022
	(in thousands)
Cement	$	224,761	$	229,409
Tools	145,293		138,018
Coiled tubing	122,554		118,603
Wireline	116,918		107,352
Total revenues	$	609,526	$	593,382

Revenue by country for the years ended December 31, 2023 and 2022 were as follows:


	Year Ended December 31, 2023				Year Ended December 31, 2022
	Amount		Percentage		Amount		Percentage
	(in thousands)				(in thousands)
United States	$	602,343	98.8	%	$	587,873	99.1	%
Canada and other	7,183		1.2	%	5,509		0.9	%
	$	609,526	100.0	%	$	593,382	100.0	%

Performance Obligations

At December 31, 2023 and December 31, 2022, the amount of remaining performance obligations was not material.

Contract Balances

At December 31, 2023 and December 31, 2022, contract assets and contract liabilities were not material.

4. Inventories

Inventories, consisting primarily of finished goods and raw materials, are stated at the lower of cost or net realizable value. Cost is determined on an average cost basis. The Company reviews its inventory balances and writes down its inventory for estimated obsolescence or excess inventory equal to the difference between the cost of inventory and the estimated market value based upon assumptions about future demand and market conditions. The reserve for obsolescence was $6.2 million and $6.7 million at December 31, 2023 and 2022, respectively.

F-14

Inventories, net as of December 31, 2023 and 2022 were comprised of the following:


	December 31,
	2023		2022
	(in thousands)
Raw materials	$	31,235	$	39,249
Work in progress	542		161
Finished goods	28,867		29,345
Inventories	60,644		68,755
Reserve for obsolescence	(6,158)		(6,710)
Inventories, net	$	54,486	$	62,045

5. Property and Equipment

Property and equipment amounts as of December 31, 2023 and 2022 were as follows:


		December 31,
	Estimated Useful Lives	2023		2022
		(in thousands)
Operating equipment	1 to 12 years	$	318,553	$	321,315
Autos and trucks	1 to 7 years	3,392		4,140
Furniture, fixtures, and equipment	2 to 12 years	2,469		3,843
Shop equipment	3 to 15 years	14,220		14,552
Buildings	7 to 39 years	5,690		4,599
Leasehold improvements	3 to 11 years	2,279		2,017
Land	indefinite	1,561		1,348
		348,164		351,814
Less: Accumulated depreciation		(265,798)		(262,097)
Property and equipment, net		$	82,366	$	89,717

Depreciation expense was $29.1 million and $26.8 million for the years ended December 31, 2023 and 2022, respectively.

Capital expenditures for years ended December 31, 2023 and 2022 were as follows:


	Year Ended December 31,
	2023		2022
	(in thousands)
Completion Solutions	$	22,337	$	32,162
Corporate	—		105
	$	22,337	$	32,267

6. Leases

Under ASC 842, the Company determines if an arrangement is a lease at inception. Leases with an initial term of 12 months or less are not recorded in the Company’s Consolidated Balance Sheets. Lease with an initial term greater than 12 months are recognized in the Company’s Consolidated Balance Sheets based on lease classification as either operating or financing. Some of the Company’s lease agreements include lease and non-lease components for which the Company has elected to not separate for all classes of underlying assets. The Company’s lease agreements do not contain any material residual value guarantees or material restrictive covenants. The Company may sublease its real estate to third parties, subject to certain provision of the lease, when it has no future use for the property.

F-15

Operating Leases

As a lessee, the Company’s operating lease portfolio primarily consists of operating leases for equipment, vehicles, office space, yard facilities, and employee housing. Operating lease ROU assets and operating lease obligations are recognized based on the present value of the future minimum lease payments at commencement date. As most of the Company’s leases do not provide an implicit borrowing rate, the Company uses its incremental borrowing rate based on the lease information available at the commencement date in determining the present value of future payments. The incremental borrowing rate utilized is based upon the interest rate associated with the Company’s ABL Credit Facility (as defined and described in Note 9 – Debt Obligations) which is utilized to fund its working capital needs and planned capital expenditures. The Company’s leases have remaining terms of one to ten years and may include options to extend or terminate the lease. The operating lease ROU assets also include any upfront lease payments made and exclude lease incentives and initial direct costs incurred.

The Company leases most of these properties under long-term (greater than one year) non-cancelable term leases many of which contain renewal options that can extend the lease term from one to five years and some of which contain escalation clauses. The Company may also enter into short-term or month-to-month operating leases. Options to renew these leases are generally not considered reasonably certain to be exercised due to the nature of the Company’s operations and the markets it serves. Therefore, the periods covered by such optional periods are not included in the determination of the term of the lease.

The Company also leases supplemental equipment, typically under cancellable short-term contracts which are less than 30 days. This equipment is typically required for a specific project and for a short duration. Due to the nature of the Company’s operations, any option to renew these short-term leases is generally not considered reasonably certain to be exercised. Therefore, the periods covered by such optional periods are not included in the determination of the term of the lease, and the lease payments during these periods are similarly excluded from the calculation of operating lease asset and lease obligation balances.

Operating lease expense consists of rent expense related to leases that were included in ROU assets under ASC 842. The Company recognizes operating lease expense on a straight-line basis, except for certain variable expenses that are recognized when the variability is resolved, typically during the period in which they are paid. Variable operating lease payments typically include charges for property taxes and insurance, and some leases contain variable payments related to non-lease components, including common area maintenance and usage of facilities or office equipment (for example, copiers). The Company does not have variable expenses.

Additional Information

The following table summarizes the components of the Company’s lease expense recognized for the years ended December 31, 2023 and 2022, excluding variable lease and prepaid rent costs:


	Year Ended December 31,
	2023		2022
	(in thousands)
Operating lease expense
Operating lease right of use assets	$	12,524	$	8,670
Operating lease non right of use assets	6,810		7,697
Total operating lease expense	$	19,334	$	16,367

Finance lease expense
Depreciation of right of use assets	$	89	$	385
Interest on lease obligations	69		199
Total finance lease expense	$	158	$	584

Operating lease expense is included in the line items “Cost of revenues” and “General and administrative expenses” in the Company’s Consolidated Statements of Income and Comprehensive Income (Loss) for the years ended December 31, 2023 and 2022.

F-16

Supplemental information related to leases was as follows as of December 31, 2023 and 2022:


	December 31,
	2023	2022
Operating leases
Weighted average remaining lease term	4.3	5.3
Weighted average discount rate	5.8%	5.0%

Finance leases
Weighted average remaining lease term	0.7	0.4
Weighted average discount rate	25.1%	21.7%

Supplemental balance sheet information related to leases was as follows as of December 31, 2023 and 2022:


	December 31,
	2023		2022
	(in thousands)
Operating lease right of use assets
Operating lease right of use assets, gross	$	65,026	$	52,947
Less: Accumulated amortization	(22,970)		(16,611)
Operating lease right of use assets, net	$	42,056	$	36,336

Operating lease obligations
Current portion of operating lease obligations	$	10,314	$	7,956
Long-term operating lease obligations	32,594		29,370
Total operating lease obligations	$	42,908	$	37,326

Finance lease right of use assets
Finance lease right of use assets, gross	$	70	$	1,057
Less: Accumulated depreciation	(19)		(510)
Finance lease right of use assets, net	$	51	$	547

Finance lease obligations
Current portion of finance lease obligations	$	31	$	178
Long-term finance lease obligations	—		—
Total finance lease obligations	$	31	$	178

F-17

Future annual minimum lease payments as of December 31, 2023 were as follows:


	Operating Lease Right of Use Obligations		Finance Leases		Total
	(in thousands)
2024	$	12,470	$	46	$	12,516
2025	11,571		—		11,571
2026	9,998		—		9,998
2027	7,169		—		7,169
2028	5,588		—		5,588
Thereafter	1,567		—		1,567
Total lease payments	$	48,363	$	46	$	48,409
Less: present value discount	(5,455)		(15)		(5,470)
Present value of lease obligations	$	42,908	$	31	$	42,939

Supplemental cash flow information related to leases for the years ended December 31, 2023 and 2022 were as follows:


	Year Ended December 31,
	2023		2022
	(in thousands)
Cash paid for amounts included in the measurement of lease obligations:
Operating cash flows from operating leases	$	12,344	$	8,698
Operating cash flows from finance leases	$	89	$	385
Financing cash flows from finance leases	$	217	$	1,269

Right of use assets obtained in exchange for lease obligations:
Operating leases	$	15,955	$	8,356
Finance leases	$	70	$	336

7. Intangible Assets

The gross carrying amount and accumulated amortization of intangible assets as of December 31, 2023 and 2022 were as follows:


	December 31, 2023
	Gross Carrying Amount		Accumulated Amortization		Net Carrying Amount		Weighted Average Amortization Period
	(in thousands, except weighted average amortization period information)
Customer relationships	$	63,270	$	(52,622)	$	10,648	3.8
Non-compete agreements	6,500		(6,500)		—		0.0
Technology	125,110		(45,329)		79,781		9.7
Total	$	194,880	$	(104,451)	$	90,429

F-18


	December 31, 2022
	Gross Carrying Amount		Accumulated Amortization		Net Carrying Amount		Weighted Average Amortization Period
	(in thousands, except weighted average amortization period information)
Customer relationships	$	63,270	$	(49,845)	$	13,425	4.8
Non-compete agreements	6,500		(6,166)		334		0.8
Technology	125,110		(36,924)		88,186		10.7
Total	$	194,880	$	(92,935)	$	101,945

The Company abandoned its “E-Set” tools business and related $1.0 million in-process research and development indefinite-lived intangible asset in the fourth quarter of 2022.

Amortization of Intangibles

Amortization of intangibles was $11.5 million and $13.5 million for the years ended December 31, 2023 and 2022, respectively.

Future estimated amortization of intangibles is as follows:


Year Ending December 31,	(in thousands)
2024	$	11,183
2025	11,183
2026	11,082
2027	10,315
2028	8,000
Thereafter	38,666
	$	90,429

8. Accrued Expenses

Accrued expenses as of December 31, 2023 and 2022 consisted of the following:


	December 31,
	2023		2022
	(in thousands)
Accrued interest	$	17,216	$	5,012
Accrued compensation and benefits	9,784		10,283
Accrued bonus	1,169		3,979
Accrued legal fees and settlements	68		145
Other accrued expenses	7,934		8,972
Accrued expenses	$	36,171	$	28,391

F-19

9. Debt Obligations

The Company’s debt obligations as of December 31, 2023 and 2022 were as follows:


	December 31,
	2023		2022
	(in thousands)
2028 Notes	$	300,000	$	—
2023 Notes (1)	—		307,339
ABL Credit Facility (1)	57,000		32,000
Other short-term debt (2)	2,859		2,267
Total debt before deferred financing costs	$	359,859	$	341,606
Deferred financing costs	(36,480)		(1,308)
Total debt	$	323,379	$	340,298
Less: Current portion of long-term debt	(2,859)		(2,267)
Long-term debt	$	320,520	$	338,031

(1) Subsequent to December 31, 2022, the Company redeemed all of the outstanding 2023 Notes and extended the maturity date of the ABL Credit Facility from October 25, 2023 to January 29, 2027. As such, these obligations are classified as long-term on the Company’s Consolidated Balance Sheet at December 31, 2022. Refer to further disclosure within this footnote for additional information.

(2) The weighted average interest rate of short-term debt outstanding at December 31, 2023 and 2022, respectively, was 8.2% and 6.0%.

Units Offering and 2028 Notes

Units

On January 30, 2023, the Company completed its public offering of 300,000 units with an aggregate stated amount of $300.0 million (the “Units”). Each Unit consisted of $1,000 principal amount of the Company’s 13.000% Senior Secured Notes due 2028 (collectively, the “2028 Notes”) and five shares of common stock (the “Common Stock”) of the Company. The Company received proceeds of $279.8 million from the Units offering, after deducting underwriting discounts and commission, which was used to fund a portion of the redemption price of the 2023 Notes (as defined and described below). These proceeds were allocated to the 2028 Notes and the Common Stock based on their relative fair value at the time of issuance.

Each Unit separated into its constituent securities (the 2028 Notes and shares of Common Stock) automatically on October 27, 2023. A holder of Units could have elected to separate its Units into its constituent securities, in whole but not in part, on or after March 31, 2023. Prior to such date, the Units could not be separated at the option of the holder.

In the first quarter of 2023, the Company recorded approximately $41.7 million of deferred financing costs in connection with the Units offering. These costs are direct deductions from the carrying amount of the 2028 Notes and are being amortized through interest expense through the maturity date of the 2028 Notes using the effective interest method. The unamortized portion of these deferred financing costs was $36.5 million at December 31, 2023.

2028 Notes

On January 30, 2023, the Company and certain of its subsidiaries entered into an indenture, dated as of January 30, 2023 (the “2028 Notes Indenture”), with U.S. Bank Trust Company, National Association, as the trustee and as notes collateral agent, pursuant to which the 2028 Notes, which form a part of the Units, were issued. The 2028 Notes will mature on February 1, 2028 and bear interest at an annual rate of 13.000% payable in cash semi-annually in arrears on each of February 1 and August 1, commencing August 1, 2023. The 2028 Notes are senior secured obligations of the Company and are guaranteed on a senior secured basis by each of the Company’s current domestic subsidiaries and will be so guaranteed by certain future subsidiaries, in each case, subject to agreed guaranty and security principles and certain exclusions.

Prior to February 1, 2026, the Company may, on any one or more occasions, redeem all or a part of the 2028 Notes at a redemption price equal to 100.0% of the principal amount of the 2028 Notes redeemed, plus a “make-whole” premium, plus accrued and unpaid interest, if any, to, but excluding, the date of redemption. In addition, prior to February 1, 2026, the Company may, from time to time, redeem up to 35.0% of the aggregate principal amount of the 2028 Notes with an amount of

F-20

cash not greater than the net cash proceeds of certain equity offerings at a redemption price equal to 113.0% of the principal amount of the 2028 Notes redeemed, plus accrued and unpaid interest, if any, to, but excluding, the date of redemption, provided that at least 65.0% of the aggregate principal amount of the 2028 Notes originally issued under the 2028 Notes Indenture on January 30, 2023 remains outstanding immediately after such redemption and the redemption occurs within 180 days of the closing date of such equity offering. Also, prior to February 1, 2026, the Company may redeem during each 12-month period beginning on January 30, 2023, up to 10% of the aggregate principal amount of the 2028 Notes outstanding at a redemption price equal to 103.0% of the aggregate principal amount of the 2028 Notes being redeemed, plus accrued and unpaid interest, if any, to, but excluding, the date of redemption.

On and after February 1, 2026, the Company may redeem the 2028 Notes, in whole or in part, at the redemption prices (expressed as percentages of principal amount of the 2028 Notes to be redeemed) set forth below, plus accrued and unpaid interest, if any, to, but excluding the date of redemption, if redeemed during the periods indicated:


	Redemption Price
February 1, 2026 to January 31, 2027	106.500	%
February 1, 2027 to October 31, 2027	103.250	%
November 1, 2027 and thereafter	100.000	%

On each May 15 and November 14, commencing November 14, 2023 (each, an “Excess Cash Flow Offer Date”), the Company is required to make an offer (an “Excess Cash Flow Offer”) to all holders of the 2028 Notes and, if required by the terms of any Pari Passu Notes Lien Indebtedness (as defined in the 2028 Notes Indenture), to any holders of any Pari Passu Notes Lien Indebtedness to purchase, prepay or redeem, together on a pro-rata basis, the maximum principal amount of the 2028 Notes and any such Pari Passu Notes Lien Indebtedness (plus all accrued interest (including additional interest, if any) on the 2028 Notes and any such Pari Passu Notes Lien Indebtedness and the amount of all fees and expenses, including premiums, incurred in connection therewith) that may be purchased, prepaid or redeemed using an amount of cash equal to the Excess Cash Flow Amount (as defined in the 2028 Notes Indenture and which is 75.0% of Excess Cash Flow (as defined in the 2028 Notes Indenture), as determined immediately prior to the Excess Cash Flow Offer Date), if any, subject to certain exceptions set forth in the 2028 Notes Indenture. The offer price in any such offer will be equal to 100% of the principal amount of the 2028 Notes and any such Pari Passu Notes Lien Indebtedness (or, in respect of any such Pari Passu Notes Lien Indebtedness, such lesser price, if any, as may be provided for by the terms of such Pari Passu Notes Lien Indebtedness), plus accrued and unpaid interest and additional interest, if any, to, but excluding, the date of purchase, prepayment or redemption, subject to the rights of holders of the 2028 Notes or any such Pari Passu Notes Lien Indebtedness on the relevant record date to receive interest due on an interest payment date that is on or prior to the date of purchase, prepayment or redemption, and will be payable in cash.

If the Company experiences certain changes of control, each holder of 2028 Notes may require the Company to repurchase all or a portion of its 2028 Notes for cash at a price equal to 101.0% of the principal amount of such 2028 Notes, plus any accrued but unpaid interest, if any, to, but excluding, the date of repurchase.

The 2028 Notes Indenture contains covenants that, among other things and subject to certain exceptions and qualifications, limit the Company’s ability and the ability of its restricted subsidiaries to (i) incur additional indebtedness and guarantee indebtedness; (ii) pay dividends or make other distributions of capital stock; (iii) prepay, redeem or repurchase certain debt; (iv) issue certain preferred stock or similar equity securities, (v) make loans and investments; (vi) sell assets; (vii) incur liens; (viii) enter into transactions with affiliates; (ix) enter into agreements restricting its subsidiaries’ ability to pay dividends; or (x) consolidate, merge, or sell all or substantially all of its assets. The Company was in compliance with the provision of the 2028 Notes Indenture at December 31, 2023.

Upon an event of default, the trustee of the 2028 Notes or the holders of at least 25% in aggregate principal amount of then outstanding 2028 Notes may declare the 2028 Notes immediately due and payable, except that a default resulting from certain events of bankruptcy or insolvency with respect to the Company, any significant subsidiary or any group of restricted subsidiaries that, taken together, would constitute a significant subsidiary, will automatically cause all outstanding 2028 Notes to become due and payable.

2023 Notes

On October 25, 2018, the Company issued $400.0 million principal amount of 8.750% Senior Notes due 2023 (the “2023 Notes”). The 2023 Notes were issued under an indenture, dated as of October 25, 2018, by and among the Company, certain subsidiaries of the Company and Wells Fargo, National Association, as trustee. The 2023 Notes bore interest at an annual rate of 8.750% payable on May 1 and November 1 of each year, commencing May 1, 2019. The 2023 Notes were senior

F-21

unsecured obligations of the Company and were fully and unconditionally guaranteed on a senior unsecured basis by each of the Company’s domestic subsidiaries.

On February 1, 2023, with proceeds received from its public offering of Units and borrowings under its ABL Credit Facility (as defined and described below), the Company redeemed all of the outstanding 2023 Notes at a redemption price of 100.0% of outstanding principal amount thereof ($307.3 million), plus accrued and unpaid interest ($6.7 million). The Company also wrote off unamortized deferred financing costs in the amount of $1.2 million associated with the 2023 Notes in conjunction with the redemption.

ABL Credit Facility

On October 25, 2018, the Company entered into a credit agreement dated as of October 25, 2018 (the “2018 ABL Credit Agreement”), by and among the Company, Nine Energy Canada, Inc., JP Morgan Chase Bank, N.A., as administrative agent and as an issuing lender, and certain other financial institutions party thereto as lenders and issuing lenders. The 2018 ABL Credit Agreement permitted aggregate borrowings of up to $200.0 million, subject to a borrowing base, including a Canadian tranche with a sub-limit of up to $25.0 million and a sub-limit of $50.0 million for letters of credit (the “ABL Credit Facility”). Pursuant to the 2018 ABL Credit Agreement, the ABL Credit Facility was set to mature on October 25, 2023 or, if earlier, on the date that was 180 days before the scheduled maturity date of the 2023 Notes if they had not been redeemed or repurchased by such date.

Pursuant to the 2018 ABL Credit Agreement, loans to the Company and its domestic related subsidiaries (the “U.S. Credit Parties”) under the ABL Credit Facility were base rate loans or London Interbank Offered Rate (“LIBOR”) loans; and loans to Nine Energy Canada Inc., a corporation organized under the laws of Alberta, Canada, and its restricted subsidiaries (the “Canadian Credit Parties”) under the Canadian tranche were Canadian Dollar Offered Rate (“CDOR”) loans or Canadian prime rate loans. The applicable margin for base rate loans and Canadian prime rate loans varied from 0.75% to 1.25%, and the applicable margin for LIBOR loans or CDOR loans varied from 1.75% to 2.25%, in each case depending on the Company’s leverage ratio. In addition, a commitment fee of 0.50% per annum was charged on the average daily unused portion of the revolving commitments.

On January 17, 2023, the Company entered into the First Amendment to Credit Agreement (the “ABL Facility Amendment”) with JP Morgan Chase Bank, N.A., as administrative agent, and the lender parties thereto, which amends certain terms of the 2018 ABL Credit Agreement (as amended the “ABL Credit Agreement”). The ABL Facility Amendment became effective on January 30, 2023.

Pursuant to the ABL Facility Amendment, the maturity date of the ABL Credit Facility was extended from October 25, 2023 to January 29, 2027. In addition, the ABL Facility Amendment, among other changes, revised the terms of the ABL Credit Facility as follows: (a) decreased the size of the ABL Credit Facility from $200.0 million to $150.0 million, subject to the borrowing base (the “Loan Limit”), (b) changed the interest rate benchmark from LIBOR to Term Secured Overnight Financing Rate with a 10 basis point spread adjustment and increased pricing from the existing range of 1.75% to 2.25% to a range of 2.00% to 2.50%, in each case depending on the Company’s leverage ratio, (c) modified the financial covenant, enhanced reporting and cash dominion triggers in the ABL Credit Facility from the existing minimum availability threshold of the greater of $18.75 million and 12.5% of the Loan Limit to a minimum availability threshold of (i) $12.5 million from January 30, 2023 until May 31, 2023 and (ii) the greater of $17.5 million and 12.5% of the Loan Limit thereafter, (d) decreased the Canadian tranche sub-limit from $25.0 million to $5.0 million, (e) decreased the letter of credit sub-limit from $50.0 million to $10.0 million and (f) made satisfaction of the Payment Conditions (as defined in the ABL Facility Amendment) a condition to an Excess Cash Flow Offer in addition to a condition to voluntary payments of the 2028 Notes. The Payment Conditions in summary are (A) no default or event of default on a pro forma basis and (B) immediately after and at all times during the 30 days prior, on a pro forma basis, (1) (x) availability under the ABL Credit Facility shall not be less than the greater of 15% of the Loan Limit and $22.5 million and (y) the fixed charge coverage ratio shall be at least 1.00 to 1.00 or (2) availability under the ABL Credit Facility shall not be less than the greater of 20% of the Loan Limit and $30.0 million.

The ABL Credit Agreement contains various affirmative and negative covenants, including financial reporting requirements and limitations on indebtedness, liens, mergers, consolidations, liquidations and dissolutions, sales of assets, dividends and other restricted payments, investments (including acquisitions), and transactions with affiliates. In addition, the ABL Credit Agreement contains a financial covenant requiring a minimum fixed charge ratio of 1.00 to 1.00 that is tested quarterly when (a) the availability under the ABL Credit Facility drops below (i) at any time on or before May 31, 2023, $12.5 million and (ii) at any time thereafter, the greater of $17.5 million and 12.5% of the Loan Limit or (b) a default has occurred. This financial covenant applies until the availability exceeds the applicable threshold for 30 consecutive days and no default is ongoing. The Company was in compliance with all covenants under the ABL Credit Agreement as of December 31, 2023.

F-22

Pursuant to the ABL Credit Agreement, all of the obligations under the ABL Credit Facility are secured by security interests (subject to permitted liens) in substantially all of the personal property of U.S. Credit Parties, excluding certain assets. The obligations under the Canadian tranche are further secured by security interests (subject to permitted liens) in substantially all of the personal property of Canadian Credit Parties, excluding certain assets.

At December 31, 2023, the Company had $57.0 million outstanding borrowings under the ABL Credit Facility, and its availability under the ABL Credit Facility was approximately $28.1 million, net of outstanding letters of credit of $1.1 million. On February 14, 2024, the Company repaid approximately $5.0 million of its outstanding borrowings under the ABL Credit Facility.

Magnum Promissory Notes

On October 25, 2018, pursuant to the terms of a Securities Purchase Agreement, dated October 15, 2018 (as amended on June 7, 2019, the “Magnum Purchase Agreement”), the Company acquired all of the equity interests of Magnum Oil Tools International, LTD, Magnum Oil Tools GP, LLC, and Magnum Oil Tools Canada Ltd. (such entities collectively, “Magnum”). The Magnum Purchase Agreement included the potential for additional future payments in cash of (i) up to 60% of net income (before interest, taxes, and certain gains or losses) for the “E-Set” tools business in 2019 through 2026 and (ii) up to $25.0 million based on sales of certain dissolvable plug products in 2019 (the “Magnum Earnout”).

On June 30, 2020, pursuant to an amendment to the Magnum Purchase Agreement to terminate the remaining Magnum Earnout and all obligations related thereto, the Company issued promissory notes with an aggregate principal amount of $2.3 million (the “Magnum Promissory Notes”) to the sellers of Magnum. The Magnum Promissory Notes bore interest at a rate of 6.0% per annum. The principal amount of the Magnum Promissory Notes was paid in equal quarterly installments which began January 1, 2021. The remaining outstanding balance was paid on October 1, 2022.

Other Short-Term Debt

From time to time, the Company renews certain insurance policies and finances the premium for its excess policy. The outstanding balance on these premiums was $2.9 million and $2.3 million at December 31, 2023 and 2022, respectively.

Fair Value of Debt Instruments

The estimated fair value of the Company’s debt obligations as of December 31, 2023 and 2022 was as follows:


	December 31,
	2023		2022
	(in thousands)
2028 Notes	$	264,750	$	—
2023 Notes	$	—	$	300,700
ABL Credit Facility	$	57,000	$	32,000
Other short-term debt	$	2,859	$	2,267

The fair value of the 2028 Notes, 2023 Notes, ABL Credit Facility, and other short-term debt is classified as Level 2 in the fair value hierarchy. The fair value of the 2028 Notes and the 2023 Notes is established based on observable inputs in less active markets. The fair value of the ABL Credit Facility and other short-term debt approximates their carrying value.

10. Defined Contribution Plans

Background

The Company sponsors a defined contribution plan, the Nine Energy Service 401(k) Plan (the “Nine Plan”), under Section 401(k) of the Internal Revenue Code of 1986, as amended, for all qualified employees.

During the year ended December 31, 2022, the Company did not match employee contributions.

Effective January 1, 2023, employee contributions were matched by the Company at 100% of the first 3% and 50% of the remaining up to 5% of the participant’s eligible compensation.

F-23

Contributions

For the year ended December 31, 2023, the Company made employer contributions of $2.0 million under the Nine Plan.

For the year ended December 31, 2022, the Company made no employer contributions under the Nine Plan.

11. Stock-based Compensation

Stock Options

Information about stock option activity during the years ended December 31, 2023 and 2022 was as follows:


2023 Activity	Number of Shares in Underlying Options	Weighted Average Exercise Price		Remaining Weighted Average Contractual Life in Years	Intrinsic Value
					(in thousands)
Beginning balance	587,506	$	33.80	3.0	$	—
Granted	—	—		—	—
Exercised	—	—		—	—
Forfeited	—	—		—	—
Expired	(52,015)	26.50		—	—
Total outstanding	535,491	$	34.51	2.2	$	—
Options exercisable	535,491	$	34.51	2.2	$	—


2022 Activity	Number of Shares in Underlying Options	Weighted Average Exercise Price		Remaining Weighted Average Contractual Life in Years	Intrinsic Value
					(in thousands)
Beginning balance	610,410	$	33.52	3.9	$	—
Granted	—	—		—	—
Exercised	—	—		—	—
Forfeited	—	—		—	—
Expired	(22,904)	26.28		—	—
Total outstanding	587,506	$	33.80	3.0	$	—
Options exercisable	587,506	$	33.80	3.0	$	—

The intrinsic value at December 31, 2023 and 2022 is the amount by which the fair value of the underlying share exceeds the exercise price of an option as of December 31, 2023 and 2022, respectively.

The Company granted no options in 2023 and 2022.

There was no compensation expense recorded for the years ended December 31, 2023 and 2022. As of December 31, 2023, there is no remaining compensation expense related to options for the Company to expense. Future stock option grants will result in additional compensation expense.

F-24

Restricted Stock and Restricted Stock Units

Information about restricted stock and restricted stock unit activity during the years ended December 31, 2023 and 2022 was as follows:


2023 Activity	Number of Shares and Units	Weighted Average Grant Date Fair Value
Nonvested at January 1, 2023	1,934,556	$	2.12
Granted	662,845	3.51
Vested	(1,063,090)	1.85
Forfeited	(59,767)	2.63
Nonvested at December 31, 2023	1,474,544	$	2.92


2022 Activity	Number of Shares and Units	Weighted Average Grant Date Fair Value
Nonvested at January 1, 2022	2,379,320	$	2.83
Granted	651,250	2.80
Vested	(1,068,092)	4.13
Forfeited	(27,922)	2.02
Nonvested at December 31, 2022	1,934,556	$	2.12

The total amount of compensation expense related to the restricted stock and restricted stock units recorded was approximately $2.2 million and $2.4 million for the years ended December 31, 2023 and 2022, respectively. As of December 31, 2023, the Company expects to record compensation expense related to restricted stock and restricted stock units of approximately $3.0 million over the remaining term of approximately 1.8 years. Future restricted stock and restricted stock unit grants would result in additional compensation expense.

Performance Cash Awards

In May 2022 and May 2023, the Company granted performance cash awards (the “PCAs”) that vest based upon the Company’s achievement of certain criteria related to its relative total shareholder return (“TSR”) in comparison to TSR of members of its peer group (the “Peer Group”), as defined by the PCA grant. These awards, which the Company granted at a target achievement amount, are subject to three individual year-long performance periods (the “Performance Periods”), and payment related to each Performance Period can range from 0% to 200% of the target amount for that Performance Period.

The PCAs were valued on the date of grant based on the estimated fair value, which was based on numerous assumptions including the likelihood of the Company’s stock price performance achieving targeted thresholds, using a Monte Carlo simulation model. The assumptions used to value the awards included the historical volatility of the Company as well as the volatility of its Peer Group and the risk-free rate, which was derived using the U.S. Treasury security rates.

Under the relevant liability accounting, the Level 3 fair values for each tranche of the PCAs are remeasured at the end of each reporting period and was $2.0 million and $3.4 million at December 31, 2023 and 2022, respectively.

The following information is related to the Company’s May 2023 grant of PCAs at December 31, 2023.


	December 31, 2023
Volatility for remeasurement	118.62	%
Risk-free rate	4.11	%

F-25

The following information is related to the Company’s May 2022 grant of PCAs at December 31, 2023 and December 31, 2022.


	December 31, 2023		December 31, 2022
Volatility for remeasurement	98.16	%	123.82	%
Risk-free rate	4.55	%	4.30	%

Expense related to performance cash was $1.3 million and $1.8 million for the years ended December 31, 2023 and 2022, respectively. As of December 31, 2023, there was $1.1 million of remaining compensation expense related to performance cash for the Company to expense. Future PCA grants will result in additional compensation expense.

12. Commitments and Contingencies

Litigation

The Company records accruals related to litigation and other legal proceedings when they are either known or considered probable and can be reasonably estimated. Legal proceedings are inherently unpredictable and subject to significant uncertainties, and significant judgment is required to determine both probability and the estimated amount. Some of these uncertainties include the stage of litigation, available facts, uncertainty as to the outcome of any legal proceedings or settlement discussions, and any novel legal issues presented. Because of such uncertainties, accruals are based on the best information available at the time. As additional information becomes available, the Company reassesses the potential liability related to pending litigation. As of both December 31, 2023 and 2022, the Company recorded a $0.1 million accrual for liabilities related to legal matters, which is included under the caption “Accrued expenses” in its Consolidated Balance Sheets.

From time to time, the Company has various claims, lawsuits, and administrative proceedings that are pending or threatened with respect to personal injury, workers’ compensation, contractual matters, and other matters. Although no assurance can be given with respect to the outcome of these claims, lawsuits, or proceedings or the effect such outcomes may have, the Company believes any ultimate liability resulting from the outcome of such claims, lawsuits, or administrative proceedings, to the extent not otherwise provided for or covered by insurance, will not have a material adverse effect on its business, operating results, or financial condition.

Self-insurance

The Company uses a combination of third-party insurance and self-insurance for health insurance claims. The self-insured liability represents an estimate of the undiscounted ultimate cost of uninsured claims incurred as of the balance sheet date. The estimate is based on an analysis of trailing months of incurred medical claims to project the amount of incurred but not reported claims liability. The estimated liability for self-insured medical claims was $1.6 million and $1.2 million at December 31, 2023 and 2022, respectively, and is included under the caption “Accrued expenses” on the Company’s Consolidated Balance Sheets.

Although the Company does not expect the amounts ultimately paid to differ significantly from the estimates, the self-insurance liability could be affected if future claims experience differs significantly from historical trends and actuarial assumptions.

Contingent Liabilities

On October 1, 2018, pursuant to the terms and conditions of a Securities Purchase Agreement (“the Frac Tech Purchase Agreement”), the Company acquired Frac Technology AS, a Norwegian private limited company (“Frac Tech”) focused on the development of downhole technology, including a casing flotation tool and a number of patented downhole completion tools. The Frac Tech Purchase Agreement, as amended, includes, among other things, the potential for additional future payments, based on certain Frac Tech revenue metrics through December 31, 2025.

F-26

The Company’s contingent liability (Level 3) for the years ended December 31, 2023 and 2022 was as follows:


	Frac Tech
	(in thousands)
Balance at December 31, 2021	$	910
Payments	(195)
Revaluation adjustments	454
Balance at December 31, 2022	$	1,169
Payments	(387)
Revaluation adjustments	437
Balance at December 31, 2023	$	1,219

All contingent liabilities that relate to contingent consideration are reported at fair value, based on a Monte Carlo simulation model. Significant inputs used in the fair value measurement include forecasted sales of the plugs, terms of the agreement, a risk-adjusted discount factor (ranging from 4.5% to 5.7%), and a credit-adjusted rate (ranging from 11.5% to 11.6%). Contingent liabilities include $0.8 million and $0.4 million reported in “Accrued expenses” at December 31, 2023 and 2022, respectively, and $0.4 million and $0.8 million reported in “Other long-term liabilities” at December 31, 2023 and 2022, respectively, in the Company’s Consolidated Balance Sheets. The impact of the revaluation adjustments is included in the Company’s Consolidated Statements of Income and Comprehensive Income (Loss).

13. Taxes

The components of the provision (benefit) for income taxes for the years ended December 31, 2023 and 2022 were as follows:


	Year Ended December 31,
	2023		2022
	(in thousands)
Current
U.S. federal	$	—	$	—
U.S. state	502		510
Foreign	83		36
Total current provision	$	585	$	546
Deferred
U.S. federal	$	—	$	—
U.S. state	—		—
Foreign	—		—
Total deferred provision (benefit)	—		—
Total provision for income taxes	$	585	$	546

F-27

The provision (benefit) for income taxes for the years ended December 31, 2023 and 2022 differed from the provision (benefit) calculated using the applicable statutory federal income tax rate as follows:


	Year Ended December 31,
	2023		2022
	(in thousands)
Tax provision (benefit) at statutory rate	$	(6,642)	$	3,137
Foreign rate differential	(7)		(16)
State income taxes, net of federal benefit	397		403
Nondeductible expenses	2,137		912
Valuation allowance	5,158		(5,823)
Non-cash compensation	(515)		1,879
Other	57		54
Total provision for income taxes	$	585	$	546

The tax effects of the cumulative temporary differences resulting in the net deferred tax asset (liabilities) at December 31, 2023 and 2022 were as follows:


	December 31,
	2023		2022
	(in thousands)
Deferred income tax assets:
Inventories	$	1,931	$	2,298
Goodwill and intangible assets	67,860		75,617
Deferred tax benefit from net losses	85,708		79,914
Stock-based compensation and cash award expense	2,260		2,524
Tax credit carryforwards	660		655
Accrued expenses	872		678
Interest carryover	20,814		13,860
Lease liability	9,757		8,441
Other	489		163
Total deferred income tax assets	190,351		184,150
Less: Valuation allowance	(168,034)		(162,888)
Net deferred income tax assets	$	22,317	$	21,262
Deferred income tax liabilities:
Property and equipment	$	(12,745)	$	(12,974)
ROU asset	(9,572)		(8,288)
Total deferred income tax liabilities	(22,317)		(21,262)
Net deferred income tax asset (liability)	$	—	$	—

As of December 31, 2023, the Company had federal and state net operating loss carryforwards (“NOLs”) of approximately $471.8 million. The federal NOLs related to tax years 2017 and prior can be used for a 20-year period and, if unused, will begin to expire in 2034. The state NOLs can be used from 7 to 20 years and vary by state. A small portion of state NOLs expired in 2023.

The Company evaluates its deferred tax assets on a quarterly basis to determine whether a valuation allowance is required. The Company assesses whether a valuation allowance should be established based on its determination of whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible and prior to the expiration of its NOL and tax credit carryforwards. The Company considers the scheduled reversal of deferred tax liabilities, projected future taxable income, and tax planning strategies in making this assessment. Due to recent operating results, the Company continues to be in a three-year cumulative loss position for the year ended December 31, 2023. According to ASC 740, cumulative losses in recent years represent significant negative evidence in

F-28

considering whether deferred tax assets are realizable. As a result, the Company continues to record a valuation allowance against its U.S. domestic and Canadian deferred tax assets. The 2023 results include an increase in the Company’s valuation allowance of approximately $5.1 million. If the Company is able to generate sufficient taxable income in the future, and it becomes more likely than not that the Company will be able to fully utilize the net deferred tax assets on which a valuation allowance was recorded, the allowance will be released resulting in a tax benefit.

The Company is subject to U.S. federal income tax as well as income tax in multiple state jurisdictions. The earliest period the Company is subject to examination of federal income tax returns by the Internal Revenue Service is 2020. The state income tax returns and other state tax filings of the Company are subject to examination by the state taxing authorities for various periods, generally up to four years after they are filed.

The Company accounts for uncertain tax positions in accordance with guidance in ASC 740, which prescribes the minimum recognition threshold a tax position taken or expected to be taken in a tax return is required to meet before being recognized in the financial statements. A reconciliation of the beginning and ending amount of uncertain tax positions is as follows:


	2023
	(in thousands)
Balance at January 1,	$	779
Change in prior year tax positions	(235)
Change in current year tax positions	—
Cash settlements with taxing authorities	—
Lapse of statute of limitations	—
Balance at December 31,	$	544

The total amount of unrecognized tax benefits at December 31, 2023 was $0.5 million. The total balance of unrecognized tax benefit would impact the Company’s future effective income tax rate if recognized. During 2023, the Company released approximately $0.2 million of the unrecognized tax benefit due to a decrease in federal refund expected from a prior year. The Company recognizes interest and penalties related to uncertain tax positions within the provision for income taxes in its Consolidated Statements of Income and Comprehensive Income (Loss). As of December 31, 2023, no interest and penalties have been accrued.

14. Earnings (Loss) Per Share

Basic earnings (loss) per share is computed by dividing net income (loss) by the weighted average number of shares of Common Stock outstanding for the period. Diluted earnings (loss) per share is based on the weighted average number of shares outstanding during each period and the exercise of potentially dilutive stock options assumed to be purchased from the proceeds using the average market price of the Common Stock for each of the periods presented as well as the potentially dilutive restricted stock, restricted stock units, and performance stock units.

Basic and diluted earnings (loss) per share of Common Stock was computed as follows:


	Year Ended December 31, 2023
	Net Loss		Average Shares Outstanding	Loss Per Share
	(in thousands, except for share and per share amounts)
Basic	$	(32,213)	33,282,234	$	(0.97)
Unvested restricted stock and stock units	—		—	—
Diluted	$	(32,213)	33,282,234	$	(0.97)


	Year Ended December 31, 2022
	Net Income		Average Shares Outstanding	Earnings Per Share
	(in thousands, except for share and per share amounts)
Basic	$	14,393	30,930,890	$	0.47
Unvested restricted stock and stock units	—		1,320,508	—
Diluted	$	14,393	32,251,398	$	0.45

F-29

The diluted earnings (loss) per share calculation excludes all stock options, unvested restricted stock, unvested restricted stock units, and unvested performance stock units for 2023 because there is a net loss for the period, and their inclusion would be anti-dilutive. The average number of securities that were excluded from diluted earnings (loss) per share that would potentially dilute earnings (loss) per share for the period in which the Company experienced a net loss was as follows:


			2023
Year ended December 31,			1,113,033

15. Related Party Transactions

The Company leases office space, yard facilities, and equipment and purchases building maintenance and repair services from entities owned by David Crombie, an executive officer of the Company. Total lease expense and building maintenance and repair expense associated with these entities was $1.3 million for both the years ended December 31, 2023 and 2022. The Company also purchased $2.9 million and $2.6 million of products and services for the years ended December 31, 2023 and 2022, respectively, from an entity in which Mr. Crombie is a limited partner. There were outstanding payables due to these entities of $0.2 million and $0.1 million at December 31, 2023 and 2022, respectively.

In addition, the Company completed leasing office space in Corpus Christi, Texas at the end of 2023 and previously leased office space in Midland, Texas from an entity (the “Leasing Entity”) affiliated with Warren Lynn Frazier, a beneficial owner of more than 5% of the Common Stock. From the third quarter of 2020 through mid-2022, another entity affiliated with Mr. Frazier sub-leased a portion of such space in Corpus Christi, Texas from the Company. Total rental expense associated with these office spaces, net of sub-leasing income, was $1.2 million and $1.6 million for the years ended December 31, 2023 and 2022, respectively. There were no net outstanding payables due to the Leasing Entity at December 31, 2023 and $0.1 million of net outstanding payables at December 31, 2022. Additionally, on June 30, 2020, the Company issued the Magnum Promissory Notes to the sellers of Magnum, including Mr. Frazier. At December 31, 2023, there was no outstanding principal balance payable to Mr. Frazier as the balance payable to Mr. Frazier of $1.1 million at December 31, 2021 was paid during 2022. For additional information regarding the Magnum Promissory Notes, see Note 9 – Debt Obligations.

The Company provides products and rentals to National Energy Reunited Corp. (“NESR”), where one of the Company’s directors serves as a director. The Company billed NESR $1.5 million and $0.8 million for the years ended December 31, 2023 and 2022, respectively. Total outstanding receivables due to the Company from NESR were $0.4 million and $0.2 million at December 31, 2023 and 2022, respectively.

Ann G. Fox, President and Chief Executive Officer and a director of the Company, is a director of Devon Energy Corporation (“Devon”). The Company generated revenue from Devon of $3.0 million and $2.2 million for the years ended December 31, 2023 and 2022, respectively. There were outstanding receivables due from Devon of $0.7 million and $0.5 million at December 31, 2023 and 2022, respectively.

16. Other Supplemental Information

Total Assets by Segment

Total assets by segment as of December 31, 2023 and 2022 were as follows:


	December 31,
	2023		2022
	(in thousands)
Completion Solutions	$	359,205	$	399,546
Corporate	42,779		27,288
	$	401,984	$	426,834

F-30

Long-lived Assets by Country

Long-lived assets (defined as property and equipment and definite-lived intangible assets) by country as of December 31, 2023 and 2022 were as follows:


	December 31,
	2023		2022
	(in thousands)
United States	$	171,453	$	189,962
Canada and other	1,342		1,700
	$	172,795	$	191,662

ATM Program

On November 6, 2023, the Company entered into an equity distribution agreement (the “Equity Distribution Agreement”) with Piper Sandler & Co. (the “Agent”). Pursuant to the Equity Distribution Agreement, the Company may, from time to time, sell shares of Common Stock having an aggregate offering price of up to $30.0 million through the Agent acting as the Company’s sales agent. The Agent will receive a commission equal to 3.0% of the gross sale price of any shares sold under the Equity Distribution Agreement. Under the Equity Distribution Agreement, the Company will set the parameters for the sale of the shares thereunder, including the number of shares to be sold, the time period during which sales are requested to be made and any price below which sales may not be made. During the quarter ended December 31, 2023, no sales were made under the Equity Distribution Agreement.

F-31

Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure

None.

Item 9A. Controls and Procedures

Evaluation of Disclosure Controls and Procedures

Disclosure controls and procedures are controls and other procedures of an issuer that are designed to ensure that information required to be disclosed by the issuer in the reports that it files or submits under the Exchange Act is recorded, processed, summarized, and reported within the time periods specified in the SEC’s rules and forms. Disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that information required to be disclosed by an issuer in the reports that it files or submits under the Exchange Act is accumulated and communicated to the issuer’s management, including its principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosure.

As required by Rule 13a-15(b) under the Exchange Act, our management, with the participation of our principal executive officer and principal financial officer, has evaluated the effectiveness of our disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) as of December 31, 2023. Based upon that evaluation, our principal executive officer and principal financial officer concluded that our disclosure controls and procedures were effective as of December 31, 2023.

Management’s Report on Internal Control Over Financial Reporting

Our management is responsible for establishing and maintaining adequate internal control over financial reporting (as defined in Rule 13a-15(f) and Rule 15d-15(f) under the Exchange Act). Our internal control over financial reporting is a process designed by, or under the supervision of, our principal executive officer and principal financial officer, and effected by our board of directors, management, and other personnel, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of our financial statements for external purposes in accordance with GAAP.

As of December 31, 2023, our management assessed the effectiveness of our internal control over financial reporting based on the criteria established by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”) in Internal Control – Integrated Framework (2013). Based on its assessment using the criteria established by COSO, management has concluded that our internal control over financial reporting was effective as of December 31, 2023.

The effectiveness of our internal control over financial reporting as of December 31, 2023 has been audited by PricewaterhouseCoopers LLP, an independent registered public accounting firm, as stated in their report which appears on page F-1 of this Annual Report and which is included in Item 8 of Part II of this Annual Report.

Changes in Internal Control over Financial Reporting

There have been no changes in our internal control over financial reporting during the quarterly period ended December 31, 2023 that materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

Item 9B. Other Information

None.

Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections

Not applicable.

PART III

Item 10. Directors, Executive Officers and Corporate Governance