EDGAR 10-K Filing

Company CIK: 1084991
Filing Year: 2025
Filename: 1084991_10-K_2025_0001084991-25-000024.json

---

ITEM 1. BUSINESS
ITEM 1. BUSINESS
Unless the context otherwise requires, references in this Annual Report on Form 10-K to “Natural Gas Services Group,” the “Company,” “NGS,” “we,” “us,” or “our” refer to Natural Gas Services Group, Inc. and its consolidated subsidiary, NGSG Properties, LLC. Certain specialized terms used in describing our natural gas compressor business are defined in “Glossary of Industry Terms” on page ii.
Description of Business
We were incorporated in December 1998 and initially operated as a holding company of a group of subsidiaries that were engaged in the manufacturing, operation and leasing of natural gas compression equipment, flares and related assets to the natural gas industry with a focus on unconventional natural gas production plays in the U.S. (such as coalbed methane, gas shales and tight gas). We completed our initial public offering in October 2002 and our common stock began trading on the American Stock Exchange under the symbol “NGS.” In October 2008, our common stock began trading on the New York Stock Exchange.
Today, we are a premier provider of natural gas compression equipment and services to the energy industry. We rent, operate and maintain natural gas compressors for oil and gas production and processing facilities. In addition, we design and assemble compressor units for rental to our customers. We also provide aftermarket services in the form of call-out services on customer-owned equipment as well as commissioning of new units for customers. We are headquartered in Midland, Texas, with an assembly facility located in Tulsa, Oklahoma and service facilities located in several major oil and gas producing basins in the U.S.
Our primary business and source of revenue and gross profit is derived from the rental of natural gas compressor units for applications associated with oil and gas production with a focus on large and medium horsepower applications. Our customers, specifically for large and medium horsepower units, are exploration and production (“E&P”) companies that utilize our compressor units for artificial lift, or “gas lift,” applications (i.e., production enhancement enabled with high-pressure gas compression equipment) in unconventional oil wells on single and multi-well pads. In addition, our customer base includes oil and gas E&P companies that focus primarily on natural gas production (with typically smaller horsepower applications). Our largest rental area is the Permian Basin (75 percent of rental revenues in 2024), with the majority of our remaining rental revenue generated in other oil and gas producing regions and basins in Texas, New Mexico and Oklahoma, including the San Juan Basin, the Texas Panhandle/western Oklahoma, the Barnett Shale, the Eagle Ford Shale and central Oklahoma. Other regions and plays in which we provide services include the Utica and Marcellus Shales in Ohio, and the Antrim Shale in Michigan.
Recent Developments
For the past several years, we have been undergoing a deliberate and strategic shift by (i) focusing our business development efforts on expanding our rental revenue sources primarily in large (400 horsepower or greater) compressor units and crude oil artificial lift applications and (ii) de-emphasizing internal assembly of compressor units and the related support of extensive facilities associated with such activities.
Regarding the shift in revenue sourcing, we are continuing to invest in our larger compression units (400 horsepower or greater) which provide for greater revenues and more scalable costs resulting in higher overall profitability. In addition, the emphasis on the larger units is consistent with a focus on supporting our customers’ crude oil production efforts primarily through artificial lift applications which generally require larger units as opposed to natural gas production which generally requires our low and medium compression units. Due primarily to more favorable pricing for crude oil production vis-à-vis natural gas, our customers are continuing to dedicate their investments in favor of crude oil production which supports a growing demand for our larger horsepower units and services.
With respect to our assembly of compressor units for lease or sale to our customers, we have been transitioning from assembling a majority of our compressor units in-house to contracting with third-party fabricators who assemble the units to our specifications, utilizing parts and components from OEM. We continue to design and engineer our compressors and under this arrangement, we procure and pay for the components of our compressor packages which are delivered to one of our third-party fabricators, who then assemble the components and test the compressor units prior to our receiving them. During the assembly process, we hold title to the compressors and related components.
In connection with the transition to third-party fabrication, we initiated the termination of fabrication and assembly activities at our Midland, Texas facility during the fourth quarter of 2023 and began to wind down activities throughout 2024. On January 28, 2025, we announced our intent to close this facility and cease operations by April 1, 2025. In addition, we have initiated efforts to market the facility and the underlying real property. In connection with this action, we have transferred all inventory from this facility to our regional district locations and our Tulsa, Oklahoma facility. We continue to maintain new unit assembly capability at our Tulsa, Oklahoma facility.
We are committed to this transition for a number of reasons, including (i) we feel that the cost advantage of fabricating and assembling new units at the Midland facility has declined substantially in recent years; (ii) our assembly facilities are not capable of producing large horsepower units as efficiently as certain third-party service providers; (iii) third-party service providers have improved in quality and cost competitiveness; and (iv) use of third-party fabricators relieves us of issues related to efficiency, inventory and labor scarcity.
Please see Part II, Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” for further information regarding our operations.
Our Operating Units
We identify our operating units based upon major revenue sources as (i) Rental, (ii) Sales and (iii) Aftermarket Services.
Rental. Our rental compression units provide large, medium and small horsepower applications for conventional and unconventional oil and gas production. Our rental contracts generally provide for initial terms ranging from six to 60 months and generally extend on a month-to-month basis thereafter. We believe that, by outsourcing their compression needs, our customers are able to increase their revenues by producing higher volumes of oil and gas due to higher equipment run time, decrease their operating and maintenance cost of operating compression, lower their capital investment needs and more efficiently meet their changing compression needs. We maintain and service all of the compression equipment that we rent to our customers.
The size, type and geographic dispersion of our rental fleet enables us to provide our customers with a range of compression units that can serve a wide variety of applications, and to select the correct equipment for the job, rather than the customer trying to fit the job to its own equipment. We base our compressor rental rates on several factors, including the cost and size of the equipment, the type and complexity of service desired by the customer, the length of contract and the inclusion of any other services desired, such as installation, transportation and daily operation.
As of December 31, 2024, we had 1,912 natural gas compressors in our rental fleet totaling 598,840 horsepower. Of this total, we had 1,208 natural gas compressors totaling 491,756 horsepower rented to 68 customers. The unit utilization rate of our rental fleet as of December 31, 2024, was 63.2 percent, while our horsepower utilization for the same period was 82.1 percent. During 2024, we placed into service 220 unit sets, including 198 from our existing fleet and 22 new units, with a total of 154,909 horsepower. A total of 111 of those units, including 22 new units, were 400 horsepower or larger, representing approximately 87.4 percent of the total horsepower set. This activity resulted in a 360 basis point increase in our average annual horsepower utilization from 78.2 percent during to 81.8 percent for 2024.
Sales. We design and assemble compressor components manufactured by OEM suppliers, as well as certain proprietary compressor frames and cylinders into compressor units that are ready for rental or sale. In order to provide customer support for our compressor sales business, we also stock varying levels of replacement parts at our Tulsa, Oklahoma facility and our field service locations. We also provide an exchange and rebuild program for small horsepower screw compressors and maintain an inventory of new and used compressors to facilitate this part of our business.
Aftermarket Services. We service and maintain compressors owned by our customers on an “as needed” and contract basis, as well as providing services related to the installation and start-up of new compressor units. We perform engine and compressor overhauls on a condition-based interval or a time-based schedule or at our customers’ request.
Business Strategy
Our long-term intentions to grow our revenue and profitability are based on the following business strategies:
•Optimize existing utilized fleet. We believe there are opportunities to modestly improve the profitability of our existing utilized rental fleet through targeted price increases, particularly in geographic areas that have experienced high rates of cost inflation, along with operational efficiencies by using improved data collection and analysis to optimize our labor, parts, and maintenance costs.
•Improve asset utilization. We believe we can improve the overall cash flow of the business by increasing utilization of the existing fleet as well as monetizing non-cash assets. We have a significant number of unutilized units-we will review these assets to determine where relatively low-cost capital expenditures can improve the marketability and cash flow potential of the units. We also have a significant amount of capital tied up in non-cash assets (including accounts receivable, inventory and other fixed assets, primarily real property) that we believe can be monetized and invested back in the fleet at or above target levels of return on invested capital.
•Expand rental fleet. We intend to prudently increase the size of our rental fleet mainly through pre-contracted agreements with our customers. We believe our future growth in this part of our strategy will be primarily driven through our placement of larger horsepower, centralized wellhead natural gas compressors for unconventional oil production, with select increases in medium horsepower units to meet customer demand beyond our inventory.
•Execute accretive mergers and acquisitions. We believe there are opportunities in mergers with or acquisitions of competitive rental compression companies or related businesses providing similar services. While there is no certainty as to the probability of any particular deal, we will continue to evaluate potential acquisitions, joint ventures and other opportunities that could enhance value for our shareholders.
All of the above strategies are subject to revisions and adjustments as a result of several factors discussed in Item 1A. “Risk Factors.”
Competitive Strengths
We believe our competitive strengths include:
•Strong operational performance. We deliver very high levels of mechanical availability to our customers. Mechanical availability is defined as the percentage of time that our units are capable of operating as designed and is a measure of reliability. The cost of rental compression is an appreciable operating expense for a producer and the improved productivity delivers material incremental profitability to customers. This creates significant value for our customers and we believe our high levels of mechanical availability, particularly for our large horsepower rental compression units, is a competitive differentiator for customers selecting our units.
•Innovative rental compression units. We have made a series of technical innovations to our rental compression units that have improved operational performance while also reducing the environmental impact, largely related to the volume of fugitive emissions. Environmental considerations have increased in importance for our customers, particularly with recent environmental regulations and taxation, most notably the Methane Emissions Reduction Program. We use “eComp” technology with existing equipment to reduce emissions through vent capture and electronic valving. Our use of proprietary System Management and Recovery Technology (“SMART”) on our compressor units reduces unplanned shutdowns and increases productivity and our new equipment includes telemetry software to meet customer demands for operational data to analyze and streamline production. We believe the superior operating and environmental performance of our natural gas engine and electric-drive units, particularly our large horsepower units, is a significant competitive differentiator.
•Long-standing customer relationships. We have developed long-standing relationships providing compression equipment to many major and independent oil and gas companies. Our customers generally continue to rent our compressors after the expiration of the initial terms of our rental agreements, which we believe reflects their satisfaction with the reliability and performance of our services and products.
•High level of customer service. Our ability to provide a broad range of compressors has enabled us to effectively meet the evolving needs of our customers. We believe this ability, coupled with our personalized services and in-depth knowledge of our customers’ operating needs and growth plans, have allowed us to enhance our relationships with existing customers as well as attract new customers. The size, type and geographic diversity of our rental fleet enable us to provide customers with a range of compression units that can serve a wide variety of applications. We are able to select the correct equipment for the job, rather than the customer trying to fit its application to our equipment.
•Availability of new units. The rental compression industry has undergone significant change over the last several years. Capital constraints, in the form of reduced debt availability, higher interest rates, and shareholder demands for return of capital, have forced capital discipline upon the industry. These factors, along with supply chain challenges, led to a dearth of available rental compression units at a time of solid customer demand. Our strong balance sheet allowed us to strategically gain market share with desirable customers renting large horsepower units on pre-contracted basis. We believe our relatively modest leverage remains a strategic advantage for us to continue to gain market share on attractive terms for shareholder return.
Industry Overview and Outlook
The oil and gas industry has historically been cyclical and production levels of oil and gas are dependent upon numerous factors. The market for compression equipment and services is highly dependent on the production levels and pricing of oil and gas.
Crude Oil. The level of production for crude oil and capital expenditures activity has generally been dependent upon the prevailing view of future crude oil prices, which are influenced by numerous supply and demand factors, including availability and cost of capital, well productivity and development costs, global and domestic economic conditions, environmental regulations, policies of OPEC and Russia, and other factors. We feel that the current crude oil market production outlook is favorable, with current prices creating strong incentives for our customers to maximize their production levels. While crude oil prices have historically been volatile, we expect demand for our existing compressor fleet to remain positive assuming crude oil prices remain within reasonable bands with respect to current pricing levels.
Natural Gas. We believe the market outlook for natural gas production in the U.S. remains steady while short term price volatility remains a factor due to geopolitical influences and shifts in LNG exports. We believe opportunities for increased utilization of our small and medium horsepower units are supported by continued investment in shale gas development, particularly in the Permian basin and Marcellus Shale.
We will continue to evaluate our business and operating strategy and we will continue to remain prudent in both our allocation of capital and our capital structure. Nevertheless, if any of these circumstances change significantly, our business could be adversely affected. Please read Item 1A., “Risk Factors,” in this report.
Major Customers
Rental and sales activity with Occidental Permian, LTD. (“Oxy”) for the years ended December 31, 2024, 2023 and 2022 amounted to 54 percent, 50 percent and 42 percent of our revenue, respectively. No other single customer accounted for more than 10 percent of our revenues in 2024, 2023 or 2022. We do anticipate diversification of our revenue concentration during 2025 in connection with commitments we are currently processing with certain other large E&P customers. This development will likely reduce our revenue concentration attributable to Oxy.
Oxy amounted to 52 percent of our accounts receivable as of December 31, 2024, and 64 percent of our accounts receivable as of December 31, 2023. No other customers amounted to more than 10 percent of our accounts receivable as of December 31, 2024 or 2023. The loss of this key customer would have a material adverse effect on our business, results of operations, financial condition and cash flows, depending upon the demand for our compressors at the time of such loss and our ability to attract new customers.
Sales and Marketing
Our sales force pursues the rental and sales market for compressors and other services in their respective territories. Additionally, our personnel coordinate with each other to develop relationships with customers who operate in multiple regions. Our sales and marketing strategy is focused on communication with current customers and potential customers through frequent direct contact, technical assistance, print literature, direct mail and referrals. Our sales and marketing personnel coordinate with our operations personnel in order to promptly respond to and address customer needs. Our overall sales and marketing efforts concentrate on demonstrating our commitment to enhancing our customers’ cash flows through enhanced product design, assembly, installation, operations, customer service and support.
Competition
The compression services business is highly competitive. We have several competitors in the natural gas compression industry, some of which have greater financial resources. We believe that we compete effectively on the basis of price, compression unit availability, customer service, flexibility in meeting customer needs, and quality and reliability of our compressors and related services.
Compressor industry participants can achieve significant advantages through increased size and geographic breadth. As the number of rental compressors in our rental fleet increases, the number of sales, support, and maintenance personnel required and the minimum level of inventory may not increase proportionately.
Backlog
As of December 31, 2024, we had no sales backlog compared to $0.8 million as of December 31, 2023. The absence of a sales backlog is indicative of our efforts to de-emphasize selling compression equipment in favor of rentals. Sales backlog consists of firm customer orders for which a purchase or work order has been received, satisfactory credit or a financing arrangement exists, and delivery is scheduled. In addition, the major components of our compressors are acquired from suppliers through periodic purchase orders that currently require three to six months or more of lead time prior to delivery of the order. We do not believe that backlog is a critical indicator of the future growth potential of our business.
Liability and Other Insurance Coverage
Our equipment and services are provided to customers who are subject to hazards inherent in the oil and gas industry, such as explosions, fires, and oil spills. We maintain liability insurance that we believe is customary in the industry and which includes environmental cleanup but excludes product warranty insurance because the majority of components on our compressor unit are covered by the OEM manufacturers and our outsourced fabrication service providers. We also maintain insurance with respect to our facilities. Based on our historical experience, we believe that our insurance coverage is adequate. However, there is a risk that our insurance may not be sufficient to cover any particular loss or that insurance may not cover all losses. In addition, insurance rates have in the past been subject to wide fluctuation, and changes in coverage could result in less coverage, increases in cost or higher deductibles and retentions.
Intellectual Property
We believe that the success of our business depends more on the technical competence, creativity and marketing abilities of our employees than on any individual patent, trademark, or copyright. Nevertheless, as part of our ongoing research, design and development activities, we may seek patents when appropriate on inventions concerning new products, processes and product improvements. With respect to our executive officers and certain key, senior employees, we maintain confidentiality and proprietary information agreements with these officers and employees.
Suppliers and Raw Materials
Preparing our rental compressors for service involves the purchase by us of engines, compressors, coolers, frames and other components, and the assembly, primarily by third-party service providers, of these OEM components on skids for delivery to customer locations. These major components of our compressor units are acquired through periodic purchase orders placed with third-party suppliers on an “as needed” basis, which typically requires a three to twelve month lead time with delivery dates scheduled to coincide with our estimated assembly schedules. Although we do not have formal continuing supply and service contracts with any major supplier or third-party assembly service provider, we believe we have adequate alternative sources available. In the past, we have not experienced any sudden and dramatic increases in the prices of the major components for our compressors. However, the occurrence of such an event could have a material adverse effect on our results of operations, financial condition and cash flows, particularly if we are unable to increase our rental rates and sale prices proportionate to any such component price increases.
Government Regulation
All of our operations and facilities are subject to numerous federal, state, foreign and local laws, rules and regulations related to various aspects of our business, including containment and disposal of hazardous materials, water quality and wastewater discharges, oilfield waste and other waste materials and protection of human health.
To date, we have not been required to expend significant resources in order to satisfy applicable environmental laws and regulations. We do not anticipate any material capital expenditures for environmental control facilities or extraordinary expenditures to comply with environmental rules and regulations in the foreseeable future. However, compliance costs under existing laws or under any new requirements could become material and we could incur liabilities for noncompliance. And as noted below, we may be indirectly affected by environmental laws that affect our customers.
Our business is generally affected by political developments and by federal, state, foreign and local laws and regulations, which relate to the oil and gas industry. The adoption of laws and regulations affecting the oil and gas industry for economic, environmental and other policy reasons could increase our costs and could have an adverse effect on the demand for our services and our operations. The state and federal environmental laws and regulations that currently apply to our operations could become more stringent in the future.
Climate Change
In response to findings that emissions of carbon dioxide, methane and other Greenhouse Gases (“GHGs”) endanger public health and the environment, federal legislation has been considered from time to time to reduce GHG emissions. Methane, a primary component of natural gas, and carbon dioxide, a byproduct of the burning of natural gas, are examples of GHGs. At the federal level, the government could seek to pursue legislative, regulatory or executive initiatives that may impose significant restrictions on fossil-fuel exploration and production and use such as limitations or bans on hydraulic fracturing of oil and gas wells, bans or restrictions on new leases for production of minerals on federal properties, and imposing restrictive requirements on new pipeline infrastructure or fossil-fuel export facilities.
The Inflation Reduction Act of 2022 (the “IRA 2022”) imposes a methane emissions charge on certain oil and gas facilities, including onshore petroleum and natural gas production facilities, which emit 25,000 metric tons or more of carbon dioxide equivalent gas per year and exceed certain emissions thresholds. We do not operate any facilities that are subject to this emissions charge. In July 2023, the U.S. Environmental Protection Agency (“EPA”) proposed to expand the scope of the GHG Reporting Program for petroleum and natural gas facilities, as required by the IRA 2022. Among other things, the proposed rule expands the emissions events that are subject to reporting requirements to include “other large release events” and applies reporting requirements to certain new sources and sectors. The rule took effect on January 1, 2025, for reporting year 2025 (due March 2026) in certain circumstances, with the potential to also impact GHG reporting for reporting year 2024 (due March 2025) in certain circumstances. In January 2024, the EPA proposed a rule implementing the IRA 2022’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 IRA 2022. The methane emissions charge imposed under the Methane Emissions and Waste Reduction Incentive Program for calendar year 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 final rule for the waste emissions charge was implemented in November, 2024. In February 2025, however, the U.S. House and Senate approved a joint resolution of disapproval under the Congressional Review Act to repeal the methane emissions charge, which President Trump is expected to sign into law.
However, the new administration has taken quick action to pause or reverse a wide range of environmental policies. On his first day in office, President Trump signed a series of executive orders reversing prior climate change-related federal actions. Among them, the administration disbanded the Interagency Working Group on the Social Cost of Greenhouse Gases, directed all agencies to disregard the social cost of carbon calculations that were previously required, declared an energy emergency, and pulled out of the Paris Agreement. At this time, it is unclear how or when such changes will take effect, and to what extent this administration’s climate policy will reshape the regulatory landscape. Although it is not currently possible to predict how any proposed or future GHG legislation, regulation, agreements or initiatives will impact our business, any such legislation or regulation of GHG emissions could result in increased compliance or operating costs, additional operating restrictions or reduced demand for our compressor services, and could have a material adverse effect on our business, financial condition and results of operations.
Other energy legislation and initiatives could include a carbon tax, methane fee or cap and trade program. At the state level, many states, including the states in which we or our customers conduct operations, have adopted legal requirements that have imposed new or more stringent permitting, disclosure or well construction requirements on oil and gas activities. For instance, various states and groups of states have adopted or are considering adopting legislation, regulations or other regulatory initiatives that are focused on such areas as GHG cap and trade programs, carbon taxes, reporting and tracking programs, and restriction of emissions. For example, in 2019, Colorado passed a bill which delegates authority to local governments to regulate oil and gas activities and requires the Colorado Oil and Gas Conservation Commission to minimize emissions of methane and other air contaminants. Likewise, the New Mexico Environment Department has adopted regulations to restrict the venting or flaring of methane.
At the international level, there is an agreement, the United Nations-sponsored “Paris Agreement,” for nations to limit their GHG emissions through non-binding, individually determined reduction goals every five years after 2020. President Biden pledged the renewed participation of the United States on his first day in office. In November 2021, the United States participated in the United Nations Climate Change Conference in Glasgow, Scotland, United Kingdom that resulted in a pact among approximately 200 countries, including the United States, called the Glasgow Climate Pact. Relatedly, the United States and European Union jointly announced the launch of the “Global Methane Pledge,” which aims to cut global methane pollution at least 30% by 2030 relative to 2020 levels, including “all feasible reductions” in the energy sector. In conjunction with these pacts, the United States committed to an economy-wide target of reducing net greenhouse gas emissions by 50-52 percent below 2005 levels by 2030. In January 2025, however, President Trump issued an executive order withdrawing the U.S. from the Paris Agreement, and froze federal funds relating to the Agreement. The extent to which the U.S. will maintain climate change-related pledges is currently unknown, but any future laws and regulations imposing reporting obligations on, or limiting emissions of GHGs from, our compressors could require us to incur costs to reduce emissions associated with our operations.
Litigation risks are also increasing, as a number of cities and other local governments have sought to bring suits against the largest E&P companies in state or federal court, alleging, among other things, that such companies created public nuisances by producing fuels that contributed to global warming effects, such as rising sea levels, and therefore are responsible for roadway and infrastructure damages, or alleging that the companies have been aware of the adverse effects of climate change for some time but defrauded their investors by failing to adequately disclose those impacts.
There are also increasing financial risks for fossil fuel producers and oil and gas field service providers (such as us) as shareholders currently invested in fossil-fuel energy and related service companies concerned about the potential effects of climate change may elect in the future to shift some or all of their investments into non-energy related sectors. Institutional lenders who provide financing to fossil-fuel energy and related companies also have become more attentive to sustainable lending practices and some of them may elect not to provide funding for fossil fuel energy companies. Additionally, the lending practices of institutional lenders have been the subject of intensive lobbying efforts in recent years, oftentimes public in nature, by environmental activists, proponents of the international Paris Agreement, and foreign citizenry concerned about climate change not to provide funding for fossil fuel producers. Limitation of investments in and financings for fossil fuel energy companies could result in the restriction, delay or cancellation of drilling programs or development or production activities of our customers, which in turn could have a material adverse effect on our business.
The adoption and implementation of new or more stringent international, federal or state legislation, regulations or other regulatory initiatives that impose more stringent standards for GHG emissions from the oil and gas sector or otherwise restrict the areas in which this sector may produce oil and gas or generate GHG emissions could result in increased costs of compliance or additional operating restrictions or reduced demand for our compressor products and services, and could have a material adverse effect on our business, financial condition,results of operations and cash flows. The current administration has shown its willingness to reduce the number of regulations that increase compliance costs on companies such as ours, but the extent of changes are, as of yet, unclear. Further, the new administration has signed an executive order declaring a national energy emergency in the hopes of reducing regulatory costs in the oil and gas industry.
We believe that our existing environmental control procedures are adequate and that we are in substantial compliance with environmental laws and regulations, and the phasing in of emission controls and other known regulatory requirements should not have a material adverse effect on our financial condition, results of operations and cash flows; however, it is possible that future developments, such as new or increasingly strict requirements and environmental laws and enforcement policies thereunder, could lead to material costs of environmental compliance by us. While we may be able to pass on the additional cost of complying with such laws to our customers; however, there can be no assurance that attempts to do so will be successful. Some risk of environmental liability and other costs are inherent in the nature of our business; however, and there can be no assurance that environmental costs will not rise.
To the extent that new laws or other governmental actions restrict the energy industry or impose additional environmental protection requirements that result in increased costs to the oil and gas industry, we could be adversely affected. The new administration has signaled its interest in rescinding or nullifying regulations which financially adversely impact the oil and gas industry, although the extent of any such changes is unclear at this time. We cannot determine to what extent our future operations and earnings may be affected by new legislation, new regulations or changes in existing regulations.
Site Remediation and Waste Management and Disposal
The Comprehensive Environmental Response, Compensation and Liability Act of 1980 (“CERCLA”), also known as the Superfund law, and analogous state laws impose liability on certain classes of persons, known as potentially responsible parties (“PRPs”) for the disposal or release of a regulated hazardous substance into the environment. These PRPs include (1) the current owners and operators of a facility, (2) the past owners and operators of a facility at the time the disposal or release of a hazardous substance occurred, (3) parties that arranged for the offsite disposal or treatment of a hazardous substance, and (4) transporters of hazardous substances to off-site disposal or treatment facilities. PRPs under CERCLA may be subject to strict, joint and several liability for the costs of investigating and cleaning up environmental contamination, for damages to natural resources and for the costs of certain health studies. In addition to statutory liability under CERCLA, common law claims for personal injury or property damage can also be brought by neighboring landowners and other third parties related to contaminated sites.
The Resource Conservation and Recovery Act (“RCRA”), and comparable state statutes and their implementing regulations, regulate the generation, transportation, treatment, storage, disposal, and cleanup of hazardous and solid (non-hazardous) wastes. Under a delegation of authority from the EPA, most states administer some or all of the provisions of RCRA, sometimes in conjunction with their own, more stringent requirements. Federal and state regulatory agencies can seek to impose administrative, civil, and criminal penalties for alleged non-compliance with RCRA and analogous state requirements. In general, hazardous waste is waste with properties that can potentially endanger human health or the environment.
Under CERCLA, RCRA and analogous state laws, we could be required to remove or remediate environmental impacts on properties we currently own and lease or formerly owned or leased (including hazardous substances or wastes disposed of or released by prior owners or operators), to clean up contaminated off-site disposal facilities where our wastes have come to be located or to implement remedial measures to prevent or mitigate future contamination. Compliance with these laws may constitute a significant cost and effort for us. No specific accounting for environmental compliance has been maintained or projected by us at this time. We are not presently aware of any material environmental demands, claims, or adverse actions, litigation or administrative proceedings in which either we or our acquired properties are involved in or subject to or arising out of any predecessor operations.
We currently own or lease, and in the past have owned or leased, a number of properties that have been used in support of our operations for a number of years. We have utilized operating and disposal practices that were or are currently standard in the industry. However, materials such as solvents, thinner, waste paint, waste oil, wash down water and sandblast material may have been disposed of or released in or under properties currently or formerly owned or operated by us or our predecessors. Although we have utilized operating and disposal practices that were standard in the industry at the time, hydrocarbons, hazardous substances, or other regulated wastes may have been disposed of or released on or under the properties owned or leased by us or on or under other locations where such materials have been taken for disposal by companies sub-contracted by us. In addition, some of these properties may have been previously owned or operated by third parties whose treatment and disposal or release of hydrocarbons, hazardous substances or other regulated wastes was not under our control. These properties and the materials released or disposed thereon may be subject to CERCLA, RCRA and analogous state laws. Under such laws, we could be required to remove or remediate historical property contamination, or to perform certain operations to prevent future contamination. We are not currently under any order requiring that we undertake or pay for any cleanup activities; however, we cannot provide any assurance that we will not receive any such order in the future.
Under CERCLA and analogous state laws, we could be required to remove or remediate environmental impacts on properties we currently own and lease or formerly owned or leased (including hazardous substances or wastes disposed of or released by prior owners or operators), to clean up contaminated off-site disposal facilities where our wastes have come to be located or to implement remedial measures to prevent or mitigate future contamination. Compliance with these laws may constitute a significant cost and effort for us. No specific accounting for environmental compliance has been maintained or projected by us at this time. We are not presently aware of any material environmental demands, claims, or adverse actions, litigation or administrative proceedings in which either we or our acquired properties are involved in or subject to or arising out of any predecessor.
Furthermore, the modification of existing laws or regulations or the adoption of new laws or regulations that result in the curtailment of exploratory or developmental drilling for oil and gas could materially and adversely affect our operations by discouraging our customers from drilling for hydrocarbons, disrupting revenue through permitting or similar delays. Demand for our compression products and services could be diminished in connection with these initiatives. Further, to the extent that the review results in the development of additional restrictions on exploration and drilling, limitations on the availability of leases, or restrictions on the ability to obtain required permits, it could have a material adverse impact on our operations by reducing our customers’ compression needs and the demand for our services.
Air Emissions
The federal Clean Air Act (“CAA”) and implementing regulations and comparable state laws and regulations regulate emissions of air pollutants from various industrial sources and also impose various monitoring and reporting requirements, including requirements related to emissions from certain stationary engines, such as those on our compressor units. These laws and regulations impose limits on the levels of various substances that may be emitted into the atmosphere from our compressor units and required us to meet more stringent air emission standards and install new emission control equipment on all of our engines built after July 1, 2008.
In recent years, the EPA has lowered the National Ambient Air Quality Standard (“NAAQS”) for several air pollutants. For example, in 2013, the EPA lowered the annual standard for fine particulate matter from 15 to 12 micrograms per cubic meter. In 2015, the EPA published the final rule strengthening the standards for ground level ozone, and the states are expected to establish revised attainment/non-attainment regions. State implementation of the revised NAAQS could result in stricter permitting requirements, delay or prohibit our customers’ ability to obtain such permits, and result in increased expenditures for pollution control equipment, which could negatively impact our customers’ operations by increasing the cost of additions to equipment, and negatively impact our business.
In 2012, the EPA finalized rules that establish new air emission controls for oil and gas production and natural gas processing operations. Specifically, the EPA’s rule package included New Source Performance Standards (“NSPS”) to address emissions of sulfur dioxide and volatile organic compounds (“VOCs”) and a separate set of emission standards to address hazardous air pollutants frequently associated with oil and gas production and processing activities. The rules established specific new requirements regarding emissions from compressors and controls at natural gas processing plants, dehydrators, storage tanks and other production equipment as well as the first federal air standards for natural gas wells that are hydraulically fractured. The EPA has taken a number of steps to amend or expand on these regulations since 2012. For example, in June 2016, the EPA published NSPS that require certain new, modified or reconstructed facilities in the oil and gas sector to reduce methane gas and VOC emissions. These standards expanded the 2012 standards by using certain equipment-specific emissions control practices, requiring additional controls for pneumatic controllers and pumps as well as compressors, and imposing leak detection and repair requirements for natural gas compressor and booster stations. In addition, in December 2023, the EPA proposed a rule to further reduce methane and VOC emissions from new and existing sources in the oil and gas sector. These standards, as well as any future laws and their implementing regulations, may impose stringent air permit requirements, or mandate the use of specific equipment or technologies to control emissions. We cannot predict the final regulatory requirements or the future costs to comply with such requirements with any certainty.
We are also subject to air regulation at the state level. For example, sources of air emissions within Texas are controlled by the Texas Commission on Environmental Quality (“TCEQ”). Air emission sources that emit at greater than de minimis levels must obtain a permit prior to operation through the TCEQ. In addition, TCEQ has implemented revisions to certain air permit programs that significantly increase the air permitting requirements for new and certain existing oil and gas production and gathering sites for a number of counties in the Barnett Shale production area that established new emissions standards for engines, which impact the operation of specific categories of engines by requiring the use of alternative engines, compressor packages or the installation of aftermarket emissions control equipment. Expansion by the TCEQ of this type of program and the adoption of similar regulations in other states may increase our compliance costs.
Water Discharge
Clean Water Act. The Clean Water Act (“CWA”) and the Oil Pollution Act of 1990 and implementing regulations govern:
•the prevention of discharges, including oil and produced water spills, and
•liability for drainage into waters.
The CWA and analogous state laws impose restrictions and strict controls with respect to the discharge of pollutants, including spills and leaks of oil and other substances, into waters of the United States. The discharge of pollutants into regulated waters and wetlands is prohibited, except in accordance with the terms of a permit issued by the EPA or an analogous state agency. The CWA also requires the development and implementation of spill prevention, control and countermeasures to help prevent the contamination of navigable waters in the event of a petroleum hydrocarbon spill or leak at hydrocarbon facilities. In addition, the CWA and analogous state laws require individual permits or coverage under general permits for discharges of 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 CWA and analogous state laws and regulations. Our compression operations do not generate process wastewaters that are discharged to waters of the U.S. However, the operations of our customers may generate such wastewaters subject to the CWA. While it is the responsibility of our customers to follow CWA regulations and obtain proper permits, violations of the CWA may indirectly impact our operations in a negative manner.
Safe Drinking Water Act. Some of our customers’ natural gas production is developed from unconventional sources that require hydraulic fracturing as part of the completion process. Legislation to amend the Safe Drinking Water Act (“SDWA”) to repeal the exemption for hydraulic fracturing from the definition of “underground injection” and require federal permitting and regulatory control of hydraulic fracturing, as well as legislative proposals to require disclosure of the chemical constituents of the fluids used in the fracturing process, have been proposed from time to time and the federal government continues to consider legislation to amend the SDWA. Some states have also proposed or adopted legislative or regulatory restrictions on hydraulic fracturing, including prohibitions on the practice. We cannot predict the future of such legislation and what additional, if any, provisions would be included. Additional levels of regulation or interpretation are adopted at the federal or state level could lead to increased operating costs and prohibitions or curtailment of current hydraulic practices could reduce demand for our compression services, which could materially adversely affect our financial position, results of operations and cash flows.
Occupational Safety and Health
We are subject to the requirements of Occupational Safety and Health Administration (“OSHA”) and comparable state statutes. These laws and the implementing regulations strictly govern the protection of the health and safety of employees. The OSHA hazard communication standard, the EPA community right-to-know regulations under Title III of CERCLA, and similar state statutes require that we maintain and/or disclose information about hazardous materials used or produced in our operations. We believe that we are in compliance with these applicable requirements and with other comparable laws.
Human Capital
Our human capital resources objectives include, as applicable, identifying, recruiting, retaining, incentivizing and integrating our existing and new employees into our company. We offer competitive and comprehensive compensation and benefits including: (i) a 401(k) plan with employer matching contributions, (ii) medical, dental and eye care insurance benefits, (iii) health savings and flexible spending accounts and (iv) paid time off, among others. We also provide cash and equity incentive plans in order to attract, retain and reward our employees through the granting of cash-based and stock-based compensation awards, in order to increase stockholder value and the success of our company by motivating such individuals to perform to the best of their abilities and achieve well-defined short- and long-term business goals. The Compensation Committee of our Board of Directors is responsible for designing and administering executive compensation programs for our executive officers.
We are committed to providing a work environment that is free of discrimination and harassment. We are an equal-opportunity employer. We make employment decisions on the basis of an individual’s qualifications and our business needs. As new employees join us, they learn more about our policies and culture through orientation and onboarding, our Employee Handbook, Code of Conduct, and compliance trainings.
We are committed to maintaining a healthy, safe and secure work environment that protects our employees, contractors, business partners, customers and visitors to our facilities. We comply with applicable health, safety, and environmental laws as well as our internal policies and procedures. Safety is a core value to us and safety performance is a key metric that is included in the incentive compensation of certain employees, including our executive officers. We actively promote the highest standards of safety behavior and environmental awareness and strive to meet or exceed all applicable local, state and federal regulations.
As of December 31, 2024, we had 245 total employees, none of which are represented by a labor union. A total of 54 employees were based at our Midland, Texas headquarters location while the remaining 191 employees were deployed to our operating facilities throughout our operating regions. We believe that we have good relations with our employees.
Available Information
We use our website as a channel of distribution for Company information. We make available free of charge on the Investor Relations section of our website (www.ngsgi.com) our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, and Current Reports on Form 8-K. We also make available through our website other reports filed with or furnished to the Securities and Exchange Commission (“SEC”) under the Exchange Act including our proxy statements and reports filed by officers and directors under Section 16(a) of the Exchange Act, as well as our Code of Business Ethics and the charters to our various Committees of our Board of Directors. Paper copies of our filings are also available, without charge upon written request. Please mail requests to Natural Gas Services Group, Inc., 404 Veterans Airpark Lane, Suite 300, Midland, TX 79705. The information contained on our website is not part of this Report.

---

ITEM 1A. RISK FACTORS
ITEM 1A. RISK FACTORS
You should carefully consider the following risks associated with owning our common stock. Although the risks described below are the risks that we believe are material, they are not the only risks relating to our industry, our business and our common stock. Additional risks and uncertainties, including those that we have not yet identified or that we currently believe are immaterial, may also adversely affect our business, results of operations, financial condition and cash flows.
Risks Associated With Our Industry
Decreased oil and gas prices and oil and gas industry expenditure levels adversely affect our revenue.
Our revenue is derived primarily from expenditures in the oil and gas industry, which, in turn, are based on budgets to explore for, develop and produce oil and gas. When these expenditures decline, as they have at various times during the past several years, our revenue will suffer. The industry’s willingness to explore for, develop and produce oil and gas depends largely upon the prevailing view of future oil and gas prices. Prices for oil and gas historically have been, and are likely to continue to be, highly volatile. Many factors affect the supply and demand for oil and gas and, therefore, influence oil and gas prices, including:
•the level of oil and gas production;
•the level of oil and gas inventories;
•domestic and worldwide demand for oil and gas;
•the expected cost of developing new reserves;
•the cost of producing oil and gas;
•the level of drilling and completions activity;
•inclement weather;
•domestic and worldwide economic activity;
•regulatory and other federal and state requirements in the U.S.;
•the ability of OPEC, national oil companies and other large producers to set and maintain production levels and prices for crude oil;
•political conditions in or affecting oil and gas producing countries;
•terrorist activities affecting traditional supply routes and other possible terrorist activities in the U.S. and elsewhere;
•the cost of developing alternative energy sources;
•environmental regulation; and
•tax policies.
The rental contracts of many of our operating compressor units have a short-term duration, and oil and gas companies tend to respond quickly to upward or downward changes in prices. Any prolonged reduction in drilling and production activities has historically eroded both rental pricing and utilization rates for our compression equipment and services and adversely affected our financial results. As a result of any such prolonged reductions, we may suffer losses, be unable to make necessary capital expenditures or be unable to meet our financial obligations.
The intense competition in our industry could result in reduced profitability and loss of market share for us.
We compete with the oil and gas industry’s largest equipment and service providers who have greater name recognition than we do. These companies also have substantially greater financial resources, larger operations and greater budgets for marketing, research and development than we do. They may be better able to compete because of their broader geographic dispersion and ability to take advantage of international opportunities, the greater number of compressors in their fleet, their product and service diversity or a lower cost of capital. As a result, we could lose customers and market share to those competitors. These companies may also be better positioned than us to successfully endure downturns in the oil and gas industry.
Our operations may be adversely affected if our current competitors or new market entrants introduce new products or services with better prices, features, performance or other competitive characteristics than our products and services. Competitive pressures or other factors also may result in significant price competition that could harm our revenue and our business. In addition, our customers may purchase and operate their own compression fleets in lieu of renting compressors and using our compression services. Additionally, we may face competition in our efforts to acquire other businesses.
Adverse macroeconomic and business conditions may significantly and negatively affect our results of operations.
As a result of the COVID-19 outbreak and other economic conditions in the United States and abroad, our revenue and profitability were adversely affected in the ensuing years. Although the effects of the outbreak have generally abated, pandemics or other public health crises could significantly impact public health, economic growth, supply chains and markets. The extent to which our operations and financial results and condition may be affected by future pandemics or other public health crises will depend on various factors and consequences beyond our control, such as the duration and scope of such pandemic or public health crisis, the actions by governments and the private sector in response to the pandemic and the recovery speed and effectiveness of responses to combat any such pandemic or public health crisis. Thus, any future pandemic or public health crisis may materially adversely affect our operating and financial results in a manner that is not currently known to us and may be material and pose significant risks to our operations.
The condition of domestic and global financial markets and the potential for disruption and illiquidity in the credit markets could have an adverse effect on our operating results and financial condition, and if sustained for an extended period, such adverse effects could also become significant. Uncertainty and turmoil in the credit markets may negatively impact the ability of our customers to finance utilization of our products and services and could result in a decrease in, or cancellation of, contracts or adversely affect the collectability of our receivables. If the availability of credit to our customers is reduced, they may reduce their drilling and production expenditures, thereby decreasing demand for our products and services, which could have a negative impact on our financial condition. A prolonged period of depressed prices for oil and gas would likely result in delays or cancellation of projects by our customers, reducing the demand for our products and services.
Continued elevated levels of inflation could have an adverse impact on our operating results.
The U.S. economy has experienced elevated levels of inflation since early 2022. While such levels of inflation have moderated somewhat, inflation pressure continues and uncertainty remains regarding expectations of inflation during 2025. Should inflationary pressures continue or increase, the result will be an increase in our cost structure, including labor costs, parts costs, lubricants and other items used in our operations. If such cost increases occur, we may be unable to pass along such increases to our customers in the form of higher rental rates for our compressor units. Increases in inflation could also increase the costs of new compressor units, making them less attractive and decreasing the demand from our customers for such assets. In addition, inflation may adversely affect customers’ financing costs, cash flows, and profitability, which could adversely impact their operations and our ability to collect receivables. Should any of these items occur, they could negatively impact our results of operations, financial condition and cash flows.
A reduction in demand for oil could adversely affect our business.
Our results of operations depend upon the level of activity in the energy market, including oil development, production, and transportation. Oil and gas prices and the level of drilling and exploration activity can be volatile. As a result, the demand for our natural gas compression services can be adversely affected. A reduction in demand has, and could in the future continue to, force us to reduce our pricing substantially. Additionally, our customers’ production from oil-weighted reserves constitutes a substantial portion of our business. These are considered unconventional sources and are generally less economically feasible to be developed in low crude oil price environments. A decline in demand for oil and gas generally has an adverse effect on our business, results of operations, financial condition and cash flows.
Our industry is highly cyclical, and our results of operations may be volatile.
Our industry is highly cyclical, with periods of high demand and high pricing followed by periods of low demand and low pricing. Periods of low demand intensify the competition in the industry and often result in rental equipment being idle for long periods of time. At times, we have been required to enter into lower rate rental contracts in response to market conditions and our revenues have decreased as a result of such conditions. Due to the short-term nature of most of our rental contracts, changes in market conditions can quickly affect our business. As a result of the cyclicality of our industry, we anticipate our results of operations will be volatile in the future.
Increased regulation or ban of current fracturing techniques could reduce demand for our compressors.
From time to time, for example, legislation has been proposed in Congress to amend the federal SDWA to require federal permitting of hydraulic fracturing and the disclosure of chemicals used in the hydraulic fracturing process. Further, the EPA completed a study finding that hydraulic fracturing could potentially harm drinking water resources under adverse circumstances such as injection directly into groundwater or into production wells lacking mechanical integrity. Further, legislation to amend the SDWA to repeal the exemption for hydraulic fracturing (except when diesel fuels are used) from the definition of “underground injection” and require federal permitting and regulatory control of hydraulic fracturing, as well as legislative proposals to require disclosure of the chemical constituents of the fluids used in the fracturing process, have been proposed in recent sessions of Congress. Several states and local jurisdictions also have adopted or are considering adopting regulations that could restrict or prohibit hydraulic fracturing in certain circumstances, impose more stringent operating standards and/or require the disclosure of the composition of hydraulic fracturing fluids. While we do not perform hydraulic fracturing, many of our customers do and their activity level drives demand for our products.
More recently, federal and state governments have begun investigating whether the disposal of produced water into underground injection wells has caused increased seismic activity in certain areas. The results of these studies could lead federal and state governments and agencies to develop and implement additional regulations.
A ban of hydraulic fracturing would likely halt some projects, including unconventional projects, at least temporarily. Expanded regulations are likely to introduce a period of uncertainty as companies determine ways to proceed. Any curtailment could result in a reduction in demand for our compressors, potentially affecting both rentals and sales of our units.
We are subject to extensive environmental laws and regulations that could require us to take costly compliance actions that could harm our financial condition.
Our fabrication and maintenance operations are significantly affected by stringent and complex federal, state and local laws and regulations governing the discharge of substances into the environment or otherwise relating to environmental protection. In these operations, we generate and manage hazardous wastes such as solvents, thinner, waste paint, waste oil, wash down wastes, and sandblast material. We attempt to use generally accepted operating and disposal practices and, with respect to acquisitions, will attempt to identify and assess whether there is any environmental risk before completing an acquisition. Based on the nature of the industry, however, hydrocarbons or other wastes may have been disposed of or released on or under properties owned or leased by us or on or under other locations where such wastes have been taken for disposal. The waste on these properties may be subject to federal or state environmental laws that could require us to remove the waste or remediate sites where they have been released. We could be exposed to liability for cleanup costs, natural resource and other damages as a result of our conduct or the conduct of, or conditions caused by, prior owners, lessees or other third parties. Environmental laws and regulations have changed in the past, and they are likely to change in the future. If current existing regulatory requirements or enforcement policies change, we may be required to make significant unanticipated capital and operating expenditures.
Any failure by us to comply with applicable environmental laws and regulations may result in governmental authorities taking actions against our business that could harm our operations and financial condition, including the:
•issuance of administrative, civil and criminal penalties;
•denial or revocation of permits or other authorizations;
•reduction or cessation in operations; and
•performance of site investigatory, remedial or other corrective actions.
Increasing attention to environmental, social and governance matters and future related reporting requirements may impact our business, financial results and stock price.
In recent years, increasing attention has been given to corporate activities related to environmental, social and governance (“ESG”) matters in public discourse and the investment community. A number of advocacy groups, both domestically and internationally, have campaigned for governmental and private action to promote change at public companies related to ESG matters, including through the investment and voting practices of investment advisers, public pension funds, universities and other members of the investing community. These activities include increasing attention and demands for action related to climate change and energy transition matters, such as promoting the use of substitutes to fossil fuel products
and encouraging the divestment of fossil fuel equities, as well as pressuring lenders and other financial services companies to limit or curtail activities with fossil fuel companies.
Members of the investment community have begun to screen companies for sustainability performance, including practices related to climate change. In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings systems for evaluating companies on their approach to ESG matters. These ratings are used by some investors to inform their investment and voting decisions. Unfavorable ESG ratings may 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.
Regulatory requirements related to ESG or sustainability reporting have been issued in the European Union that apply to financial market participants. In the United States, such regulations have been issued related to pension investments in California, and for the responsible investment of public funds in Illinois. Additional regulation is pending in other states. We expect regulatory requirements related to ESG matters to continue to expand globally. If we are not able to meet future sustainability reporting requirements of regulators or current and future expectations of investors, customers or other stakeholders, our business and ability to raise capital may be adversely affected.
Increasing attention to climate change, increasing societal expectations on companies to address climate change, and potential consumer use of substitutes to energy commodities may result in increased costs, reduced demand for our customers’ hydrocarbon products which will likely translate to reduced demand for compression services, reduced profits, increased investigations and litigation, increased governmental regulations and negative impacts on our stock price and access to capital markets.
International, national and state governments and agencies continue to evaluate and promulgate legislation and regulations that are focused on restricting GHG emissions. Compliance with climate action regulations applicable to our customers’ operations may have significant implications that could adversely affect our business and operating results in the fossil fuel sectors, and boosting demand for technologies contributing to the climate action agenda.
In the United States, the EPA has taken steps to regulate GHG emissions as air pollutants under the CAA. The EPA’s Greenhouse Gas Reporting Rule requires monitoring and reporting of GHG emissions from, among others, certain mobile and stationary GHG emission sources in the oil and gas industry. In addition, the U.S. government has proposed rules in the past setting GHG emissions standards for, or otherwise aimed at reducing GHG emissions from, the oil and gas industry. Caps or fees on carbon emissions, including in the U.S., have been and may continue to be established and the cost of such caps or fees could disproportionately affect the fossil fuel sectors. We are unable to predict whether and when the proposed changes in laws or regulations ultimately will occur or what they ultimately will require, and accordingly, we are unable to assess the potential financial or operational impact they may have on our customers and therefore our business.
Risks Associated With Our Company
Approximately one half of our compressor unit rental agreements, representing approximately one quarter of our rented horsepower, are month-to-month in duration, which, if terminated or not renewed, would adversely impact our revenue and our ability to recover our initial equipment costs.
The length of our compressor rental agreements with our customers varies based on customer needs, equipment configurations and geographic area. In certain cases, under currently prevailing rental rates, the initial rental periods are not long enough to enable us to fully recoup the average cost of acquiring or assembling the equipment. On a unit basis, of the 1,208 compressors rented at December 31, 2024, 573 were rented on a month-to-month basis. On a horsepower basis, of the 491,756 total rented horsepower, we had 115,071 of that total rented on a month-to-month basis, with the remainder on contracts expiring between 2025 and 2029. We have limited ability to increase prices during our initial contract terms. As a result, we are unable to pass unexpected increases in the prices of the equipment, materials and services we utilize to provide contract operations services, as a result of inflation of otherwise, onto our customers, which could result in a negative impact on our results of operations, financial condition and cash flows. Given the volatility of the oil and gas market, we cannot be certain that a substantial number of our customers will continue their rental agreements or that, if such agreements were terminated we will be able to re-rent the equipment to new customers or that any re-rentals would be at comparable rental rates. The inability to timely renegotiate or re-rent a substantial portion of our compressor rental fleet could have a material adverse effect upon our business, financial condition, results of operations and cash flows.
We depend on particular suppliers and are vulnerable to product shortages and price increases.
In recent years, we have transitioned from in-house assembly of compressors, and we now purchase the majority of our compressors from third-party assemblers and suppliers. If we are unable to purchase compression equipment or other integral equipment, materials and services from third party suppliers, we may be unable to retain existing customers or compete for new customers, which could have a material adverse effect on our business, results of operations, financial condition and cash flows. Our reliance on these suppliers involves several risks, including price increases (as a result of inflation or otherwise), quality issues and a potential inability to obtain an adequate supply of such equipment, materials and services in a timely manner. Additionally, we may experience long lead times from our suppliers of compression equipment, which may negatively impact our ability to deliver compressors to our customers in a timely manner. If we are unable to meet the demands of our customers, our existing customers may terminate their contractual relationships with us or curtail future orders, or we may not be able to compete for business from new customers, which, in either case, could have a material adverse effect on our business, results of operations and financial condition. Further, supply chain issues could adversely affect our ability to obtain necessary materials, parts or lubricants used in our operations or increase the costs of such items. A significant increase in the price of such equipment, materials and services as a result of inflation, or other factors, could have a negative impact on our business, results of operations, financial condition and cash flows.
Our operations entail inherent risks and we could be subject to substantial liability claims that could harm our financial condition. Our insurance coverage may not insure against all potential losses and we could be materially harmed by unexpected losses and liabilities.
Our compressors are used in production applications where an accident or a failure of a product can cause personal injury, loss of life, damage to property, equipment or the environment, or suspension of operations. While we maintain insurance coverage, we face the following risks:
•we may not be able to continue to obtain insurance on commercially reasonable terms;
•we may be faced with types of liabilities that will not be covered by our insurance, such as damages from significant product liabilities and from environmental contamination;
•the dollar amount of any liabilities may exceed our policy limits; and
•we do not maintain coverage against the risk of interruption of our business.
Any claims made under our policies will likely cause our premiums to increase. Any future damages caused by our products or services that are not covered by insurance, are in excess of policy limits or are subject to substantial deductibles, would reduce our earnings and our cash available for operations.
A significant amount of our revenues and accounts receivable are related to one customer and a loss of this customer or other current customers could adversely affect our results of operations.
Our business is dependent not only on securing new customers but also on maintaining current customers. We had one customer that accounted for an aggregate of approximately 54 percent of our revenue for the year ended December 31, 2024, and the same customer accounted for an aggregate of approximately 50 percent of our revenue for the year ended December 31, 2023. As of December 31, 2024, this same customer accounted for an aggregate of 52 percent of our accounts receivable. Unless we are able to retain our existing customers, or secure new customers if we lose one or more of our significant customers, our revenue and results of operations would be adversely affected. In addition, the default on payments by our significant customer or other important customers would negatively impact our cash flows and current assets.
Loss of key members of our management could adversely affect our business.
Our success depends on our ability to attract, retain and motivate a highly-skilled management team and workforce. Failure to ensure that we have the depth and breadth of management and personnel with the necessary skill sets and experience could impede our ability to achieve growth objectives and execute our operational strategy. As we continue to expand, we will need to promote or hire additional staff, and, as a result of increased compensation and benefit packages in our industry, as well as inflationary pressures, it may be difficult to attract or retain such individuals without incurring significant additional costs.
In keeping with our streamlined approach to our business, our executive management team consists of three officers: our (i) Chief Executive Officer, (ii) President and Chief Operating Officer and (iii) Chief Financial Officer. In addition, we employ a number of key employees in connection with our business, including in connection with the design and engineering of our compressors. While we do have employment agreements with our three executive officers, the loss of any of our executive officers or other key employees could have an adverse impact on our business. We do not carry any key-person insurance on any of our officers or directors.
The erosion of the financial condition of our customers could adversely affect our business.
Many of our customers finance their exploration and development activities through cash flows from operating activities, the incurrence of debt or the issuance of equity. During times when the oil and gas markets are weak, our customers are more likely to experience a deterioration in their financial condition. Many of our customers’ equity values and liquidity substantially decline during declines in oil and gas prices, and in some cases access to capital markets may be an unreliable source of financing for some customers. The combination of a reduction in cash flow resulting from declines in commodity prices, an increase in the interest rates charged for debt financing, a reduction in borrowing bases under reserve-based credit facilities and the lack of availability of debt or equity financing may result in a reduction in our customers’ spending for our products and services. For example, our customers could seek to preserve capital by canceling month-to-month contracts, canceling or delaying scheduled maintenance of their existing natural gas compression equipment or determining not to enter into any new natural gas compression service contracts or purchase new compression equipment.
We might be unable to employ qualified technical personnel, which could hamper our present operations or increase our costs.
Many of the compressors that we rent are mechanically complex and often must perform in harsh conditions. We believe that our success depends upon our ability to employ and retain a sufficient number of technical personnel who have the ability to design, utilize, enhance and maintain these compressors. Our ability to maintain and expand our operations depends in part on our ability to utilize and increase our skilled labor force. The demand for skilled workers is high, and supply is limited. A significant increase in the wages paid by competing employers could result in a reduction of our skilled labor force or cause an increase in the wage rates that we must pay or both. If either of these events were to occur, our cost structure could increase and our operations and growth potential could be impaired.
We may require a substantial amount of capital to expand our compressor rental fleet and grow our business.
We have a five-year senior secured revolving credit agreement, as amended (the “Credit Facility”), with a total commitment of $300.0 million. We also have a right to request from the lender, an increase to the potential aggregate commitment of up to $50.0 million; provided, however, the aggregate commitment amount is not permitted to exceed $350.0 million. As of December 31, 2024, our borrowing base under the Credit Facility was approximately $300.0 million, with $170 million outstanding, leaving approximately $130.0 million available for future borrowing.
During 2025, the amount we will spend on capital expenditures related to compression equipment will be determined primarily by the activity of our customers, our financial resources and access to capital. The amount and timing of any capital expenditures may vary depending on a variety of factors, including the level of activity in the oil and gas exploration and production industry and the presence of alternative uses for our capital, including any acquisitions that we may pursue. In addition, although a significant portion of the value of a new compressor increases our borrowing base under our Credit Facility once it has been fully constructed and put into service, we generally have an approximate lag of 9 to 12 months between borrowing money under the Credit Facility to fund progress payments to build a compressor unit and the time it becomes eligible for inclusion in our borrowing base. This lag can reduce the amount of future borrowings available for working capital purposes and new compressor unit acquisition until the unit is placed into service.
During the past year, we funded our capital expenditures through cash flows from operating activities and borrowings under the Credit Facility. Although we believe that cash on hand, cash flows from operating activities and borrowing under our Credit Facility will provide us with sufficient cash to fund our planned capital expenditures for 2025, we cannot provide assurance that these sources will be sufficient considering the factors and limitations noted above.
In addition to expanding our existing business through organic growth opportunities, we may require additional capital to fund any significant unanticipated capital expenditures, such as a material acquisition. To the extent we would require any necessary capital, due to the existing constraints noted above and any issues or limitations in the equity and debt capital markets, such capital, may not be available to us when we need it or on acceptable terms. Our ability to raise additional capital
will depend on the results of our operations and the status of various capital and industry markets at the time we seek such capital. Failure to generate sufficient cash flows from operating activities, together with the absence of alternative sources of capital, could stagnate our growth and have a material adverse effect on our business, financial condition, results of operations or cash flows.
Our debt levels may negatively impact our current and future financial stability.
During 2024, we increased the borrowing commitment of the Credit Facility from $225 million to $300 million and we have the right to request an increase in the potential commitment by $50 million (subject to borrowing base limitation and customary covenants). As of December 31, 2024, we had $170 million of borrowings outstanding under the Credit Facility and anticipate additional borrowing under the Credit Facility through 2025. Should we utilize our full debt capacity, growth beyond that point could be impacted. As a result of our indebtedness at any given point in time, we might not have the ability to incur any substantial additional indebtedness. The level of our indebtedness could have several important effects on our future operations, including:
•our ability to obtain additional financing for working capital, acquisitions, capital expenditures and other purposes may be limited;
•a significant portion of our cash flows from operating activities may be dedicated to the payment of principal and interest (which is variable under the Credit Facility) on our debt, thereby reducing funds available for other purposes; and
•our leverage, if increased to an unacceptable level, could make us more vulnerable to economic downturns.
If we borrow under the Credit Facility and are unable to service our debt, we will likely be forced to take remedial steps that are contrary to our business plan.
If we were to materially borrow further under the Credit Facility or other borrowing arrangements, it is possible that our business will not generate sufficient cash from operating activities to meet any debt service requirements and the payment of principal when due depending on the amount of borrowings at any given time. If this were to occur, we may be forced to:
•sell assets at disadvantageous prices;
•obtain additional financing on less favorable terms; or
•refinance all or a portion of our indebtedness on terms that may be less favorable to us.
Our current Credit Facility agreement contains covenants that limit our operating and financial flexibility and, if breached, could expose us to severe remedial provisions.
Under the terms of our current Credit Facility agreement, we must:
•comply with various leverage, commitment coverage and other customary financial ratios;
•not exceed specified levels of debt;
•comply with limits on asset sales;
•comply with limits on cash dividends; and
•other customary financial and operational limitations.
Our ability to meet the financial ratios and tests under the Credit Facility can be affected by events beyond our control, and we may not be able to satisfy those ratios and tests. A breach of any one of these covenants or requirements could permit the lending organization to accelerate outstanding amounts so that it is immediately due and payable. If a breach occurs, no further borrowings would be available under our Credit Facility. If we are unable to repay any outstanding amounts, the lender could proceed against and foreclose on the assets we pledged as collateral to secure payment of our indebtedness.
Our current Credit Facility agreement contains a variable interest rate and increases to such rate may increase our borrowing cost.
The interest expense charged on our outstanding borrowings under the Credit Facility agreement is based upon a variable rate which fluctuates as interest rates change. Changes in macroeconomic conditions outside of our control could result in a higher interest rate being charged on our outstanding borrowings and an increase in the overall interest costs charged. This could have an adverse impact on our operations, our free cash flow and our ability to invest in future growth.
If we fail to acquire or successfully integrate additional businesses, our growth may be limited and our results of operations may suffer.
As part of our business strategy, we evaluate potential acquisitions of other businesses or assets. However, there can be no assurance that we will be successful in consummating any such acquisitions. The successful acquisition of businesses or assets will depend on various factors, including, but not limited to, our ability to obtain financing and the competitive environment for acquisitions. In addition, we may not be able to successfully integrate any businesses or assets that we acquire in the future. The integration of acquired businesses is likely to be complex and time-consuming, place a significant strain on management and may disrupt our business. We also may be adversely impacted by any unknown liabilities of acquired businesses, including environmental liabilities. We may encounter substantial difficulties, costs and delays involved in integrating common accounting, information and communication systems, operating procedures, internal controls and human resources practices, including incompatibility of business cultures and the loss of key employees and customers. These difficulties may reduce our ability to gain customers or retain existing customers, and may increase operating expenses, resulting in reduced revenues and income and a failure to realize the anticipated benefits of acquisitions.
Failure to effectively manage our business and growth could adversely affect our operating results and our internal controls.
In 2024, we had significant growth in our revenue and operations. Our strategy envisions the continued expansion and growth of our business, subject to the demand for oil and gas and the impact of the other risks set forth in this risk factor section and elsewhere in this Report. Continued rapid growth will likely challenge and place a strain on our management systems and resources if we are unable to timely adapt and expand such systems and resources. Many of our ongoing reporting functions rely on data capture and recording using manual entry of transaction data. In order to efficiently and effectively manage our planned growth, we will need to continue to analyze and upgrade our use of information technology (“IT”), including our enterprise resource planning and other operating systems and this will likely require future capital investment. We must continue to refine and expand our business capabilities, our workforce, our systems and processes, and our access to financing sources. As we continue to grow, we must continue to hire, train, supervise and manage new employees. We cannot assure that we will be able to:
•meet our capital needs;
•upgrade and expand our office and field management infrastructure so that it is appropriate for our level of activity;
•continue to improve our IT systems effectively or efficiently and in a timely manner, including financial and management controls, reporting systems and procedures; and
•attract, hire, train and retain additional highly skilled and motivated officers, sales staff, district managers and employees and allocate our human resources optimally.
If we are unable to manage our growth, our financial conditions and results of operations may be adversely affected.
Liability to customers under warranties and indemnification provisions may materially and adversely affect our results of operations.
We provide warranties as to the proper operation and conformance to specifications of the equipment we rent and sell. Our equipment is complex and often deployed in harsh environments. Failure of this equipment to operate properly or to meet specifications may increase our costs by requiring additional engineering resources and services, replacement of parts and equipment or monetary reimbursement to a customer. We have in the past received warranty claims and we expect to continue to receive them in the future. To the extent that we incur substantial warranty claims in any period, our reputation, our ability to obtain future business and our results of operations, financial condition and cash flows could be materially and adversely affected.
Our rental and sales contracts provide for varying forms of indemnification from our customers and in most cases may require us to indemnify our customers. Under some of our rental and sales contracts, liability with respect to personnel and property is customarily assigned on a “knock-for-knock” basis, which means that we and our customers assume liability for our respective personnel and property. However, in certain rental and sales contracts we assume liability for damage to our customer’s property as well as the property of certain other third parties on the site resulting from our negligence. Since our products are used in production applications in the energy industry, expenses and liabilities in connection with accidents involving our products and services could be extensive and may exceed our insurance coverage.
Our ability to to use net operating loss carryforwards to offset future taxable income may be subject to certain limitations.
Our ability to utilize net operating loss (“NOL”) carryforwards to reduce future taxable income is subject to limitations under Sections 382 and 383 of the Internal Revenue Code of 1986, as amended (“IRC”). As disclosed in Note 11 (“Income Taxes”) to our Consolidated Financial Statements, we have substantial NOL carryforwards. The utilization of such carryforwards may be limited by the occurrence of certain ownership changes, including the purchase or sale of our common stock by significant shareholders and the offering of our common stock during any three-year period resulting in an aggregate change of more than 50 percent in our beneficial ownership. In the event of an ownership change, Section 382 of the IRC imposes an annual limitation on the amount of our taxable income that can be offset by our NOL carryforwards. Under such circumstances, it is possible that the limitations imposed on our ability to utilize pre-ownership change NOLs could cause a significant increase in our U.S. federal income tax liabilities and could cause U.S. federal income taxes to be paid earlier than they otherwise would be paid if such limitations were not in effect.
Failure to maintain effective internal controls could have a material adverse effect on our operations.
Section 404 of the Sarbanes-Oxley Act requires annual management assessments of the effectiveness of our internal control over financial reporting. Effective internal controls are necessary for us to produce reliable financial reports and to help prevent financial fraud. If, as a result of deficiencies in our internal controls, we cannot provide reliable financial reports or prevent fraud, our business decision process may be adversely affected, our business and operating results could be harmed, investors could lose confidence in our reported financial information, and the price of our stock could decrease as a result.
We rely on computer and telecommunications systems, and failures in our systems or cyber security attacks or breaches could result in information theft, data corruption, disruption in operations and/or financial loss.
In the conduct of our business, we rely heavily on IT systems (“digital technology”), including internet-based systems, to process, transmit and store electronic information. In particular, we depend upon our digital technology for supply chain management, inventory management, payment processing and data storage. Like many companies, we have become increasingly dependent upon digital technology to conduct daily operations. Our business partners, including customers, vendors, service providers and financial institutions, are also dependent upon digital technology.
We are continually exposed to various cybersecurity risks, including but not limited to, unauthorized access to our systems or data, malware and ransomware attacks, denial-of-service attacks, phishing, theft or loss of intellectual property, and data breaches. These risks could result from malicious actors, employee error, malfeasance, or other operational vulnerabilities. A cybersecurity attack could have a significant adverse impact on our business operations, results of operations, financial condition, cash flows and reputation. Potential consequences include loss of sensitive or proprietary information, disruption of business operations, financial losses from remedial actions, litigation and potential legal liabilities and damage to customer and investor confidence.
We have taken steps to protect against cyber-attacks to minimize the risk of our systems being penetrated and compromised by implementing a comprehensive cybersecurity program, such as risk assessments and penetration testing, deployment of firewalls and intrusion detection systems, deployment of encryption technologies, implementation of access controls and the development of incident response and recovery plans. Additionally, we have employed data backup and storage measures that could allow for recovery of our data. However, we cannot assure that our efforts to prevent such an attack or, that if an attack were to occur, that we would be able to access our data in a timely fashion.
Risks Associated With Our Common Stock
The price of our common stock may fluctuate.
The trading price of our common stock and the price at which we may sell securities in the future are subject to substantial fluctuations in response to various factors, including our ability to successfully accomplish our business strategy, the trading volume of our stock, changes in governmental regulations, actual or anticipated variations in our quarterly or annual financial results, our involvement in litigation, general market conditions, the prices of oil and gas, announcements by us and our competitors, our liquidity, our ability to raise additional funds, and other events such as those discussed in the factors above.
Future sales of our common stock could adversely affect our stock price.
Substantial sales of our common stock in the public market, or the perception by the market that those sales could occur, may lower our stock price or make it difficult for us to raise additional equity capital in the future. According to filings made with the SEC through March 14, 2025, an aggregate of approximately 35 percent of the outstanding shares of our common stock are owned by five institutional investors, each of which owns more than 5 percent of our outstanding shares as of the date of their respective filings. Potential sales of large amounts of these shares in a short period of time by one or more of these significant investors could have a negative impact on our stock price. In addition, potential sales of our common stock by our directors and officers, who beneficially own approximately 6 percent of the outstanding shares of our common stock as of March 14, 2025, and because of the negative perception of sales by insiders, could also have a negative impact on our stock price.
We have a comparatively low number of shares of common stock outstanding and, therefore, our common stock may suffer from limited liquidity and its price will likely be volatile and its value may be adversely affected.
Because of our relatively low number of outstanding shares of common stock, the trading price of our common stock will likely be subject to significant price fluctuations and limited liquidity. This may adversely affect the value of your investment. In addition, our common stock price is subject to fluctuations in response to variations in quarterly operating results, changes in management, future announcements concerning us, general trends in the industry and other events or factors such as those described above.
If we issue debt or equity securities, you may lose certain rights and your ownership may be diluted.
If we raise funds in the future through the issuance of debt or equity securities, the securities issued may have rights and preferences and privileges senior to those of holders of our common stock, and the terms of the securities may impose restrictions on our operations or dilute your ownership in our Company.
We currently have on file with the SEC an effective “universal” shelf registration statement on Form S-3, which enables us to sell, from time to time, up to $200 million of our common stock and other securities, including debt securities, covered by the registration statement in one or more public offerings. The shelf registration statement allows us to enter the public markets and consummate sales of the registered securities in rapid fashion and with little or no notice. Issuances of securities under our shelf registration statement may dilute our existing shareholders.
If securities analysts downgrade our stock or cease coverage of us, the price of our stock could decline.
The trading market for our common stock relies in part on the research and reports that industry or financial analysts publish about us or our business. We do not control these analysts. Furthermore, there are many large, well-established, publicly traded companies active in our industry and market, which may mean that it is less likely that we will receive widespread analyst coverage. If one or more of the analysts who do cover us downgrade our stock, our stock price would likely decline rapidly. If one or more of these analysts cease coverage, we could lose visibility in the market, which in turn could cause our stock price to decline.
Provisions contained in our governing documents could hinder a change in control.
Our articles of incorporation and bylaws contain provisions that may discourage acquisition bids and may limit the price investors are willing to pay for our common stock. Our articles of incorporation and bylaws provide that:
•directors are elected for three-year terms, with approximately one-third of the board of directors standing for election each year;
•cumulative voting is not allowed, which limits the ability of minority shareholders to elect any directors;
•advance notice for nominations of directors by shareholders and for shareholders to include matters to be considered at our annual meeting;
•the unanimous vote of the board of directors or the affirmative vote of the holders of not less than 80% of the votes entitled to be cast by the holders of all shares entitled to vote in the election of directors is required to change the size of the board of directors; and
•directors may be removed only for cause or by the holders of not less than 80% of the votes entitled to be cast on the matter.
Our Board of Directors has the authority to issue up to five million shares of preferred stock. The Board of Directors can fix the terms of the preferred stock without any action on the part of our shareholders. The issuance of shares of preferred stock may delay or prevent a change in control transaction. In addition, preferred stock could be used in connection with the Board of Directors’ adoption of a shareholders’ rights plan (also known as a poison pill), which would make it much more difficult to effect a change in control of our Company through acquiring or controlling blocks of stock. Also, our directors and officers as a group will continue to beneficially own stock and although this is not a majority of our stock, it confers substantial voting power in the election of directors and management of our Company. This would make it difficult for other minority shareholders to effect a change in control or otherwise extend any significant control over our management. This may adversely affect the market price and interfere with the voting and other rights of our common stock.

---

ITEM 1B. UNRESOLVED STAFF COMMENTS
ITEM 1B. UNRESOLVED STAFF COMMENTS
None.

---

ITEM 2. PROPERTIES
ITEM 2. PROPERTIES
The table below describes the material facilities that we owned or leased as of December 31, 2024:
Location
Status
Square Feet
Uses
Tulsa, Oklahoma Owned and Leased 91,780 Compressor fabrication, rental and services
Midland, Texas Owned 70,000 Compressor repair and overhaul, services
Lewiston, Michigan Owned 15,360 Compressor fabrication, rental and services
Midland, Texas Owned 45,000 Corporate office
Pecos, Texas Leased 7,500 Office and parts and services
Bloomfield, New Mexico Owned 7,000 Office and parts and services
Godley, Texas Leased 5,000 Parts and services
Bridgeport, Texas Leased 4,500 Office and parts and services
Midland, Texas Owned 4,100 Parts and services
Carlsbad, New Mexico Leased 4,000 Office and parts and services
Carrollton, Ohio Leased 2,600 Parts and services
Wheeler, Texas Leased 2,160 Parts and services
We believe that our properties are generally well maintained and in good condition and adequate for our purposes. As discussed in Part I, Item 1. “Business,” we announced our intent to close our repair and overhaul services facility in Midland, Texas and cease operations by April 1, 2025. In addition, we have initiated efforts to market the facility and the underlying real property.

---

ITEM 3. LEGAL PROCEEDINGS
ITEM 3. LEGAL PROCEEDINGS
From time to time, we are a party to various legal proceedings in the ordinary course of our business. While management is unable to predict the ultimate outcome of these actions, it believes that any ultimate liability arising from these actions will not have a material effect on our financial position, results of operations or cash flow. We are not currently a party to any bankruptcy, receivership, reorganization, adjustment or similar proceeding, and we are not aware of any material threatened litigation.

---

ITEM 4. MINE SAFETY DISCLOSURE
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
PART II

---

ITEM 5. MARKET FOR REGISTRANT'S COMMON EQUITY
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS
AND ISSUER PURCHASES OF EQUITY SECURITIES
Our common stock currently trades on the New York Stock Exchange under the symbol “NGS.” As of December 31, 2024, as reflected by our transfer agent records, we had 7 record holders of our common stock. This number does not include any beneficial owners for whom shares of common stock may be held in “nominee” or “street” name. On March 14, 2025, the last reported sale price of our common stock as reported by the New York Stock Exchange was $22.64 per share.
Dividends
To date, we have not declared or paid any dividends on our common stock. We currently do not anticipate paying a cash dividend on our common stock. Although we intend to retain our earnings, if any, to finance the growth of our business, our Board of Directors will have the discretion to declare and pay dividends in the future. Payment of dividends in the future will depend upon our earnings, capital requirements, and other factors which our Board of Directors may deem relevant. Our Credit Facility agreement also contains restrictions on our paying dividends under certain circumstances.
Equity Compensation Plans
For disclosures regarding securities authorized for issuance under equity compensation plans, see Part III, Item 12. “Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters” of this Form 10-K.
Sale of Unregistered Securities and Issuer Repurchases
None.
Purchases of Equity Securities by Issuer and Affiliated Purchasers
None.

---

ITEM 6. SELECTED FINANCIAL DATA
ITEM 6. RESERVED

---

ITEM 7. MANAGEMENT'S DISCUSSION AND ANALYSIS
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The discussion and analysis of our financial condition and results of operations for each of the years ended December 31, 2024 and 2023 are based on, and should be read in conjunction with, our audited Consolidated Financial Statements and the related notes included elsewhere in this 2024 Annual Report on Form 10-K. For a discussion and analysis of changes from 2022 to 2023 and other financial information related to prior periods, refer to Part II, Item 7. “Management’s Discussion and Analysis of Financial Condition and Results of Operations” included in our 2023 Annual Report on Form 10-K. The following discussion contains forward-looking statements that include risks and uncertainties. For a description of limitations inherent in forward-looking statements, see “Special Note Regarding Forward-Looking Statements” on page i and Part I, Item 1A. “Risk Factors” in this Report.
All dollar amounts included in the tables that follow are presented in thousands unless otherwise indicated. Certain variances presented as changes in year over year amounts that represent results that are not meaningful are indicated as “NM.”
Overview
We rent, design, sell, service, operate and maintain natural gas compressors and related equipment for oil and gas production and processing facilities, generally using equipment from third-party fabricators and OEM suppliers along with limited in-house assembly. A limited level of assembly work is done in-house and an increasing amount is done by third-party contractors. We also provide an exchange and rebuild program for compressors and maintain an inventory of new and used compressors to facilitate this business. Our primary focus is on the rental of natural gas compressors. Our rental contracts generally provide for initial terms of six to 60 months, with our larger horsepower units having longer initial terms than our small and medium horsepower units. After the initial term of our rental contracts, most of our customers have continued to rent our compressors on a month-to-month basis. Rental amounts are billed monthly in advance and include maintenance of the rented compressor units.
We conduct our operations in several oil and gas producing basins throughout the United States including the Permian, Barnett Shale, Anadarko, San Juan, Utica/Marcellus Shale, Eagle Ford Shale and Antrim Shale. We have operating facilities in five states including Texas, Oklahoma, New Mexico, Michigan and Ohio. A total of 75 percent of our rental revenue is generated from the Permian Basin and approximately 75 percent of our rental revenue supports oil production primarily in the form of gas lift operations. We operate in one reporting segment.
In December 2023, we decided to cease fabrication of new compressor units for sale or rental to customers at our Midland, Texas facility. We continue to maintain new unit compressor fabrication capability at our Tulsa, Oklahoma facility as well as having relationships with multiple outsourced compressor fabrication providers.
State of the Industry and Outlook
Our strategy for growth is focused on our compressor rental business. Gross margins, exclusive of depreciation and amortization, for our rental business have historically been in the mid-40 percent to low-60 percent range, while margins for the compressor sales business tend to be substantially lower.
The oil and gas equipment rental and services industry is cyclical in nature. The most critical factor in assessing the outlook for the industry is the worldwide supply and demand for oil and gas and the corresponding changes in commodity prices. As demand and prices increase, oil and gas producers typically increase their capital expenditures for drilling, development and production activities, although recent equity capital constraints and demands from institutional investors to keep spending within operating cash flow have meaningfully restrained capital expenditure budgets of domestic exploration and production companies. Generally, increased capital expenditures result in greater revenues and profits for service and equipment companies.
Generally, higher commodity prices lead to higher capital expenditures by oil and gas producers and higher levels of production. In general, we expect our overall business activity and revenues to track the level of activity in the oil and gas industry, specifically production levels, with changes in crude oil and condensate production and consumption levels and prices affecting our business more than changes in domestic natural gas production and consumption levels and prices. In recent years we have increased our rental and sales in unconventional oil shale plays, which are more dependent on crude oil prices. With this shift towards oil production the demand for overall compression services and products is driven by two general factors; (i) an increased focus by producers on artificial lift applications, e.g., production enhancement with compression assisted gas lift;
and (ii) declining reservoir pressure in maturing natural gas producing fields, especially non-conventional production. These latter types of applications have historically been serviced by wellhead size compressors, and continue to be, but there has also been an economic move by our customers towards centralized drilling and production facilities, which have increased the market need for single and multiple larger horsepower compressor packages. We recognized this need in recent years and have shifted our cash and fabrication resources towards renting gas compressor packages that range from 400 horsepower up to 2,500 horsepower. While this is a response to market conditions and trends, it also provides us with the opportunity to compete as a full-line compression service provider.
We typically experience a decline in demand during periods of low oil and gas prices. In recent years, our level of activity has become more largely driven by the price of crude oil as opposed to natural gas. Generally, we feel that the level of demand for our compressor services is more closely tied to production activities, which are likely to fare better than drilling activity in periods of declining commodity prices.
Operating Highlights
The following table summarizes our key operating statistics as of the dates or for the periods presented, as applicable:
December 31,
2024 2023 2022
Rented horsepower (at period end) 491,756 420,432 318,350
Average rented horsepower 457,302 369,484 308,065
Fleet horsepower available (at period end): 598,840 520,365 425,340
Fleet horsepower available - average 558,752 472,360 423,054
Horsepower utilization (at period end) 82.1 % 80.8 % 74.8 %
Average horsepower utilization 81.8 % 78.2 % 72.8 %
Units utilized (at period end) 1,208 1,247 1,221
Fleet units (at period end): 1,912 1,876 1,869
Unit utilization (at period end) 63.2 % 66.5 % 65.3 %
Rental revenues $ 144,236 $ 106,159 $ 74,465
Total revenues $ 156,742 $ 121,167 $ 84,825
Rental revenues as a percent of total revenues 92.0 % 87.6 % 87.8 %
Of the total horsepower utilized as of December 31, 2024, 376,685 of horsepower was being rented under contracts expiring between 2025 and 2029 and 115,071 of that horsepower was being rented on a month-to-month basis. Of the 1,208 compressors utilized as of December 31, 2024, 573 were being rented on a month-to-month basis.
Our Performance Trends and Outlook
The oil and gas industry has historically been cyclical and production levels of oil and gas are dependent upon numerous factors. The market for compression equipment and services is highly dependent on the production levels and pricing of oil and gas.
Crude Oil. The level of production for crude oil activity and capital expenditures has generally been dependent upon the prevailing view of future crude oil prices, which are influenced by numerous supply and demand factors, including availability and cost of capital, well productivity and development costs, global and domestic economic conditions, environmental regulations, policies of OPEC and Russia, and other factors. We feel that the current crude oil market production outlook is favorable, with current prices creating strong incentives for our customers to maximize their production levels. While crude oil prices have historically been volatile, we expect demand for our existing compressor fleet to remain positive assuming crude oil prices remain within reasonable bands with respect to current pricing levels.
Natural Gas. We believe the market outlook for natural gas production in the U.S. remains steady while short term price volatility remains a factor due to geopolitical influences and shifts in LNG exports. We believe opportunities for increased utilization of our small and medium horsepower units are supported by continued investment in shale gas development, particularly in the Permian basin and Marcellus Shale.
Non-GAAP Financial Measures
We utilize certain financial and operating metrics to analyze our performance and assess our operating results and overall profitably and liquidity. The most significant of these measure are “Adjusted Gross Margin” and “Adjusted EBITDA” both of which are measurements that are not explicitly defined in accordance with generally accepted accounting principles in the United States of America (“GAAP”), or non-GAAP financial measures, and may vary among different industries and the participants therein.
Adjusted Gross Margin
We define “Adjusted Gross Margin” as total revenue less costs of revenues (excluding depreciation and amortization expense). Adjusted gross margin is included as a supplemental disclosure because it is a primary measure used by our management as it represents the results of revenue and costs (excluding depreciation and amortization expense), which are key components of our operations. Adjusted gross margin differs from gross margin, in that gross margin includes depreciation and amortization expense. We believe Adjusted gross margin is important because it focuses on the current operating performance of our operations and excludes the impact of the prior historical costs of the assets acquired or constructed that are utilized in those operations. Depreciation and amortization expense does not accurately reflect the costs required to maintain and replenish the operational usage of our assets and therefore may not portray the costs from current operating activity. Rather, depreciation and amortization expense reflects the systematic allocation of historical property and equipment costs over their estimated useful lives.
Adjusted gross margin has certain material limitations associated with its use as compared to gross margin. These limitations are primarily due to the exclusion of depreciation and amortization expense, which is material to our results of operations. Because we use capital assets, depreciation and amortization expense is a necessary element of our costs and our ability to generate revenue. In order to compensate for these limitations, management uses this non-GAAP measure as a supplemental measure to other GAAP results to provide a more complete understanding of our performance.
As an indicator of our operating performance, Adjusted gross margin should not be considered an alternative to, or more meaningful than, gross margin as determined in accordance with GAAP. Our Adjusted gross margin may not be comparable to a similarly titled measure of another company because other entities may not calculate Adjusted gross margin in the same manner.
The following table calculates our gross margin, the most directly comparable GAAP financial measure, and reconciles it to Adjusted gross margin with further detail by revenue classification for the periods presented:
Year Ended December 31,
2024 2023 2022
Total revenue $ 156,742 $ 121,167 $ 84,825
Cost of revenue, exclusive of depreciation and amortization (68,756) (62,454) (46,357)
Depreciation allocable to cost of revenues (30,813) (25,856) (23,551)
Gross margin 57,173 32,857 14,917
Depreciation allocable to cost of revenues 30,813 25,856 23,551
Adjusted gross margin $ 87,986 $ 58,713 $ 38,468
Adjusted gross margin by revenue classification:
Rental $ 87,333 $ 57,282 $ 36,715
Sales (290) 2 918
Aftermarket services 943 1,429 835
Total adjusted gross margin $ 87,986 $ 58,713 $ 38,468
Adjusted EBITDA
“Adjusted EBITDA” is a non-GAAP financial measure that we define as net income (loss) before interest, taxes, depreciation and amortization, as well as an increase in inventory allowance, impairments, retirement of rental equipment, non-recurring restructuring charges including severance and non-cash equity-classified stock-based compensation expenses. This term, as used and defined by us, may not be comparable to similarly titled measures employed by other companies and is not a measure of performance calculated in accordance with GAAP. Adjusted EBITDA should not be considered in isolation or as a substitute for operating income, net income or loss, cash flows provided by operating, investing and financing activities, or other income or cash flow statement data prepared in accordance with GAAP. However, management believes Adjusted EBITDA is useful to an investor in evaluating our operating performance because:
•it is widely used by investors in the energy industry to measure a company’s operating performance without regard to items excluded from the calculation of Adjusted EBITDA, which can vary substantially from company to company depending upon accounting methods and book value of assets, capital structure and the method by which assets were acquired, among other factors;
•it helps investors to more meaningfully evaluate and compare the results of our operations from period to period by removing the impact of our capital structure and asset base from our operating structure; and
•it is used by our management for various purposes, including as a measure of operating performance, in presentations to our Board of Directors, as a basis for strategic planning and forecasting, and as a component for setting incentive compensation.
Adjusted EBITDA has limitations as an analytical tool, and you should not consider it in isolation, or as a substitute for analysis of our results as reported under GAAP. Some of these limitations are:
•Adjusted EBITDA does not reflect all our cash expenditures, future requirements for capital expenditures, or contractual commitments;
•Adjusted EBITDA does not reflect changes in, or cash requirements for, our working capital needs;
•Adjusted EBITDA does not reflect the cash requirements necessary to service interest or principal payments on our debts; and
•although depreciation and amortization are non-cash charges, the assets being depreciated and amortized will often have to be replaced in the future, and Adjusted EBITDA does not reflect any capital expenditures for such replacements.
There are other material limitations to using Adjusted EBITDA as a measure of performance, including the inability to analyze the impact of certain recurring items that materially affect our net income or loss, and the lack of comparability of results of operations of different companies. Please read the table below to see how Adjusted EBITDA reconciles to our net income (loss), the most directly comparable GAAP financial measure.
The following table reconciles our net income (loss), the most directly comparable GAAP financial measure, to Adjusted EBITDA for the periods presented:
Year Ended December 31,
2024 2023 2022
Net income (loss) $ 17,227 $ 4,747 $ (569)
Interest expense 11,927 4,082 364
Income tax expense 4,439 1,873 528
Depreciation and amortization 31,347 26,550 24,116
Impairments 841 779 -
Inventory allowance 1,863 3,965 83
Retirement of rental equipment 28 505 196
Severance and restructuring charges 33 1,224 2,537
Stock-based compensation 1,821 2,054 1,910
Adjusted EBITDA $ 69,526 $ 45,779 $ 29,165
Results of Operations
Year Ended December 31, 2024 Compared to the Year Ended December 31, 2023
Rentals
We generate revenue from renting compressors to our customers. These contracts, which all qualify as operating leases under GAAP, may also include a fee for servicing the compressor unit during the rental contract. Our rental contracts typically range from six to 60 months. Our revenue is recognized over time, with monthly payments over the term of the contract. After the terms of the contract have expired, a customer may renew its contract or continue renting on a monthly basis thereafter. The primary costs associated with providing our compressor fleet to our customers includes routine maintenance and repairs, fluids, primarily motor oils, and labor and related support costs for our field service facilities and employees that are geographically dispersed throughout our operating regions.
The following table summarizes the revenues, costs, adjusted gross margin and related operating statistics with respect to our rentals of compressors for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Rental revenue $ 144,236 $ 106,159 $ 38,077 35.9 %
Cost of rentals (excluding depreciation and amortization) 56,903 48,877 8,026 16.4 %
Rental adjusted gross margin $ 87,333 $ 57,282 $ 30,051 52.5 %
Rental adjusted gross margin percentage 60.5 % 54.0 % 6.5 %
Percent of total company revenues 92.0 % 87.6 % 4.4 %
Rented horsepower 491,756 420,432 71,324 17.0 %
Percent of fleet horsepower utilized 82.1 % 80.8 % 1.3 %
Units utilized 1,208 1,247 (39) (3.1) %
Percent of fleet units utilized 63.2 % 66.5 % (3.3) %
Customers under contract 68 84 (16) (19.0) %
Rental revenue increased for the year ended December 31, 2024, compared to 2023 due primarily to an increase in rented horsepower despite a nominal decrease in the number of units rented and a decrease in total customers. The increase in revenue reflects a continuing trend of growing demand for our higher horsepower units (400 horsepower and greater) which provide for higher rental rates and realized adjusted gross margins. The increase in utilized horsepower reflects the continued addition of high horsepower compressor units to our fleet during 2024 consistent with our emphasis on larger units over the past two years. During the year ended December 31, 2024, we placed into service a total of 220 newly set units, including 198 from our existing fleet and 22 new units. Of those sets, a total of 111 were high horsepower units and 22 of those were new units to the fleet. The decline in customers is primarily attributable to E&P industry consolidation as well as the acquisition of existing producing oil and gas properties among E&P companies; however, it has not resulted in any meaningful decrease in our level of business activity. The cost of rentals increased on an absolute basis due to the effects of supporting a larger quantity of utilized horsepower and inflationary pressures primarily in labor and parts costs. As a result of these factors, our adjusted gross margin increased on both an absolute basis as well as a percentage of revenues for the year ended December 31, 2024, compared to the year ended December 31, 2023.
Sales
We generate revenue by the sale of custom/assembled compressors and parts, as well as exchange/rebuilding customer owned compressors and sale of used rental equipment. Costs of sales include purchases of engines, compressors, coolers and other component materials as well as direct and indirect labor attributable to the assembly of equipment to meet the unique specifications of our customers. In addition, our costs of sales include overhead and related support costs attributable to our assembly, repair and overhaul facilities in Midland, Texas and Tulsa, Oklahoma.
The following table summarizes the revenues, costs and adjusted gross margin with respect to our sales of compressors, parts and equipment and repair/overhaul services for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Sales revenue $ 7,613 $ 8,921 $ (1,308) (14.7) %
Cost of sales (excluding depreciation and amortization) 7,903 8,919 (1,016) (11.4) %
Sales adjusted gross margin $ (290) $ 2 $ (292) NM
Sales adjusted gross margin percentage (3.8) % - % (3.8) %
Percent of total company revenues 4.9 % 7.4 % (2.5) %
Sales revenue declined for the year ended December 31, 2024, compared to 2023. Sales are subject to fluctuations in the timing of industry activity related to our customers’ capital projects and, as such, can vary substantially between periods. Due to these circumstances as well as the costs of maintaining support facilities relative to revenues, we continue to shift our business away from sales of new compressor packages to renting our owned units to our customers. While the costs to support our sales revenues declined on an absolute basis, primarily reflecting a lower volume of business, the gross margin declined to a negative value due primarily to indirect labor and fixed overhead costs that are not otherwise subject to capitalization at our assembly, repair and overhaul facilities.
Aftermarket Services
We provide routine or call-out services on customer-owned equipment as well as commissioning of new units for customers. Revenue is recognized after services in the contract are rendered. The primary costs associated with our aftermarket services are labor, support costs, materials and supplies.
The following table summarizes the revenues, costs and adjusted gross margin with respect to our aftermarket services for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Aftermarket services revenue $ 4,893 $ 6,087 $ (1,194) (19.6) %
Cost of aftermarket services (excluding depreciation and amortization) 3,950 4,658 (708) (15.2) %
Aftermarket services adjusted gross margin $ 943 $ 1,429 $ (486) (34.0) %
Aftermarket services adjusted gross margin percentage 19.3 % 23.5 % (4.2) %
Percent of total company revenues 3.1 % 5.0 % (1.9) %
Third party aftermarket services revenues, costs and margin declined for the year ended December 31, 2024, compared to 2023. The decline is primarily attributable to a lower volume of service call-out work performed during 2024 compared to 2023. Aftermarket services only represented 3.1 percent of our revenue in 2024, providing minimal impact on our overall adjusted gross margin.
Selling, General and Administrative Expenses
Our selling, general and administrative (“SG&A”) expenses include compensation and benefits, including stock-based compensation, commissions and other support costs of departments serving administrative and corporate governance functions, such as executive management, finance and accounting, sales and marketing, human resources, information technology, health, safety and environmental and investor relations. In addition, SG&A includes non-personnel costs, such as occupancy costs, IT support costs, professional fees and other supporting corporate expenses including public company compliance costs. When applicable, SG&A expenses also includes severance benefits and related costs associated with exit activities and restructuring actions.
The following table summarizes the components of our SG&A expenses for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Primary selling, general and administrative expenses $ 19,158 $ 13,660 $ 5,498 40.2 %
Stock-based compensation 1,821 2,054 (233) (11.3) %
Severance and restructuring charges 33 1,224 (1,191) NM
Total $ 21,012 $ 16,938 $ 4,074 24.1 %
SG&A expenses as a percent of total revenues 13.4 % 14.0 % (0.6) %
SG&A expenses increased for the year ended December 31, 2024, as compared to 2023 on an absolute dollar basis while continuing a steady decline as a percent of revenues. As our revenues have increased commensurate with our growth, total SG&A expenses have consistently declined as a percent of revenues despite our incurring a higher level of costs to appropriately scale our administrative function. The absolute dollar increase was primarily impacted by (i) higher salaries, benefits and commissions of $3.3 million reflecting new executive leadership and support staff growth as well and higher commissions attributable to higher revenues, (ii) higher consulting expenses of $1.2 million primarily attributable to recruiting charges and interim staffing for certain senior and executive roles, (iii) higher public company compliance-related costs of $1.0 million consistent with our change in SEC filer status and (iv) higher information technology support costs of $0.4 million in support of our growth. These items were partially offset by lower stock-based compensation expense of $0.2 million as certain prior year awards were fully amortized and lower legal fees of $0.4 million. In addition, we incurred less than $0.1 million of severance charges in 2024 associated with certain restructuring activities at our assembly facilities. The 2023 period included a restructuring charge of $1.2 million associated with a previously disclosed compensation arrangement with our former CEO who served in an interim role from mid-November of 2022 through mid-February of 2024.
Depreciation and Amortization
Depreciation and amortization expenses reflect the depreciation of our rental compressor fleet as well as the depreciation and amortization of our operating and corporate facilities, vehicles and other equipment, and the amortization of finance leases and intangible assets.
The following table summarizes the components of our depreciation and amortization expenses for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Depreciation and amortization allocable to cost of revenues:
Rental $ 30,453 $ 25,507 $ 4,946 19.4 %
Sales 296 260 36 13.8 %
Aftermarket services 64 89 (25) (28.1) %
30,813 25,856 4,957 19.2 %
Corporate depreciation 413 569 (156) (27.4) %
Intangible asset amortization 121 125 (4) (3.2) %
Total $ 31,347 $ 26,550 $ 4,797 18.1 %
Depreciation and amortization as a percent of total revenues 20.0 % 21.9 % (1.9) %
Depreciation and amortization expense increased on an absolute basis and declined as a percent of revenues during the year ended December 31, 2024, compared to 2023. The increase is primarily the result of new units added to our rental fleet in 2024 and 2023. We placed into service 22 high horsepower units (approximately 28,740 horsepower) to our fleet in 2024 and 92 units (approximately 98,349 horsepower) in 2023. All 22 in 2024 and 73 of those units in 2023, were 400 horsepower or larger, representing a substantial portion of the total horsepower added during each year, respectively. These higher horsepower unit additions, which began in earnest during 2023, are reflective of our strategic plans to concentrate our business development on these higher margin applications.
Impairments
We assess our long-lived assets for impairment on an annual basis or when indicators of impairment are present. An impairment loss is recognized if the future undiscounted cash flows associated with the asset (or asset group) and the estimated fair value of the asset are less than the asset’s carrying value.
The following table indicates the charges incurred for impairments for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Impairments $ 841 $ 779 $ 62 8.0 %
During 2024, we fully impaired an intangible asset attributable to a trade name for $0.7 million. Consistent with our shift in focus away from the sales of compressor and related technology, we determined that we will no longer market the technology associated with the trade name. Please see Note 8 (“Intangible Assets”) to our Consolidated Financial Statements for additional information. In addition, we fully impaired certain information technology assets in the amount of $0.2 million for which we have terminated plans to develop and utilize the associated applications. During 2023, we fully impaired certain information technology assets in the amount of $0.8 million under similar circumstances.
Inventory Allowance
We routinely review our stock of inventory for obsolescence and realizability. When the carrying value exceeds the net realizable value, a charge is recorded to operating income.
The following table indicates the charges incurred for inventory allowance for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Inventory allowance $ 1,863 $ 3,965 $ (2,102) (53.0) %
Due primarily to the slow-moving nature, obsolescence of a portion of our long-term inventory and inventory related to the retirement of certain rental equipment, we recorded an increase of $1.9 million to the inventory allowance reserve for the year ended December 31, 2024. During 2023, we recorded an increase of $4.0 million to the inventory allowance reserve under similar circumstances as well as our decision to cease further assembly activities at our facility in Midland, Texas. We ended 2024 with an inventory allowance balance of $5.9 million. Please see Note 4 (“Inventory”) to our Consolidated Financial Statements for additional information regarding the inventory allowance.
Retirement of Rental Equipment
We routinely review the rental fleet to determine which units are no longer of the type, configuration, make or model that our customers are demanding or that are not cost efficient to refurbish, maintain and/or operate. When appropriate, we retire such units from the fleet and write-off any remaining carrying value.
The following table indicates the charges incurred for the retirement of rental equipment for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Retirement of rental equipment $ 28 $ 505 $ (477) NM
Retirements of compressor units during 2024 were minimal as compared to 2023 during which time we determined 95 units should be retired from our rental fleet for which we recorded loss on retirement of rental equipment during the year.
Gain on the Sale of Property and Equipment
As circumstances warrant, we will market certain property and equipment, primarily trucks, when we have determined that there is no longer a productive use for such assets or favorable opportunities arise to monetize otherwise idle assets. Gains and losses are recognized accordingly upon the completion of such transactions.
The following table presents the gains recognized upon the sale of property and equipment for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Gain on the sale of property and equipment, net $ 430 $ 481 $ (51) (10.6) %
Gains recognized during the years ended December 31, 2024 and 2023 are primarily attributable to the sales of trucks after the completion of their useful lives. In addition, amounts are included during both years for sales scrap materials.
Interest Expense
Interest expense primarily reflects the costs of borrowing, including commitment fees and the amortization of debt issue costs, under our Credit Facility, net of amounts capitalized attributable to certain capital projects. Also included is interest expense on our financing leases.
The following table summarizes the components of our interest expense for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Interest on borrowings, finance leases and related fees $ 15,904 $ 9,156 $ 6,748 73.7 %
Amortization of debt issue costs 746 425 321 75.5 %
Capitalized interest (4,723) (5,499) 776 (14.1) %
Total $ 11,927 $ 4,082 $ 7,845 NM
Weighted-average interest rates on borrowings 8.82 % 8.88 % (0.06) %
Weighted-average outstanding borrowings $ 169,008 $ 120,558 $ 48,450
Interest expense increased during the year ended December 31, 2024 as compared to 2023 due primarily to over $48 million of higher average borrowings outstanding under our Credit Facility during 2024. In addition, we incurred higher debt issue cost amortization due primarily to costs associated with amendments to the Credit Facility and lower capitalized interest as a result of a smaller capital expenditures program in 2024 as compared to 2023. These increases were marginally offset by the effect of lower average interest rates which declined in the second half of 2024 consistent with Federal Reserve interest rate reductions.
Other Income (Expense)
This caption primarily reflects non-operating items of income and loss including non-cash gains and losses attributable to our corporate-owned life insurance (“COLI”) policies related to our deferred compensation plan. Please see Note 12 (“Deferred Compensation Plan”) to our Consolidated Financial Statements for additional information regarding the plan.
The following table indicates our other income (expense) for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Other income (expense), net $ 268 $ 245 $ 23 9.4 %
Other income was relatively consistent during the year ended December 31, 2024 as compared to 2023 with net gains from investments supporting our COLI policies comprising the majority of the amounts for each period. Other amounts include certain vendor rebates and other miscellaneous non-operating income.
Income Tax Expense
Income tax expense represents our income tax provision as determined in accordance with GAAP. It considers taxes attributable to our obligations for federal taxes under the IRC as well as to various states in which we operate, primarily Texas. Please see Note 11 (“Income Taxes”) to our Consolidated Financial Statements for additional information.
The following table summarizes our income tax provision for the periods presented:
Year Ended December 31,
2024 2023 Change % Change
Income tax expense $ 4,439 $ 1,873 $ 2,566 NM
Effective tax rate 20.5 % 28.3 % (7.80) %
Income tax expense increased for the year ended December 31, 2024, compared to 2023 due primarily to substantially higher pre-tax income during 2024 despite a lower effective tax rate. Our effective tax rate for both years differs from the U.S. federal statutory rate of 21%. The effective tax rate declined during 2024 from that during 2023 largely due to certain executive severance compensation expenses incurred during 2023 that were non-deductible for income tax purposes. Only a minimal portion of our total income tax expense is current while $4.2 million and $1.8 million is considered deferred for 2024 and 2023, respectively.
Financial Condition
Liquidity and Capital Resources
Our primary sources of liquidity include cash on hand, cash provided by operating activities and borrowings under our Credit Facility. The Credit Facility provides us with up to $300 million in borrowing commitments with an additional $50 million at our request. The borrowing base under the Credit Facility was $300.0 million with $168.0 million of borrowings outstanding as of March 14, 2025, leaving $132.0 million of availability under the Credit Facility.
Our cash flows from operating and investing activities are subject to a degree of volatility due primarily to (i) the consistency of our customers in remitting amounts owed to us for our services in full and on a timely basis and (ii) the timing of payments to our vendors and suppliers for capital projects which are often made well in advance of placing new compressor equipment into service. In order to mitigate such volatility we employ disciplined efforts to monitor customer credit and maintain communications to support collection efforts when necessary. Furthermore, and in certain circumstances, we require deposits in advance of transactions that require substantial investment on our part. To the extent necessary, we rely on the availability of our Credit Facility to fund capital expenditures beyond that provided by our cash flows from operating activities.
Our forecasted capital expenditures for 2025 will continue to be directly dependent upon our customers’ compression requirements and our capital availability, while maintaining prudent levels of debt.
The level of our capital expenditures will vary in future periods depending on energy market conditions and other related economic factors. Based upon existing economic and market conditions, we believe that cash on hand, cash flows from operating activities and borrowings under the Credit Facility will be sufficient to satisfy our capital and liquidity requirements for at least the twelve months subsequent to the date that this Annual Report on Form 10-K was filed. We also believe we have flexibility with respect to our financing alternatives and adjustments to our capital expenditure plans if circumstances warrant. We do not have any material continuing commitments related to our current operations that cannot be met with our cash on hand, cash from operating activities and borrowings under our Credit Facility.
If we require additional capital to fund any significant unanticipated expenditures, including any material acquisitions of other businesses, joint ventures or other opportunities, this additional capital could exceed our current resources and might not be available to us when we need it, or might not be on acceptable terms. In addition, our financing capacity could be negatively impacted by other economic factors. Please see Part I, Item 1A, “Risk Factors”, of this Report.
For a detailed analysis of our historical capital expenditures, see the “Cash Flows” discussion that follows.
Cash From Operating Activities. As of December 31, 2024, we had $2.1 million of cash on hand. For additional information and an analysis of or historical cash flows from operating activities, see the “Cash Flows” discussion that follows.
Credit Facility Borrowings. During 2024, we borrowed $6.0 million, net of repayments, under the Credit Facility. Through March 14, 2025, we repaid $2.0 million, net of borrowings under the Credit Facility. The following table summarizes our borrowing activity under the Credit facility for the periods presented:
Borrowings Outstanding
End of Period Weighted-average Maximum Weighted-average Rate
Three months ended December 31, 2024 $ 170,000 $ 172,230 $ 180,000 8.47 %
Year ended December 31. 2024 $ 170,000 $ 169,008 $ 180,000 8.83 %
For additional information regarding the terms and covenants under the Credit Facility, see the “Capitalization” discussion that follows.
Proceeds from Sales and Monetization of Assets. We continually evaluate the potential sale of assets, including underutilized or retired compressor units, obsolete and slow-moving inventory and non-strategic real estate assets, among others. For additional information and an analysis of or historical proceeds from sales of assets, see the “Cash Flows” discussion that follows.
Capital Markets Transactions. From time-to-time and under market conditions that we believe are favorable to us, we may consider capital markets transactions, including the offering of debt and equity securities. We maintain an effective shelf registration statement with the SEC for up to $200 million for a variety of securities to provide financing optionality.
Cash Flows
The following table summarizes our cash flows for the periods presented:
Year Ended December 31,
2024 2023
Net cash provided by operating activities $ 66,463 $ 18,033
Net cash used in investing activities (71,440) (153,888)
Net cash provided by financing activities 4,373 135,229
Net decrease in cash and cash equivalents $ (604) $ (626)
Cash Flows from Operating Activities. Our cash flows from operating activities increased by $48.4 million during 2024 from 2023. From a broad perspective, cash flows improved due to substantial growth in our high horsepower unit rentals which also provide for higher realized margins. In addition, we made substantial progress in improving our processes for billings and collections from certain customers and lowering our “days sales outstanding” statistics for accounts receivable. These efforts arose from the negative impact on working capital during 2023 as our rental activities began to grow significantly. We anticipate a continued focus on these efforts into 2025 as we concentrate on further improvements to our working capital performance statistics.
Cash Flows from Investing Activities. For the years ended December 31, 2024 and 2023, we invested approximately $71.9 million and $153.9 million, respectively, in rental equipment, property and other equipment. Included in these totals for 2024 and 2023 were $66.9 million and $152.5 million in new equipment to our rental fleet and $5.0 million and $1.4 million in other property and equipment, respectively. Our investment in rental equipment includes any changes to work-in-progress related to our rental fleet projects at the beginning of the year compared to the end of the year. Our rental work-in-progress increased by $0.8 million and $13.8 million during 2024 and 2023, respectively. We paid $0.2 million and $0.4 million for COLI policy purchases during 2024 and 2023. We also received proceeds from the sale of property and equipment of $0.5 million and $0.5 million during the same periods, respectively.
Cash Flows from Financing Activities. During 2024, we had net borrowings of $6.0 million under the Credit Facility while 2023 included net borrowings of $139.0 million. The decrease in net borrowings is due primarily to the substantial investment in large horsepower units during the prior year consistent with our strategy of directing our business to these larger, higher margin applications. While we incurred and paid debt issuance costs during both years, the amounts paid during 2023 were $1.7 million higher as the Credit Facility was substantially upsized with the amendment and restatement in February 2023. We received proceeds from the exercise of stock options of $0.3 million during 2024 while none were received during 2023 and taxes paid related to the net share settlements of equity awards were $0.2 million and $1.0 million for 2024 and 2023, respectively.
Capitalization
The following table summarizes our total capitalization as of the dates presented:
December 31,
2024 2023
Credit facility borrowings $ 170,000 $ 164,000
Total stockholders’ equity
255,057 235,894
Total capitalization $ 425,057 $ 399,894
Debt as a percent of total capitalization 40.0 % 41.0 %
Credit Facility. We have a five-year senior secured revolving credit agreement, as amended, or the Credit Facility, with Texas Capital Bank, National Association (the “Lender”) as administrative agent, TCBI Securities, Inc., as joint lead arranger and sole book runner and Bank of America, N.A., as joint lead arranger, with a total commitment of $300.0 million. We also have a right to request from the Lender, an increase to the potential aggregate commitment of up to $50.0 million; provided, however, the aggregate commitment amount is not permitted to exceed $350.0 million. The obligations under the Credit Facility are secured by a first priority lien on most of our assets, including inventory and certain accounts receivable as well as a variable number of our leased compressor units. The maturity date of the Credit Facility is February 28, 2028.
Our Credit Facility is subject to: (i) a borrowing base calculation, (ii) variable rates of interest on borrowings that are determined, in part, upon our actual leverage ratio, as defined in the Credit Facility, (iii) commitment fees, (iv) certain financial and other covenants and (v) events of default and acceleration, among other terms and conditions that are customary for such credit instruments. Please see Note 10 (“Long-Term Debt”) to our Consolidated Financial Statements for a thorough discussion of these matters regarding our Credit Facility.
As of December 31, 2024, we had $170.0 million outstanding under our Credit Facility with a weighted average interest rate of 8.12%. As of December 31, 2024, we had approximately $130.0 million available for borrowing under the Credit Facility, subject to borrowing base determination. As of December 31, 2024, we were in compliance with all financial covenants in our Credit Facility.
Critical Accounting Estimates
We describe our significant accounting policies in Note 2 (“Summary of Significant Accounting Policies”) to our Consolidated Financial Statements. We believe that the application of these policies on a consistent basis enables us to provide the users of our financial statements with useful and reliable information regarding our results of operations, financial condition and cash flows.
The preparation of our Consolidated Financial Statements in conformity with GAAP requires us to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenue, expenses and related disclosures. In the ordinary course of business, we have made a number of estimates and assumptions relating to the reporting of results of operations and financial condition in the preparation of our Consolidated Financial Statements. We evaluate our estimates and assumptions on an ongoing basis. Our estimates are generally based on historical experience and various other assumptions that we believe to be reasonable in consideration of our circumstances and expectations for the future based on available information. Our actual results could differ significantly from those estimates under different assumptions and conditions.
We consider an accounting estimate to be critical if: (i) the accounting estimate requires us to make assumptions about matters that were highly uncertain at the time the accounting estimate was made, and (ii) changes in the estimate that are reasonably likely to occur from period to period or use of different estimates that we reasonably could have used in the current period, would have a material impact on our financial condition or results of operations.
We believe that the following discussion addresses our most critical accounting estimates, which are those that are most important to the portrayal of our results of operations, financial condition and cash flows and require our most difficult, subjective, and complex judgments, often as a result of the need to make estimates about the effect of matters that are inherently uncertain.
Inventories
We value our total inventory (current and long-term) at the lower of the actual cost and net realizable value. We regularly review inventory quantities on hand and record an allowance for excess and obsolete inventory based primarily on current and anticipated customer demand and production requirements. We assess anticipated customer demand based on current and upcoming capital expenditure budgets of our major customers as well as other significant participants in the industry, along with oil and gas price forecasts and other factors affecting the industry as a whole. Our estimates and assumptions regarding these factors are subject to significant variability and can result in provisions for valuation allowances of our inventory. For the year ended December 31, 2024, our provision for excess and obsolete inventory totaled $1.9 million which increased our allowance for obsolescence to $5.9 million as described more fully in the discussion of our Results of Operations above and Note 4 (“Inventory”) to our Consolidated Financial Statements.
Long-Lived Assets
Depreciation
Depreciation expense is computed using the straight-line method over the estimated useful lives of the underlying long-lived assets. Our rental equipment has estimated useful lives ranging from 15 to 25 years, while our property and equipment has estimated useful lives which range from 3 to 39 years. The estimated useful lives and salvage values of these long-lived assets are based on estimates and assumptions that reflect our historical experience and expectations regarding their future utilization, obsolescence, technical developments, market demand and geographic location. The use of different estimates and assumptions in the determination of depreciation, particularly with respect to useful lives, could result in significant differences to our results of operations. We regularly review the appropriateness of the estimated useful lives of our long-lived assets and may shorten or extend such lives as appropriate based on business circumstances.
Impairments
We assess our long-lived assets, including rental equipment, other property and equipment and intangible assets for impairment whenever events or changes in circumstances indicate that the net carrying values may not be recoverable. The following factors could trigger an impairment review: significant underperformance relative to historical or projected future cash flows; significant adverse changes in the extent or manner in which an asset (or asset group) is being used or its condition, including a meaningful decline in fleet utilization over prior periods; significant negative industry or company-specific trends or actions, including meaningful capital expenditure budget reductions by our major customers or other sizable exploration and production or midstream organizations, as well as significant declines in oil and natural gas prices; legislative changes prohibiting us from leasing our units; or poor general economic conditions. After the assessments of such circumstances, an impairment loss is recognized if the future undiscounted net cash flows associated with the asset (or asset group) and the estimated fair value of the asset are less than the asset’s (or asset group’s) carrying value. During the year ended December 31, 2024, we fully impaired our indefinite-lived intangible asset attributable to a trade name (see the discussion in “Results of Operations” above and Note 8. (“Intangible Assets”) to our Consolidated Financial Statements).
Income Taxes
In connection with the process of preparing our financial statements, we are required to estimate our federal income taxes as well as income taxes in each of the states in which we operate. This process involves us estimating our actual current tax exposure together with assessing temporary differences resulting from differing treatment of items for income tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are reflected on our Consolidated Balance Sheets. We must then assess the likelihood that our deferred tax assets will be recovered from future taxable income and, to the extent we believe that recovery is not probable, we must establish a valuation allowance. To the extent we establish a valuation allowance or increase this allowance during a period, we must include an expense in the tax provision in the Statement of Operations.
Significant management judgment is required in determining our provision for income taxes, our deferred tax assets and liabilities and any valuation allowance recorded against our net deferred tax assets. In this process, we consider all available positive and negative evidence including scheduled reversals of deferred tax liabilities, projected future taxable income, tax planning strategies and recent results of operations. As of December 31, 2024, we have no valuation allowance and fully expect to utilize all of our deferred tax assets.
Please see Note 11 (“Income Taxes”) for a more thorough discussion of our income taxes.
Off-Balance Sheet Arrangements
From time-to-time, we enter into off-balance sheet arrangements and transactions that can give rise to off-balance sheet obligations. As of December 31, 2024, we did not have any material off-balance sheet arrangements.
Recently Issued Accounting Pronouncements
Please see Note 2 (“Summary of Significant Accounting Policies”) to our Consolidated Financial statements for a discussion of recently issued accounting pronouncements.

---

ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
Market risk is the risk of loss arising from adverse changes in market rates and prices. The principal market risk to which we are exposed is interest rate risk.
Our interest rate risk is attributable to our borrowings under the Credit Facility, which are subject to variable interest rates. As of December 31, 2024, we had borrowings of $170.0 million under the Credit Facility at a weighted average interest rate of 8.12%. Assuming a constant borrowing level under the Credit Facility and excluding any changes in other financial metrics that would impact the applicable margin applied to Credit Facility borrowings, an increase (decrease) in the interest rate of one percent would result in an increase (decrease) in interest expense of $1.7 million on an annual basis.

---

ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The information required by this Item is presented in Part IV, Item 15. “Exhibits and Financial Statement Schedules” of this Annual Report on Form 10-K.

---

ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.

---

ITEM 9A. CONTROLS AND PROCEDURES
ITEM 9A. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
Our management, with the participation of our Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”), evaluated the effectiveness of our disclosure controls and procedures as of December 31, 2024. We maintain “disclosure controls and procedures,” as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act, that are designed to ensure that information required to be disclosed in the reports that we file or submit under the Exchange Act is (i) recorded, processed, summarized and reported, within the time periods specified in the SEC’s rules and forms and (ii) accumulated and communicated to our management, including our principal executive officer and principal financial officer, to allow timely decisions regarding required disclosure. Based upon the evaluation, our CEO and CFO concluded that, as of such date, our disclosure controls and procedures were effective to provide reasonable assurance that the information required to be disclosed in reports that we file or submit under the Exchange Act is accumulated and communicated to management, and made known to our CEO and CFO, on a timely basis to ensure that it is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms.
Management’s Annual Report on Internal Control Over Financial Reporting
Our management, including the CEO and CFO, is responsible for establishing and maintaining adequate internal control over financial reporting (“ICFR”), as defined in Rule 13a-15(f) and 15d-15(f) under the Exchange Act. Our management conducted an evaluation of the effectiveness of the Company’s internal control over financial reporting as of December 31, 2024, based on the Internal Control - Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission (COSO). 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. Based on the results of management’s evaluation described above, management concluded that our ICFR was effective as of December 31, 2024.
Remediation of Previously Identified Material Weakness
As previously reported in Part II, Item 9A. “Controls and Procedures” of our Annual Report on Form 10-K for the year ended December 31, 2023, we disclosed a material weakness related to inventory. Specifically, control activities related to year-end inventory count procedures and the process to review and approve inventory adjusting journal entries.
We have completed the execution of our remediation plan for this material weakness and, as of December 31, 2024, successfully remediated the material weakness by implementing and successfully testing the following actions:
•We updated and implemented new policies and procedures related to work in process inventory.
•We hired additional management with a focus on inventory control and inventory best practices.
•We relocated certain inventory to centralized warehouses.
•We improved and enforced our formalized inventory count and inventory adjustment procedures which were applied to our end-of-year inventory counts.
•We added additional inventory safeguards in our warehouses limiting physical access to our inventory.
•We limited the number of employees authorized to record adjustments in our accounting software through additional IT controls with respect to inventory transfers.
•We have enhanced efforts to ensure our employees understand the importance of internal controls and compliance with corporate policies and procedures.
Attestation Report of the Registered Public Accounting Firm
The effectiveness of ICFR as of December 31, 2024 was audited by Ham, Langston & Brezina LLP, an independent registered public accounting firm, as stated in its report included in Part IV, Item 15 “Exhibits and Financial Statement Schedules” of this Annual Report on Form 10-K.
Changes in Internal Control Over Financial Reporting
During the year ended December 31, 2024, except as discussed above, there were no other changes in our ICFR during the year ended December 31, 2024, that have materially affected, or are reasonably likely to materially affect, our ICFR.

---

ITEM 9B. OTHER INFORMATION
ITEM 9B. OTHER INFORMATION
Stephen C. Taylor, our Chairman of the Board of Directors, adopted a Rule 10b5-1 trading agreement that is intended to satisfy the affirmative defense of Rule 10b5-1(c) for the sale of up to an aggregate of 100,000 shares of the Company’s common stock, subject to various volume amounts and price thresholds. The plan became effective on August 21, 2024 and the plan provided that it would terminate on August 19, 2025, unless sooner terminated under its terms. The 10b5-1 Plan was entered into during an open insider trading window and no sales commenced under the plan until completion of the required cooling off period under Rule 10b5-1. The 10b5-1 Plan terminated pursuant to its terms on or about January 21, 2025, in connection with the final sale of shares covered by the plan.
No other director or officer of the Company adopted, modified or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408(a) of Regulation S-K, during the three months ended December 31, 2024.

---

ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
The information required by this item is incorporated herein by reference to the sections “Election of Directors,” “Executive Officers,” “Corporate Governance” and “The Board of Directors and its Committees” in our definitive proxy statement which will be filed with the SEC within 120 days after December 31, 2024 or as such period may be extended by action of the SEC.
We have adopted a Code of Business Conduct and Ethics that applies to our directors, officers and employees. The Code of Business Conduct and Ethics is posted in the “Investor Relations” section of our website at www.ngsgi.com. The Code of Business Conduct and Ethics maybe obtained free of charge by writing before to Natural Gas Services Group, Inc., Attn: Investor Relations, 404 Veterans Airpark Lane, Ste 300, Midland, TX 79705.

---

ITEM 11. EXECUTIVE COMPENSATION
ITEM 11. EXECUTIVE COMPENSATION
The information required by this item is incorporated herein by reference to the section “Executive Compensation” in our definitive proxy statement which will be filed with the SEC within 120 days after December 31, 2024 or as such period may be extended by action of the SEC.

---

ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND
RELATED STOCKHOLDER MATTERS
The information required by this item is incorporated herein by reference to the section “Principal Shareholders and Security Ownership of Management” in our definitive proxy statement which will be filed with the SEC within 120 days after December 31, 2024 or as such period may be extended by action of the SEC.

---

ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
The information required by this item is incorporated herein by reference to the sections “Related Person Transactions” and “Corporate Governance” in our definitive proxy statement which will be filed with the SEC within 120 days after December 31, 2024 or as such period may be extended by action of the SEC.

---

ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
ITEM 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
The information required by this item is incorporated herein by reference to the section “Principal Accountant Fees and Services” in our definitive proxy statement which will be filed with the SEC within 120 days after December 31, 2024 or as such period may be extended by action of the SEC.
PART IV

---

ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES
ITEM 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
(a) The following documents are filed as part of this Annual Report on Form 10-K.
1.Consolidated Financial Statements. The following financial statements are filed as a part of this Annual Report on Form 10-K:
Reports of Independent Registered Public Accounting Firm (PCAOB ID 298)
Consolidated Balance Sheets
Consolidated Statements of Operations
Consolidated Statements of Stockholders’ Equity
Consolidated Statements of Cash Flows
Notes to Consolidated Financial Statements
2. Financial Statement Schedules
All financial statement schedules have been omitted because they are not applicable or the information is set forth in the Consolidated Financial Statements or Notes thereto.
3. Exhibits
A list of exhibits to this Annual Report on Form 10-K is set forth below:
Exhibit No. Description
3.1
Articles of Incorporation, as amended (Incorporated by reference to Exhibit 3.1 of the 10-QSB filed with the Securities and Exchange Commission and dated November 10, 2004).
3.2
Bylaws, as amended (Incorporated by reference to Exhibit 3.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on February 10, 2021).
4.1
Description of Securities (Incorporated by reference to the Registrant’s Registration Statement on From 8-A, filed with the Securities and Exchange Commission on October 27, 2008).
4.2
Form of Senior Indenture (Incorporated by reference to Exhibit 4.2 of the Registrant’s Registration Statement on Form S-3 (No. 333-238794) and filed with the Securities and Exchange Commission on December 13, 2024).
4.3
Form of Subordinated Indenture (Incorporated by reference to Exhibit 4.4 of the Registrant’s Registration Statement on Form S-3 (No. 333-238794) and filed with the Securities and Exchange Commission on December 13, 2024).
10.1†
2019 Equity Incentive Plan, as amended (Incorporated by reference to Exhibit 4.3 of the Registrant’s Registration Statement on Form S-8 filed with the Securities and Exchange Commission on July 12, 2022).
10.2†
Stock Option Plan, as amended and restated (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on June 21, 2016).
10.3†
Retirement Agreement dated May 17, 2022 between Natural Gas Services Group, Inc. and Stephen C. Taylor (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on May 19, 2022).
10.4†
The Executive Nonqualified Excess Plan Adoption Agreement, referred to as the Nonqualified Deferred Compensation Plan (Incorporated by reference to Exhibit 10.11 of the Registrant’s Quarterly report on Form 10-Q filed with the Securities and Exchange Commission on May 6, 2016).
10.5
Amended and Restated Credit Agreement dated February 28, 2023, among Natural Gas Services Group, Inc., the other Loan Parties thereto, Texas Capital Bank, in its capacity as Administrative Agent and the Lenders party thereto (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on March 6, 2023).
10.6
Amended and Restated Pledge and Security Agreement dated February 28, 2023, among Natural Gas Services Group, Inc., the Grantors thereto, Texas Capital Bank, in its capacity as Administrative Agent, for the Lenders and other Secured Parties (Incorporated by reference to Exhibit 10.2 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on March 6, 2023).
10.7
First Amendment to Amended and Restated Credit Agreement dated November 14, 2023, among Natural Gas Services Group, Inc., the other Loan Parties thereto, Texas Capital Bank, in its capacity as Administrative Agent and the Lenders party thereto (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on November 15, 2023).
10.8
Second Amendment to Amended and Restated Credit Agreement dated June 6, 2024, among Natural Gas Services Group, Inc., the other Loan Parties thereto, Texas Capital Bank, in its capacity as Administrative Agent and the Lenders party thereto (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on June 10, 2024).
10.9
Third Amendment to Amended and Restated Credit Agreement dated June 25, 2024, among Natural Gas Services Group, Inc., the other Loan Parties thereto, Texas Capital Bank, in its capacity as Administrative Agent and the Lenders party thereto (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on June 28, 2024).
10.10†
Retention Agreement dated September 19, 2023 between Natural Gas Services Group, Inc. and James Hazlett (Incorporated by reference to Exhibit 10.11 of the Registrant’s Quarterly Report on Form 10-Q filed with the Securities and Exchange Commission on November 14, 2023).
10.11†
Employment Agreement between Brian L. Tucker and Natural Gas Services Group, Inc. dated October 9, 2023 (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on October 10, 2023).
10.12†
Employment Agreement between Justin C. Jacobs and Natural Gas Services Group, Inc. dated January 29, 2024 (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on February 1, 2024).
10.13†
Employee Non-Compete Agreement between Justin C. Jacobs and Natural Gas Services Group, Inc. dated January 29, 2024 (Incorporated by reference to Exhibit 10.2 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on February 1, 2024).
10.14†
Employee Proprietary Rights Agreement between Justin C. Jacobs and Natural Gas Services Group, Inc. dated January 29, 2024 (Incorporated by reference to Exhibit 10.2 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on February 1, 2024).
10.15†
Form of Restricted Stock Unit Award under the Natural Gas Services Group, Inc. 2019 Equity Incentive Plan, as amended (Incorporated by reference to Exhibit 10.12 of the Registrant’s Annual Report on Form 10-K filed with the Securities and Exchange Commission on April 1, 2024).
10.16†
Form of Performance Stock Unit Award under the Natural Gas Services Group, Inc. 2019 Equity Incentive Plan, as amended (Incorporated by reference to Exhibit 10.13 of the Registrant’s Annual Report on Form 10-K filed with the Securities and Exchange Commission on April 1, 2024).
10.17†
Employment Agreement between Ian M. Eckert and Natural Gas Services Group, Inc. dated November 1, 2024 (Incorporated by reference to Exhibit 10.1 of the Registrant’s Current Report on Form 8-K filed with the Securities and Exchange Commission on November 7, 2024).
19*
Amended and Restated Insider Trading Policy.
21.1*
Subsidiaries of the registrant.
23.1*
Consent of Ham, Langston & Brezina L.L.P.
31.1*
Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
31.2*
Certification of Principal Accounting Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002.
32.1*
Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
32.2*
Certification of Principal Accounting Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
97.1
Natural Gas Services Group, Inc. Clawback Policy (Incorporated by reference to Exhibit 97.1 of the Registrant’s Annual Report on Form 10-K filed with the Securities and Exchange Commission on April 1, 2024).
101.INS XBRL Instance Document.
101.SCH XBRL Taxonomy Extension Schema Document.
101.CAL XBRL Taxonomy Extension Calculation Linkbase Document.
101.DEF XBRL Taxonomy Extension Definition Linkbase Document.
101.LAB XBRL Taxonomy Extension Label Linkbase Document.
101.PRE XBRL Taxonomy Extension Presentation Linkbase Document.
† Management contract or compensatory plan or arrangement.
* Filed herewith.