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.
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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.
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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.
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• 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.
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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.
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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.
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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.
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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.
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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.
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Water Discharge
Clean Water Act . The Clean Water Act ( “C WA ” ) 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.
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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.
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