UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K10-K/A
(Mark One)
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| ☑ | ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the fiscal year endedFiscal Year Ended December 31, 2021
orOr
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| ☐ | TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 |
For the transition period from________________________to__________________________
Commission file number: 1-31398File No. 001-35049
NATURAL GAS SERVICES GROUP, INC.
(Exact Namename of Registrantregistrant as Specifiedspecified in its Charter)charter)
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| Colorado | | 75-2811855 |
(State or other jurisdiction of incorporation or organization) | | (I.R.S. Employer Identification No.) |
404 Veterans Airpark Lane, Suite 300
Midland, Texas 79705
(Address of principal executive offices and zip code)
Registrant’s telephone number, including area code: (432) 262-2700
Securities registered pursuant to Section 12(b) of the Act:
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404 Veterans Airpark Lane, Suite 300, Midland, Texas | | 79705 |
(Address of principal executive offices) | | (Zip Code) |
Registrant’s telephone number, including area code: | | (432) 262-2700 |
Securities registered pursuant to Section 12(b) of the Act: |
| Title of each class | Trading Symbol(s)Symbol | Name of each exchange on which registered |
Common Stock, $.01$0.01 par value per share | NGS | New York Stock Exchange (NYSE) |
Securities registered pursuant to sectionunder Section 12(g) of the Act: None.
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
Yes ☐ No ☒☑
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Exchange Act.
Yes ☐ No ☒☑
Indicate by check mark whether the registrant:registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to suchthe filing requirements for the past 90 days.
Yes ☒☑ No ☐
Indicate by check mark whether the registrant has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§40232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files).
Yes ☒☑ No ☐
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K is not contained herein, and will not be contained, to the best of registrant’s knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. Yes ☐ No ☒
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company, or an emerging growth company. See definitionthe definitions of “accelerated filer and large“large accelerated filer”, “accelerated filer”, “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act. Act:
(Check one):
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| Large accelerated filer | ☐ | | Accelerated filer | | ☐ |
Non-accelerated filer ☒ | ☑ | | Smaller reporting company ☒ | | ☑ |
Emerging growth company Company | ☐ |
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Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).PCAOB Firm ID: 659 Auditor Name: Moss Adams, LLP Auditor Location: Dallas, Texas
Yes ☐ No ☒
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☐
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☑
The aggregate market value of voting and non-voting common equity held by non-affiliates of the Registrant as of June 30, 2021 was approximately $129,415,763 based on the closing price of the common stock on that date on the New York Stock Exchange.
At March 14, 2022, there were 12,717,486 shares of the Registrant's common stock outstanding.
Documents incorporatedDOCUMENTS INCORPORATED BY REFERENCE
None.
EXPLANATORY NOTE
This Form 10-K/A (this “Amendment”) amends Natural Gas Services Group, Inc.’s (“Naturas Gas Services Group” and together with our consolidated subsidiaries, the “Company,” “our,” “we,” “us,” or similar terms) Annual Report on Form 10-K for the year ended December 31, 2021 (the “Original 10-K”), which was filed with the Securities and Exchange Commission (the “SEC”) on March 18, 2022. The Company is filing this Amendment for the sole purpose of providing the information required by reference
Certain information called for in Items 10 11, 12, 13 andthrough 14 of Part III are incorporatedof Form 10-K. This information was previously omitted from the Original 10-K in reliance on General Instruction G.(3) to Form 10-K. The reference on the cover page of the Original 10-K to the incorporation by reference to the registrant’sportions of our definitive proxy statement forinto Part III of the annual meetingOriginal 10-K is hereby deleted.
In accordance with Rule 12b-15 under the Securities Exchange Act of shareholders expected1934, as amended (the “Exchange Act”), Part III, Items 10 through 14, of the Original 10-K are hereby amended and restated in their entirety.In addition, in connection with the filing of this Amendment and pursuant to be held on June 16, 2022.the rules of the SEC, we are including with this Amendment new certifications of our principal executive officer and principal financial officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002. Accordingly, Item 15 of Part IV has also been amended and restated to reflect the filings of these new certifications. Because no financial statements are contained within this Amendment, we are not including certifications pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
Except as otherwise noted, this Amendment speaks as of the filing date of the Original 10-K and reflects only the changes to the cover page, Items 10 through 14 of Part III and Item 15 of Part IV. No other information included in the Original 10-K, including the information set forth in Part I and Part II, has been modified or updated in any way, and we have not updated the disclosures contained herein to reflect any events which occurred subsequent to the filing of the Original 10-K or to modify the disclosure contained in the Original 10-K other than to reflect the changes described above.
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FORM 10-K |
NATURAL GAS SERVICES GROUP, INC. |
TABLE OF CONTENTS |
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Item 16. | Form 10-K Summary | |
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SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS
This Annual Report on Form 10-K contains certain forward-looking statements, within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934, as amended, and information pertaining to us, our industry and the oil and natural gas industry that is based on the beliefs of our management, as well as assumptions made by and information currently available to our management. All statements, other than statements of historical facts contained in this Annual Report on Form 10-K, including statements regarding our future financial position, growth strategy, budgets, projected costs, plans and objectives of management for future operations, are forward-looking statements. We use the words “may,” “will,” “expect,” “anticipate,” “estimate,” “believe,” “continue,” “intend,” “plan,” “budget” and other similar words to identify forward-looking statements. You should read statements that contain these words carefully and should not place undue reliance on these statements because they discuss future expectations, contain projections of results of operations or of our financial condition and/or state other “forward-looking” information. We do not undertake any obligation to update or revise publicly any forward-looking statements. Although we believe our expectations reflected in these forward-looking statements are based on reasonable assumptions, no assurance can be given that these expectations or assumptions will prove to have been correct. Important factors that could cause actual results to differ materially from the expectations reflected in the forward-looking statements include, but are not limited to, the following factors and the other factors described in this Annual Report on Form 10-K under the caption “Risk Factors”:
•significant economic disruptions and adverse consequences resulting from current and possible long-term effects of the COVID-19 global pandemic;
•conditions in the oil and natural gas industry, including the supply and demand for natural gas and wide fluctuations in the prices of oil and natural gas;
•regulation or prohibition of new well completion techniques;
•competition among the various providers of compression services and products;
•changes in safety, health and environmental regulations;
•changes in economic or political conditions in the markets in which we operate;
•failure of our customers to continue to rent equipment after expiration of the primary rental term;
•the inherent risks associated with our operations, such as equipment defects, malfunctions and natural disasters;
•our inability to comply with covenants in our debt agreements and the decreased financial flexibility associated with our debt;
•future capital requirements and availability of financing;
•fabrication and manufacturing costs;
•general economic conditions;
•acts of terrorism; and
•fluctuations in interest rates.
We believe that it is important to communicate our expectations of future performance to our investors. However, events may occur in the future that we are unable to accurately predict or that we are unable to control. When considering our forward-looking statements, you should keep in mind the risk factors and other cautionary statements in this Annual Report on Form 10-K.
Glossary of Industry Terms
"CiP" - A branded gas compressor product line designed, manufactured and packaged by the Company. The 'Cylinder in Plane' design results in a compact and vibration-free compressor unit that particularly lends itself to unconventional wellhead applications, air compression and compressed natural gas requirements.
"flare" – A tall stack equipped with burners used as a safety device at wellheads, refining facilities, gas processing plants, and chemical plants. Flares are used for the combustion and disposal of combustible gases. The gases are piped to a remote, usually elevated, location and burned in an open flame in the open air using a specially designed burner tip, auxiliary fuel, and steam or air. Combustible gases are flared most often due to emergency relief, overpressure, process upsets, startups,
shutdowns and other operational safety reasons. Natural gas that is uneconomical for sale is also flared. Often natural gas is flared as a result of the unavailability of a method for transporting such gas to markets.
"gas lift" – A production enhancement technique whereby natural gas is injected into an oil well to increase/improve the oil production.
"oil shale" – Also referred to as tight oil, is petroleum that consists of light crude oil contained in petroleum-bearing formations of low-permeability, often shale or tight sandstone.
"reciprocating compressors" – A reciprocating compressor is a type of compressor which compresses vapor by using a piston in a cylinder and a back-and-forth motion.
"screw compressors" – A type of compressor used in low-pressure and vapor compression applications where two intermesh rotors create pockets of continuously decreasing volume, in which the gas is compressed and its pressure is increased.
PART IIII
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,” “our” or “ours” refer to Natural Gas Services Group, Inc. Certain specialized terms used in describing our natural gas compressor business are defined in "Glossary of Industry Terms" on page i.
Smaller Reporting Company
We are a “smaller reporting company” as defined by the SEC. As such, we are eligible to comply with the scaled disclosure requirements in several Regulation S-KItem 10.Directors, Executive Officers and Regulation S-X items. Our disclosures in this Annual Report reflect these scaled requirements.
The Company
We are a provider of natural gas compression equipment and services to the energy industry. We manufacture, fabricate, rent, sell and maintain natural gas compressors and flare systems for oil and natural gas production and plant facilities. We are headquartered in Midland, Texas, with fabrication facilities located in Tulsa, Oklahoma and Midland, Texas, and service facilities located in major oil and natural gas producing basins in the U.S.
We have shifted our focus over the last several years to medium to large horsepower applications that apply to natural gas associated with oil-weighted production. Our primary customers are exploration and production companies that utilize our compressor units for artificial lift applications, i.e., production enhancement enabled with high-pressure gas compression equipment, on unconventional oil wells on single and multi-well pads. In addition, our customer base includes oil and natural gas exploration and production ("E&P") companies that are focused on natural gas-weighted production (with typically smaller horsepower applications) as well as midstream companies. The Company's largest rental area is the Permian Basin (approximately 51.8% of rental revenues in 2021), with the large majority of its remaining rental revenue being generated in other oil and natural gas producing regions and plays in Texas, New Mexico and Oklahoma, including the San Juan Basin, the Texas Panhandle/western Oklahoma, the Barnett Shale, and central Oklahoma. Other regions and plays in which we provide service include the Utica and Marcellus Shales, Michigan and the DJ Basin.
Our revenue increased 6.4% to $72.4 million for the year ended December 31, 2021 from $68.1 million for the year ended December 31, 2020. This increase was largely the result of our rental revenues increasing 4.6% to $63.6 million in 2021 from $60.8 million in 2020 as well as sales revenue increasing 21.7% to $6.9 million in 2021 from $5.7 million in 2020. For the year ended December 31, 2021 the Company reported a net loss of $9.2 million as compared to net income of $1.8 million for the year ended December 31, 2020. In addition, the Company's adjusted earnings before interest, taxes, depreciation and amortization ("EBITDA") decreased 24.8% to $18.7 million in 2021 from $24.9 million in 2020. See "Item 6, Selected Financial Data, Non-GAAP Financial Measures" for a reconciliation of adjusted EBITDA to its closest GAAP financial measure, net (loss) income.
At December 31, 2021, current assets were $65.1 million, which included $22.9 million of cash and cash equivalents. Current liabilities were $20.3 million at year end 2021. Our stockholders' equityfollowing table sets forth, as of December 31, 2021, was $235.9 million.certain information regarding our executive officers.
Please see "Item 7, Management's Discussion and Analysis of Financial Condition and Results of Operations" for further information.
Our Operating Units
We identify our operating units based upon major revenue sources as Rental, Sales and Service and Maintenance.
Rental. Our rental compression units provide small, medium and large horsepower applications for unconventional oil and natural gas production. Our rental contracts typically provide for initial terms of six to 24 months, with our larger horsepower units having contract terms of up to 60 months. By outsourcing their compression needs, we believe our customers are able to increase their revenues by producing higher volumes of oil and natural gas due to greater equipment run time. Outsourcing allows our customers to reduce their compressor downtime, operating and maintenance costs, and capital investments, and more efficiently meet their changing compression needs. We maintain and service allExecutive Officers of the compression equipment we rent to our customers.
The size, type and geographic diversity 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 gas 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, 2021, we had 2,023 natural gas compressors in our rental fleet totaling 418,041 horsepower. Of this total, we had 1,254 natural gas compressors totaling 297,808 horsepower rented to 83 customers. The utilization rate of our rental fleet as of December 31, 2021 was 62.0%, while our horsepower utilization for the same period was 71.2%. We added 65 units with approximately 18,035 horsepower to our fleet during 2021. 25 of those units were 400 horsepower or larger, representing approximately 56% of the horsepower added.
Engineered Equipment Sales. This operating unit includes the following components:
•Compressor fabrication. Fabrication involves the design, fabrication and assembly of compressor components manufactured by us or other vendors into compressor units that are ready for rental or sale. In addition to fabricating compressors for our rental fleet, we engineer and fabricate custom-made natural gas compressors for sale to customers to meet their specifications based on well pressure, production characteristics and the particular applications for which compression is sought. Fabricated compressors comprised 27.5% of our sales revenue during 2021.
•Parts sales and compressor rebuilds. To provide customer support for our compressor and flare sales businesses, we stock varying levels of replacement parts at our Midland, Texas facility and at 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. Parts sales and compressor rebuilds comprised 67.2% of our sales revenue during 2021.
•Flare fabrication. We design, fabricate, sell, install and service flare stacks and related ignition and control devices for the onshore and offshore incineration of gas compounds such as hydrogen sulfide, carbon dioxide, natural gas and liquefied petroleum gases. Applications for this equipment are often environmentally and regulatory driven.
•Compressor manufacturing. We design and manufacture our own proprietary line of reciprocating natural gas compressor frames, cylinders and parts known as our “CiP”, or Cylinder-in-Plane, product line. We use the finished components to fabricate compressor units for our rental fleet or for sale to customers. We also sell finished components to other fabricators.
Service and Maintenance. We service and maintain compressors owned by our customers on an “as needed” and contract basis. Natural gas compressors require routine maintenance and periodic refurbishing to prolong their useful life. Routine maintenance includes physical and visual inspections and other parametric checks that indicate a change in the condition of the compressors. We perform engine and compressor overhauls on a condition-based interval or a time-based schedule or at the customer's request. Based on our past experience, these maintenance procedures maximize component life and unit availability and minimize downtime.
Business Strategy
Our long-term intentions to grow our revenue and profitability are based on the following business strategies:
•Expand rental fleet. We intend to prudently increase the size of our medium and large horsepower rental fleet by fabricating compressor units in numbers that correspond to pre-contracted agreements with our customers and to market share gains we seek to achieve. We believe our future growth will be primarily driven through our placement of larger horsepower, centralized wellhead natural gas compressors for unconventional oil production, with select fabrication of medium horsepower compressors to meet customer demand beyond our inventory.
•Geographic expansion. We will continue to expand our operations in existing areas, as well as pursue focused expansion into new geographic regions as opportunities are identified. Our largest rental area is the Permian Basin (approximately 51.8% of rental revenues in 2021), where we have continued to gain market share and believe we have the most expansion opportunities going forward. The large majority of the Company's remaining rental revenue is being generated in other oil and natural gas producing regions and plays in Texas, New Mexico and Oklahoma,
including the San Juan Basin, the Texas Panhandle/western Oklahoma, the Barnett Shale, and central Oklahoma. Other regions and plays in which we provide service include the Utica and Marcellus Shales, Michigan and the DJ Basin.
•Selectively pursue acquisitions. We will continue to evaluate potential acquisitions, joint ventures and other opportunities that could enhance our current market position, but only those that provide compelling returns to the Company.
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:
•Superior customer service. Our availability 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.
•Diversified product line. Our compressors are available as low pressure rotary screw and higher pressure reciprocating packages. They are designed to meet a number of applications, including compression assisted gas lift on oil wells, wellhead compression on natural gas wells, natural gas gathering and transmission, and others. In addition, our compressors can be built to handle a variety of gas mixtures, including air, nitrogen, carbon dioxide, hydrogen sulfide and hydrocarbon gases. A diversified compression product line helps us compete by being able to satisfy widely varying pressure, volume and production conditions that customers encounter.
•Purpose-built rental compressors. Our rental compressor packages have been designed and built to address the primary requirements of our customers in the producing regions in which we operate. Our units are purpose-built but standardized, as the units are compact in design and are easy, quick and inexpensive to move, install and start-up. Our control systems are technically advanced, as these systems allow the operator to monitor as well as start and stop the majority of our units remotely and/or in accordance with well conditions.
•Experienced management team. On average, our executive and operating team members have over 25 years of oilfield services and other energy industry experience. We believe our management team has successfully demonstrated its ability to grow our business during times of expansion and to manage through downturns.
•Broad geographic presence. We presently provide our products and services to a customer base of oil and natural gas exploration and production companies operating in Texas, New Mexico, Oklahoma, Pennsylvania, West Virginia, Ohio, Michigan, Colorado and Wyoming. Our footprint allows us to service many of the largest oil and natural gas producing regions in the United States. We believe that operating in diverse geographic regions allows us better utilization of our compressors, minimal incremental expenses, operating synergies, volume-based purchasing, leveraged inventories and cross-trained personnel.
•Long-standing customer relationships. We have developed long-standing relationships providing compression equipment to many major and independent oil and natural 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.
Overview and Outlook
The market for compression equipment and services is dependent on the condition of the oil and natural gas industry, including the capital expenditure budgets of domestic oil and gas companies. The level of activity and capital expenditures has generally been dependent upon the prevailing view of future gas and 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 countries and Russia, and other factors. In addition, while some recent capital budget increases have occurred, capital expenditure budgets of energy companies have become significantly more constrained over the last several years due to the deterioration of energy equity markets and strong demands from institutional investors that companies keep capital spending within operating cash flow and return capital through dividends and share repurchases. While our rental agreements are not typically capital in nature, overall capital investment typically drives our
customers demand for incremental compression needs. Oil and natural gas prices and the level of development and production activity have historically been characterized by significant volatility.
On January 30, 2020, the World Health Organization (“WHO”) announced a global health emergency because of a new strain of coronavirus known as COVID-19 due to the risks it imposes on the international community as the virus spreads globally. In March 2020, the WHO classified the COVID-19 outbreak as a pandemic, based on the rapid increase in exposure globally. During this time, the market began to experience a decline in oil prices in response to oil demand concerns due to the global economic impacts of COVID-19. These developments led to significant weakness in oil prices and ensuing reductions of exploration and production company capital and operating budgets. In recent months, oil and natural gas prices have shown significant increases but we believe energy company capital budgets have not increased at the same levels which continues to adversely affect our compressor sales.
Finally, due to supply chain disruptions as a result of the COVID-19 pandemic, we continue to experience cost increases and sporadic availability of many of our parts needed to fabricate and maintain our rental fleet. While we have a robust supplier network, pricing pressure from our customers and competitors presents challenges in increasing our rental rates to offset these increased costs. Our relationship with our major customer continues to be strong, and they have continued to pay our invoices in a timely, consistent manner. Nevertheless, if any of these circumstances change, our business could be adversely affected. Please read Item 1A, Risk Factors, in this report.
Major Customers
Sales and rental income to Occidental Permian, LTD. ("Oxy") for the years ended December 31, 2021 and 2020 amounted to 40% and 30% of our revenue, respectively. No other single customer accounted for more than 10% of our revenues in 2021 or 2020.
Oxy amounted to 46% of our accounts receivable as of December 31, 2021 and 35% of our accounts receivable as of December 31, 2020. No other customers amounted to more than 10% of our accounts receivable as of December 31, 2021 and 2020. The loss of this key customer would have a material adverse effect on our business, financial condition, results of operations 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 flare equipment 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 the customer’s cash flow through enhanced product design, fabrication, manufacturing, installation, operations, customer service and support.
Competition
We have a number of competitors in the natural gas compression segment, some of which have greater financial resources. We believe that we compete effectively on the basis of price, customer service, including the ability to place personnel in remote locations, 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 do not increase proportionately.
Backlog
As of December 31, 2021, we had a sales backlog of approximately $1.5 million compared to $1.4 million as of December 31, 2020. 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 of lead time prior to delivery of the order.
Employees
As of December 31, 2021, we had 247 total employees, none of which are represented by a labor union. We believe we have good relations with our employees.
Liability and Other Insurance Coverage
Our equipment and services are provided to customers who are subject to hazards inherent in the oil and natural 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 manufacturers. 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.
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 natural gas industry. The adoption of laws and regulations affecting the oil and natural gas industry for economic, environmental and other policy reasons could increase our costs and could have an adverse effect on our operations. The state and federal environmental laws and regulations that currently apply to our operations could become more stringent in the future.
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 waters 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. In addition, some of these properties have been operated by third parties over whom we have no control either as to such entities' treatment of materials or the manner in which such materials may have been disposed of or released.
The federal Comprehensive Environmental Response Compensation and Liability Act of 1980, commonly known as CERCLA, and comparable state statutes impose strict liability on:
•owners and operators of sites, and
•persons who disposed of or arranged for the disposal of "hazardous substances" found at sites.
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. For
example, on January 20, 2021, the Acting Secretary for the Department of the Interior signed an order effectively suspending new fossil fuel leasing and permitting on federal lands, including in the US Gulf of Mexico, for 60 days. Then on January 27, 2021, President Biden issued an executive order indefinitely suspending new oil and natural gas leases on public lands or in offshore waters pending completion of a comprehensive review and reconsideration of federal oil and gas permitting and leasing practices. 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.
Further, as discussed below under the heading "Climate Change", President Biden has announced that he intends to take aggressive action to address climate-related issues and to set the United States on a path to be carbon-neutral by 2050.
Waste Management and Disposal
The federal Resource Conservation and Recovery Act ("RCRA") and analogous state laws and their implementing regulations govern the generation, transportation, treatment, storage and disposal of hazardous and non-hazardous solid wastes. During the course of our operations, we generate wastes (including, but not limited to, used oil, antifreeze, filters, paints and solvents) in quantities regulated under RCRA. The EPA and various state agencies have limited the approved methods of disposal for these types of wastes. CERCLA and analogous state laws and their implementing regulations impose strict, and under certain conditions, joint and several liability without regard to fault or the legality of the original conduct on classes of persons who are considered to be responsible for the release of a hazardous substance into the environment. These persons include current and past owners and operators of the facility or disposal site where the release occurred and any company that transported, disposed of, or arranged for the transport or disposal of the hazardous substances released at the site. Under CERCLA, such persons may be subject to joint and several liability for the costs of cleaning up the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health studies. In addition, where contamination may be present, it is not uncommon for neighboring landowners and other third parties to file claims for personal injury, property damage and recovery of response costs allegedly caused by hazardous substances or other pollutants released into the environment.
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. 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.
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 results of operations and financial position.
Air Emissions
Our operations are also subject to federal, state, and local regulations. The Clean Air Act 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 require us to meet more stringent air emission standards and install new emission control equipment on all of our engines built after July 1, 2008.
For instance, in 2010, the U.S. Environmental Protection Agency (“EPA”) published new regulations under the CAA to control emissions of hazardous air pollutants from existing stationary reciprocal internal combustion engines. In 2012, the EPA proposed amendments to the final rule in response to several petitions for reconsideration, which were finalized and became effective in 2013. The rule requires us to undertake certain expenditures and activities, including purchasing and installing emissions control equipment on certain compressor engines and/or purchasing certified engines from complaint manufacturers.
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 natural gas production and natural gas processing operations. Specifically, the EPA’s rule package included New Source Performance Standards 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 natural 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 New Source Performance Standards that require certain new, modified or reconstructed facilities in the oil and natural 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 November 2021, the EPA proposed a rule to further reduce methan 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 cost 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.
Climate Change
In response to findings that emissions of carbon dioxide, methane and other Greenhouse Gases (“GHG”) endanger public health and the environment, federal legislation has been donsidere to reduce GHG emissions.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. 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. Further, although Congress has not passed such legislation, almost half of the states have begun to address GHG emissions, primarily through the planned development of emissions inventories or regional GHG cap and trade programs. Depending on the particular program, we could be required to control GHG emissions or to purchase and surrender allowances for GHG emissions resulting from our operations.The EPA has adopted regulations under existing provisions of the CAA that, among other things, establish construction and operating permit reviews for GHG emissions of certain large GHG emissions sources, including petroleum and natural gas facilities, such as natural gas transmission compression facilities that emit 25,000 metric tons or more of carbon dioxide equivalent per year.In addition, the Department of Transportation (the “DOT”) has implemented GHG emissions limits on vehicles manufactured for operation in the United States.
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. Also in November 2021, President Biden signed a $1 trillion dollar infrastructure bill into law. The new infrastructure law includes several climate-focused investments, including upgrades to power grids to accommodate increased use of renewable energy and expansion of electric vehicle infrastructure. Although it is not possible at this time to predict what additional domestic legislation may be adopted in light of the Paris Agreement or the Glasgow Climate Pact, or how legislation or new regulations that may be adopted based on the Paris Agreement or the Glasgow Climate Pact to address GHG emissions would impact our business, any such 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 of GHGs associated with our operations and could decrease demand for oil and natural gas.
Additionally, various states and groups of states have adopted or are considering adopting legislation, regulations or other regulatory initiatives that are focused on such areas as 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.
Litigation risks are also increasing, as a number of cities and other local governments have sought to bring suit against the largest oil and natural gas exploration and production 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 the Company) 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 compressor rental and sale 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 natural gas sector or otherwise restrict the areas in which this sector may produce oil and natural gas or generate GHG emissions could result in increased costs of complianceor additional operating restrictions or reduced demand for our compressor products and services, and could have a material adverse effect on our business, financial condition and results of operations.
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 affect on our financial condition or operational results. However, it is possible that future developments, such as new or increasingly strict requirements and environmental laws and enforcement policies there under, 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, 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. We cannot determine to what extent our future operations and earnings may be affected by new legislation, new regulations or changes in existing regulations.
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.
Patents, Trademarks and Other 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, development and manufacturing activities, we may seek patents when appropriate on inventions concerning new products and product improvements. Although we continue to use technology that was previously covered by a patent and consider it useful in certain applications, we do not consider the expired patent to be material to our business as a whole.
Suppliers and Raw Materials
Fabrication of our rental compressors involves the purchase by us of engines, compressors, coolers and other components, and the assembly of these components on skids for delivery to customer locations. These major components of our compressors are acquired through periodic purchase orders placed with third-party suppliers on an "as needed" basis, which typically requires a three to six month lead time with delivery dates scheduled to coincide with our estimated production schedules. Although we do not have formal continuing supply contracts with any major supplier, 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 the results of our operations and financial condition, particularly if we are unable to increase our rental rates and sale prices proportionate to any such component price increases.
In addition, the COVID-19 outbreak poses the risk that our suppliers may be prevented from conducting their business at sufficient levels to provide us with necessary equipment and supplies in a timely and sufficient amount. We have experienced no significant supply disruptions but have incurred longer than normal delivery estimates. To the extent we have difficulties in obtaining needed products and supplies in a timely manner, our results of operations and financial position may be adversely affected.
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 Report 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 SEC under the Securities Exchange Act of 1934, as amended, 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
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, financial condition or results of operations.
Risks Associated With Our Industry
Decreased oil and natural gas prices and oil and gas industry expenditure levels adversely affect our revenue.
Our revenue is derived primarily from expenditures in the oil and natural gas industry, which, in turn, are based on budgets to explore for, develop and produce oil and natural 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 natural gas depends largely upon the prevailing view of future oil and natural gas prices. Prices for oil and natural gas historically have been, and are likely to continue to be, highly volatile. Many factors affect the supply and demand for oil and natural gas and, therefore, influence oil and natural gas prices, including:
•the level of oil and natural gas production;
•the level of oil and natural gas inventories;
•domestic and worldwide demand for oil and natural gas;
•the expected cost of developing new reserves;
•the cost of producing oil and natural gas;
•the level of drilling and completions activity;
•inclement weather;
•domestic and worldwide economic activity;
•regulatory and other federal and state requirements in the United States;
•the ability of the Organization of Petroleum Exporting Countries, national oil companies and other large producers to set and maintain production levels and prices for oil;
•political conditions in or affecting oil and natural gas producing countries;
•terrorist activities in the United States and elsewhere;
•the cost of developing alternative energy sources;
•environmental regulation; and
•tax policies.
Our rental contracts are generally short-term, and oil and natural gas companies tend to respond quickly to upward or downward changes in prices. Any prolonged reduction in drilling and production activities historically has reduced our compressor sales and materially eroded both rental pricing and utilization rates for our equipment and services and adversely affects our financial results. As a result of any such prolonged reductions, we may suffer losses, be unable to make necessary capital expenditures and 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 natural 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 or their product and service diversity. 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 natural 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. Additionally, we may face competition in our efforts to acquire other businesses.
The outbreak of COVID-19 and recent oil market developments could adversely impact our financial condition and results of operations.
On January 30, 2020, the World Health Organization (“WHO”) announced a global health emergency because of a new strain of coronavirus known as COVID-19 due to the risks it imposes on the international community as the virus spreads globally. In March 2020, the WHO classified the COVID-19 outbreak as a pandemic, based on the rapid increase in exposure globally. During this time, the market began to experience a decline in oil prices in response to oil demand concerns due to the global economic impacts of COVID-19. These developments led to significant weakness in oil prices and ensuing reductions of E&P company capital and operating budgets. While economic and industry conditions have improved, further or increased outbreaks of COVID-19 could impact our financial condition and results of operations in 2022 and perhaps beyond, as further discussed in risk factors below.
In addition, the continued spread of the virus into our workforce could prevent us meeting the demands of our customers and adequately servicing existing compressors. Similarly, if our customers or suppliers experience adverse business consequences due to COVID-19, demand for our equipment and services could also be adversely affected. The magnitude and duration of potential social, economic and labor instability as a direct result of COVID-19 cannot be estimated at this time. Should any of these potential impacts continue for an extended period of time, the impact on our business could have an adverse effect on our financial position and results of operations.
Adverse macroeconomic and business conditions may significantly and negatively affect our results of operations.
As a result of the COVID-19 outbreak discussed above and other economic conditions in the United States and abroad, our revenue and profitability has been and will likely continue to be adversely affected. 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 purchases of our products and services and could result in a decrease in, or cancellation of, orders included in our backlog 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 natural gas would likely result in delays or cancellation of projects by our customers, reducing the demand for our products and services.
Additionally, if we are not able to pass along increases to our costs due to inflation on parts, fluids, labor and other aspects of our business, it may adversely affect our results of operations 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 natural gas prices and the level of drilling and exploration activity can be volatile. As a result, the demand for our natural gas compression services will be adversely affected. A reduction in demand has, and could continue to, force us to reduce our pricing substantially. Additionally, our customers’ production from oil-weighted reserves constitutes the majority percentage of our business. These unconventional sources are generally less economically feasible to be developed in low oil price environments. A decline in demand for oil and natural gas generally has an adverse effect on our business, financial condition and results of operations.
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. We have been required to enter into lower rate rental contracts in response to market conditions and our rentals and sales revenue 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 Safe Drinking Water Act (“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 of demand for our compressors, potentially affecting both sales and rentals 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 wastes 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 greenhouse gas (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 U.S. Environmental Protection Agency (EPA) has taken steps to regulate GHG emissions as air pollutants under the U.S. Clean Air Act of 1970, as amended. 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 natural 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 natural 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 business. Other developments focused on restricting GHG emissions include the Regional Greenhouse Gas Initiative, the Western Climate Action initiative, and various state programs implementing the California Global Warming Solutions Act of 2006 (known as Assembly Bill 32).
Requirements and voluntary initiatives to reduce greenhouse gas emissions, as well as increased climate change awareness, may result in increased costs for the oil and gas industry to curb greenhouse gas emissions and could have an adverse impact on demand for oil and natural gas.
International, national, and state governments, agencies and bodies continue to evaluate and promulgate regulations and voluntary initiatives that are focused on restricting GHG emissions. These requirements and initiatives are likely to become more stringent over time and to result in increased costs for the oil and gas industry to curb GHG emissions. In addition, these developments, and public perception relating to climate change, may curtail production and demand for hydrocarbons such as oil and natural gas by shifting demand towards and investment in relatively lower carbon energy sources such as wind, solar and alternative energy solutions. If renewable energy becomes more competitive than fossil-fuel energy globally, it could have a material effect on our results of operations.
The potential for climate related changes may pose future risks to our operations and those of our customers.
These changes can include extreme variability in weather patterns such as increased frequency and severity of significant weather events (e.g. flooding, hurricanes and tropical storms), natural hazards (e.g., increased wildfire risk), rising mean temperature and sea levels, and long-term changes in precipitation patterns (e.g. drought, desertification, or poor water quality). Such changes have the potential to affect business continuity and operating results, particularly at facilities in coastal areas or areas prone to chronic water scarcity.
Risks Associated With Our Company
A significant majority of our compressor rentals are for terms of six months or less 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 most 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 fabricating the equipment. Of the 1,254 compressors rented at December 31, 2021, 827 were rented on a month-to-month basis. Given the volatility of the oil and gas market, we cannot be sure that a substantial number of our customers will continue to renew their rental agreements or that we will be able to re-rent the equipment to new customers or that any renewals or re-rentals will be at comparable rental rates. The inability to timely renew or re-rent a substantial portion of our compressor rental fleet has and will have a material adverse effect upon our business, financial condition, results of operations and cash flows.
We could be subject to substantial liability claims that could harm our financial condition.
Our products 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 under our insurance coverage:
•we may not be able to continue to obtain insurance on commercially reasonable terms;
•we may be faced with types of liabilities that will not be covered by our insurance, such as damages from 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 40% of our revenue for the year ended December 31, 2021, and the same customer accounted for an aggregate of approximately 30% of our revenue for the year ended December 31, 2020. At December 31, 2021, this same customer accounted for an aggregate of 46% 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 flow and current assets.
Loss of key members of our management could adversely affect our business.
In keeping with our streamlined approach to our business, our executive management team consists of three officers: our (i) Chief Executive Officer, (ii) Chief Financial Officer and (iii) Vice President of Technical Services. We depend on the continued employment and performance of these three key members of our executive management team. In particular, we are significantly reliant upon the leadership and guidance of Stephen C. Taylor, who has been our President, Chief Executive Officer and Board member since 2004. In addition to his management duties, Mr. Taylor has been instrumental in our communications and standing with the investment community. If any of our key executives resign or become unable to continue in their present role and is not adequately replaced, our business operations could be materially adversely affected. We do not carry any key-man 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 flow from operations, the incurrence of debt or the issuance of equity. During times when the oil or natural gas markets are weak, our customers are more likely to experience a downturn in their financial condition. Many of our customers’ equity values and liquidity substantially declined during the most recent fall in oil and natural 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, 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 in 2022. 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 sell or 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.
During 2022, the amount we will spend on capital expenditures related to rental compression equipment will be determined primarily by the activity of our customers. 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 natural gas exploration and production industry and the presence of alternative uses for our capital, including any acquisitions that we may pursue.
During the past year, we funded our capital expenditures through cash flows from operations. Although we believe that cash on hand and cash flows from our operations and/or potential bank borrowing from line of credit will provide us with sufficient cash to fund our planned capital expenditures for 2022, we cannot assure you that these sources will be sufficient. 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, it 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 flow, together with the absence of alternative sources of capital, could have a material adverse effect on our business, financial condition, results of operations or cash flow.
Our debt levels may negatively impact our current and future financial stability.
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 flow from operations may be dedicated to the payment of principal and interest 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 our credit line and are unable to service our debt, we will likely be forced to take remedial steps that are contrary to our business plan.
We believe that our current cash position and anticipated cash flow from operations and the amount available under our line of credit will be sufficient to meet our capital needs through 2022. However, if we were to materially borrow under our line of credit or other borrowing arrangements, it is possible that our business will not generate sufficient cash flow from
operations 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; or
•refinance all or a portion of our indebtedness on terms that may be less favorable to us.
Our current credit 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 agreement, we must:
•comply with various leverage, commitment coverage and other customary ratios;
•not exceed specified levels of debt
•comply with limits on asset sales;
•comply with limits on cash dividends;
•and other customary limitations.
Our ability to meet the financial ratios and tests under our credit agreement 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 arrangement. If we are unable to repay any outstanding amounts, the lending organization could proceed against and foreclose on the assets we pledged as collateral to secure payment of our indebtedness.
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. 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 and 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.
Our strategy envisions the 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. Growth may place a strain on our management systems and resources. We must continue to refine and expand our business capabilities, our systems and processes, and our access to financing sources. If we expand, 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 manufacturing infrastructure so that it is appropriate for our level of activity;
•expand our systems effectively or efficiently or 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 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 manufacture. 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 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 and other third-party 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 coverages.
Our income taxes may change.
We are subject to income tax on a jurisdictional or legal entity basis and significant judgment is required in certain instances to allocate our taxable income to a jurisdiction and to determine the related income tax expense and benefits. Losses in one jurisdiction generally may not be used to offset profits in other jurisdictions. As a result, changes in the mix of our earnings (or losses) between jurisdictions, among other factors, could alter our overall effective income tax rate, possibly resulting in significant tax rate increases.
We are regularly audited by various tax authorities. Income tax audit assessments or changes in tax laws, regulations, or other interpretations may result in increased tax provisions which could materially affect our operating results in the period or periods in which such determinations are made or changes occur.
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. If we fail to maintain effective internal controls, we may not be able to ensure that we can conclude on an ongoing basis that we have effective internal controls over financial reporting in accordance with Section 404 of the Sarbanes-Oxley Act. Moreover, 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 are exposed to risks related to computer systems failures or cyber security threats
In the conduct of our business we are dependent upon our computing systems and those of third parties to collect, store, transmit and process data used in our operational activities and to record, process and track financial transactions. If interruptions were to occur we would be unable to access these systems for a period of time and there is a risk of data loss. Data backup and storage measures are in place that would allow recovery in a time frame that we believe would not materially impact our ability to conduct business.
We are also subject to cyber security attacks and have taken steps to minimize the probability of an attack penetrating our systems. These include network security, virus protection, filtering software and intrusion protection measures.
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 natural 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 Securities and Exchange Commission in February 2022, an aggregate of approximately 27.9% of the outstanding shares of our common stock are owned by four institutional investors, each of which owns more than 5% of our outstanding shares as of the date of their respective filings in February 2022. 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 6.5% of the outstanding shares of our common stock as of March 14, 2022, 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 prices 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 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, our common stock and other 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 of our company, 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 of us.
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
None.
ITEM 2. PROPERTIES
The table below describes the material facilities owned or leased by Natural Gas Services Group as of December 31, 2021:
| | | | | | | | | | | | | | | | | | | | |
Location
Name | | Status
Officer Since | | Square Feet
Age | | Uses
Position |
Tulsa, OklahomaStephen C. Taylor | | Owned and LeasedJanuary 2005 | | 91,780 68 | | | Compressor fabrication, rentalChairman of the Board, President and servicesChief Executive Officer |
Midland, TexasMicah C. Foster | | OwnedMay 2021 | | 70,000 42 | | | Compressor fabrication, rentalVice President and servicesChief Financial Officer |
Lewiston, MichiganJames R. Hazlett | | OwnedJune 2007 | | 15,360 67 | | | Compressor fabrication, rental and services |
Midland, Texas | | Owned | | 45,000 | | | Corporate office |
Bloomfield, New Mexico | | Owned | | 7,000 | | | Office and parts and services |
Godley, Texas | | Leased | | 5,000 | | | Parts and services |
Galeton, Colorado | | Leased | | 4,800 | | | Parts and services |
Bridgeport, Texas | | Leased | | 4,500 | | | Office and parts and services |
Midland, Texas | | Owned | | 4,100 | | | Parts and services |
Vernal, Utah | | Leased | | 3,200 | | | Parts and services |
Carrollton, Ohio | | Leased | | 2,600 | | | Parts and services |
Wheeler, Texas | | Leased | | 2,160 | | | Parts and servicesVice Present-Technical Services |
We believeStephen C. Taylor. Stephen C. Taylor, 68, has been President and Chief Executive Officer of Natural Gas Services Group since January 2005. He was elected as a Director of Natural Gas Services Group at the annual meeting of shareholders in June 2005. Effective January 1, 2006, Mr. Taylor was appointed Chairman of the Board of Directors. Immediately prior to joining Natural Gas Services Group, Mr. Taylor held the position of General Manager − US Operations for Trican Production Services, Inc. from 2002 through 2004. Mr. Taylor joined Halliburton Resource Management in 1976, becoming its Vice President − Operations in 1989. Beginning in 1993, he held multiple senior level management positions with Halliburton Energy Services until 2000 when he was elected Senior Vice President/Chief Operating Officer of Enventure Global Technology, LLC, a joint-venture deep water drilling technology company owned by Halliburton Company and Shell Oil Company. Mr. Taylor elected early retirement from Halliburton Company in 2002 to join Trican Production Services, Inc. Mr. Taylor holds a Bachelor of Science degree in Mechanical Engineering from Texas Tech University and a Master of Business Administration degree from the University of Texas at Austin.
James R. Hazlett, 67, has served as Vice President-Technical Services since June 2005. He also served as Vice President of Sales of Screw Compression Systems, Inc. from 1997 until June 2007 when Screw Compression Systems, Inc. was merged into Natural Gas Services Group. After the merger in June 2007, Mr. Hazlett continues to remain employed by Natural Gas Services Group as Vice President-Technical Services. From 1982 to 1996, Mr. Hazlett served in management roles for Ingersoll Rand/Dresser Rand, working with compression of all types in several different departments from sales and service to engineering. From 1978 to 1982, Mr. Hazlett was employed by the down-hole tool division of Hughes Tool, designing and installing gas lift and plunger systems. Mr. Hazlett holds a Bachelor of Science degree from the College of Engineering at Texas A&M University and has over 40 years of industry experience.
Micah C. Foster, 42, has served as our Vice President, Chief Financial Officer, and Corporate Secretary since his appointment on May 11, 2021. Mr. Foster has over 17 years of professional experience in the energy industry and public accounting. Prior to joining the Company, Mr. Foster served as the Chief Accounting Officer of Legacy Reserves Inc. and its predecessor Legacy Reserves LP, a publicly traded oil and natural gas production company from April 2012 to April 2020. Legacy Reserves Inc. filed for protection under Chapter 11 of the federal bankruptcy code in July, 2019 and emerged from bankruptcy in December, 2019. Prior to his appointment as Chief Accounting Officer in 2012, Mr. Foster served in various roles for Legacy ranging from Financial Accountant to Corporate Controller. Prior to joining Legacy, Mr. Foster worked as a staff auditor and senior auditor for Ernst&Young, LLP from July 2003 to January 2006. Mr. Foster holds a BBA in Accounting and Finance from Abilene Christian University and is a Certified Public Accountant.
Board of Directors of the Company
The following table sets forth, as of December 31, 2021, certain information regarding the members of our Board of Directors.
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Name | | Director Since | | Age | | Position | | Expiration of Term |
| John W. Chisholm | | December 2006 | | 67 | | Lead Director | | 2022 |
| Leslie A. Beyer | | June 2020 | | 46 | | Director | | 2023 |
| Stephen C. Taylor | | January 2005 | | 68 | | Director | | 2023 |
| David L. Bradshaw | | December 2011 | | 67 | | Director | | 2024 |
| Nigel J. Jenvey | | April 2021 | | 49 | | Director | | 2024 |
John W. Chisholm. John W. Chisholm, 67, was appointed as a Director of Natural Gas Services Group in December 2006. Mr. Chisholm was appointed as Lead Director in June 2020. Mr. Chisholm is the founder of Wellogix, an oil and gas software company that develops software aimed at expediting the exchange of enterprise data and communication of complex engineered services. Prior to founding Wellogix, Mr. Chisholm co-founded and served as President of ProTechnics Company from 1985 until its sale to Core Laboratories in December of 1996. Mr. Chisholm served as Senior Vice President of Global Sales and Marketing of Core Laboratories until 1998, when he started Chisholm Energy Partners, an investment fund focused on mid-size energy service companies. From 2002 to 2009, Mr. Chisholm served on the Board of Directors of Flotek Industries, Inc. ("Flotek"), and became its interim President in August 2009. Mr. Chisholm became President of Flotek in August 2010, was appointed as its Chief Executive Officer in March 2012, and served in those roles until January 2020. Flotek is a public company which files reports under the Securities Exchange Act of 1934. Mr. Chisholm is presently CEO of The John Chisholm Group. Mr. Chisholm holds a Business Administration degree from Fort Lewis College in Colorado.
Mr. Chisholm brings significant natural resources experience to our propertiesBoard, in connection with his background in supplying drilling and production related products and services to the oil, gas and mining industries, and his investment fund experience with mid-size energy service companies is an invaluable resource as the Company assesses its capital and liquidity needs. In addition Mr. Chisholm's experience as a board member and executive officer of a public company provides us with a wealth of leadership and management skills.
Leslie A. Beyer. Leslie A. Beyer, 46, joined our Board in June 2020. Ms. Beyer is the Chief Executive Officer of the Energy Workforce and Technology Council (“EWTC”) formed through the merger of the Petroleum Equipment & Services Association (“PESA”) and the Association of Energy Service Companies, a position she has held since the merger in February, 2021. EWTC represents more than 600 member companies in energy services, supply, manufacturing and drilling with a focus on enabling its members to safely, profitably and sustainably produce the energy needed to meet rising demand around the world. Prior to leading EWTC, Ms. Beyer was the Chief Executive Officer of PESA. Prior to joining PESA, Ms. Beyer served as Director, Member and Board Relations for the National Association of Manufacturers from 2012 to 2014. Previously, Ms. Beyer served in leadership roles at Burson-Marsteller Public Affairs and at a boutique public relations firm for more than six years. Prior to her time in public affairs, Ms. Beyer served in media relations capacities in The White House, Executive Office of the President and on the Bush 2000 Presidential Campaign. She began her career in legislative policy roles in the U.S. Senate, U.S. Department of State and U.S. Department of Housing. Ms. Beyer holds a Bachelor of Arts in Latin American Studies and Spanish from the University of Texas at Austin.
As a strong advocate for the oilfield services and equipment sector, Ms. Beyer provides the Board with a wealth of knowledge and insight about the strategic and tactical matters impacting our business and industry. In addition, Ms. Beyer's public affairs, policy and leadership experience significantly adds to our Board's capabilities.
Stephen C. Taylor. Mr. Taylor’s biography is set forth above. Mr. Taylor’s senior management experience in the natural resources industry provides the Board and our company with significant insight into our business. Mr. Taylor’s engineering and advanced business training uniquely qualifies him to provide leadership, technical expertise and financial acumen to our Board and to the operations of our Company in connection with his position as our chief executive officer.
David L. Bradshaw. David L. Bradshaw, 67, joined our board in December of 2011. Since 2005, Mr. Bradshaw has acted as a consultant in the oil and gas exploration and production sector and has overseen his investments in this area. From August 2007 through November 2009, Mr. Bradshaw served as a Director and Audit Committee Chairman for Triangle Petroleum, a publicly traded company listed on the American Stock Exchange. From November 2007 through November 2008, Mr. Bradshaw served as a Director for Comet Ridge Limited, an Australian company listed on the Australian Securities Exchange. From 1986 to 2005, Mr. Bradshaw worked for Tipperary Corporation, a U.S. public company listed on the American Stock Exchange. During his tenure at Tipperary, the company was involved in oil and gas exploration and production, and natural gas processing and transportation. He held the positions of Chief Executive Officer from 1996 to 2005, Chairman of the Board from 1997 to 2005, Chief Financial Officer from 1990 to 1996 and Chief Operating Officer from 1993 to 1996. From 1999 to 2005, Mr. Bradshaw also served as Chief Executive Officer and Chairman of Tipperary Oil & Gas (Australia) Pty Ltd, a subsidiary of Tipperary, which explored for and produced natural gas in Queensland, Australia. From 1983 to 1986, Mr.
Bradshaw was an owner and officer of Bradcorp, Inc., a private exploration and production company. Prior to this, Mr. Bradshaw spent six years in public accounting serving predominantly oil and gas clients. Mr. Bradshaw graduated from Texas A&M University with a BBA in Accounting in 1976 and a MBA in 1977, and is also a Certified Public Accountant.
Mr. Bradshaw's educational and professional training and achievements as a Certified Public Accountant and MBA, along with his past experience as both a Chief Financial Officer and Chief Executive Officer of a public company involved in the natural resources industry, provides us with considerable accounting and corporate finance skills. In addition, Mr. Bradshaw's career has spanned over forty years in the oil and gas industry and as a public accountant. His executive management positions in both private and public companies bring us significant leadership, planning and management skills and background.
Nigel J. Jenvey. Nigel. J. Jenvey, 49, was appointed as a Director of Natural Gas Services Group in April 2021. Mr. Jenvey is currently the Global Head of Carbon Management at consultancy Gaffney, Cline & Associates. Prior to joining Gaffney Cline, Mr. Jenvey spent eight years at BP as the company’s head of Carbon, Capture, Use and Storage (CCUS) and carbon solutions manager. He also led similar efforts at Maersk Oil as Technical Director of carbon & climate, and served in various managerial and project leadership roles at Royal Dutch Shell, including Shell’s global Enhanced Oil Recovery (EOR) Center of Expertise and European operating business. He began his career as a petroleum engineer at Texaco in 1995 supervising offshore oil and gas production operations in the North Sea. Mr. Jenvey is an industry leader in Carbon Management and expert in CCUS having been involved in leading projects across the world since 2004. These have included providing peer advice to the National Petroleum Council, the Society of Petroleum Engineers and various major energy companies in the US and Canada. Mr. Jenvey is the Editor of the annual Decarbonization feature in the SPE Journal of Petroleum Technology and a peer reviewer to the International Energy Agency. Mr. Jenvey has also provided testimony to Congress on CO2 Capture technologies. Mr. Jenvey holds a Bachelor degree (Hons.) in Mining Engineering from the University of Leeds and both a Diploma and a Master of Science degree in Petroleum Engineering from Imperial College in London.
Mr. Jenvey brings significant carbon management, sustainability and ESG experience to our Board. His experience of working with companies, investors, governments, academia, and non-governmental organizations provides us a wealth of knowledge and insight regarding the challenges and solutions that exist for the oil and gas industry, and adds to our Board’s capabilities to successfully guide the Company through these matters that are impacting our business and industry.
Code of Ethics
Our Board of Directors has adopted a Code of Business Conduct and Ethics (“Code”), whichis posted on our website at www.ngsgi.com. You may also obtain a copy of our Code by requesting a copy in writing at 404 Veterans Airpark Lane, Suite 300, Midland, Texas 79705 or by calling us at (432) 262-2700.
Our Code provides general statements of our expectations regarding ethical standards that we expect our Directors, officers and employees, including our Chief Executive Officer and Chief Financial Officer, to adhere to while acting on our behalf. Among other things, the Code provides that:
•we will comply with all laws, rules and regulations;
•our Directors, officers and employees are to avoid conflicts of interest and are prohibited from competing with us or personally exploiting our corporate opportunities;
•our Directors, officers and employees are to protect our assets and maintain our confidentiality;
•we are committed to promoting values of integrity and fair dealing; and that
•we are committed to accurately maintaining our accounting records under generally well maintainedaccepted accounting principles and in good condition and adequatetimely filing our periodic reports.
Our Code also contains procedures for our purposes.employees to report, anonymously or otherwise, violations of the Code.
ITEM 3. LEGAL PROCEEDINGSAudit Committee
From timeThe primary functions of our Audit Committee include:
•assisting the Board in fulfilling its oversight responsibilities as they relate to time,our accounting policies, internal controls, financial reporting practices and legal and regulatory compliance;
•discussing with management policies with respect to risk assessment and risk management;
•hiring our independent registered public accounting firm;
•monitoring the independence and performance of our independent registered public accounting firm;
•maintaining, through regularly scheduled meetings, a line of communication between the Board, our financial management and independent registered public accounting firm; and
•overseeing compliance with our policies for conducting business, including ethical business standards.
The members of the Audit Committee are David L. Bradshaw (Chairman), Leslie A. Beyer, and Nigel J. Jenvey. Our common stock is listed for trading on the New York Stock Exchange, or “NYSE”. Under rules of the NYSE, the Audit
Committee is to be comprised of three or more Directors, each of whom must be independent. Our Board has determined that all of the members of the Audit Committee are independent, as defined under the applicable NYSE rules and listing standards. In addition, our Board has determined that David L. Bradshaw is qualified as an “audit committee financial expert” as that term is defined in the rules of the United States Securities and Exchange Commission. The Audit Committee met nine times during 2021. The audit committee has also received from, and discussed with, Moss Adams the matters required to be discussed by Public Accounting Oversight Board Auditing Standard No. 1301 (AS 1301) (Communications with Audit Committees).
Any shareholder may obtain free of charge a printed copy of our Audit Committee Charter by sending a written request to Investor Relations, Natural Gas Services Group, Inc., 404 Veterans Airpark Lane, Suite 300, Midland, Texas 79705 or by visiting the “Governance” tab on the investor relations page of our website atwww.ngsgi.com.
Compensation Committee
The primary functions of our Compensation Committee include:
•assisting the Board in overseeing the management of our human resources;
•evaluating our Chief Executive Officer’s performance and compensation;
•formulating and administering our overall compensation principles and plans; and
•evaluating management.
The Compensation Committee’s policy is to offer the executive officers competitive compensation packages that will permit us to attract and retain individuals with superior abilities and to motivate and reward such individuals in an appropriate fashion in the long-term interests of Natural Gas Services Group and its shareholders. Currently, executive compensation is comprised of salary and cash bonuses and awards of long-term incentive opportunities in the form of restricted stock or restricted stock unit awards under the 2019 Equity Incentive Plan, as well as other long-term incentives payable in cash.
The members of the Compensation Committee are Leslie A. Beyer. (Chairperson since April 2021), John W. Chisholm, and David L. Bradshaw. Our Board has determined that all of the members of the Compensation Committee are independent, as defined under the applicable NYSE rules and listing standards. During 2021 there were six meetings of the Compensation Committee.
Compensation Committee Interlocks and Insider Participation
The Compensation Committee members are not officers or employees of our company, and there is not, nor was there during fiscal 2021, any compensation committee interlock (in other words, no executive of our company serves as a Director or on the compensation committee of a company that has one or more executives serving on our Board or our Compensation Committee).
Any shareholder may obtain free of charge a printed copy of our Compensation Committee Charter by sending a written request to Investor Relations, Natural Gas Services Group, Inc., 404 Veterans Airpark Lane, Suite 300, Midland, Texas 79705 or by visiting the “Governance” tab on the investor relations page of our website atwww.ngsgi.com .
Environmental, Social and Governance and Personnel Development Committee
The primary functions of our Environmental, Social and Governance ("ESG") and Personnel Development Committee include:
•overseeing the governance of the Board and its committees;
•interpreting the Governance Guidelines, the Code of Business Conduct and Ethics and other similar governance documents adopted by the Board;
•overseeing the evaluation of the Board and its committees; and
•developing, with input from executive leadership, the principles guiding our Environmental, Social and Governance efforts and monitoring our progress in meeting such principles
The members of the ESG and Governance and Personnel Development Committee are Nigel J. Jenvey (Chairman), David L. Bradshaw, and John W. Chisholm. Our Board has determined that each of the ESG and Personnel Development Committee members are independent, as defined under the applicable NYSE rules and listing standards. During 2021 there were four meetings of the ESG and Personnel Development Committee.
Any shareholder may obtain free of charge a printed copy of our Environmental, Social and Governance and Personnel Development Committee Charter by sending a written request to Investor Relations, Natural Gas Services Group, Inc., 404 Veterans Airpark Lane, Suite 300, Midland, Texas 79705 or by visiting the “Governance” tab on the investor relations page of our website atwww.ngsgi.com.
Nominating Committee
The primary functions of our Nominating Committee include:
•identifying individuals qualified to become board members, consistent with the criteria approved by the Board;
•recommending Director nominees and individuals to fill vacant positions; and
•overseeing executive development and succession and diversity efforts.
The members of the Nominating Committee are John C. Chisholm (Chairman), Leslie A. Beyer, and Nigel J. Jenvey. Our Board of Directors has determined that each of the Nominating Committee members is independent as defined under the applicable NYSE rules and listing standards. During 2021 there were four meetings of the Nominating Committee.
Any shareholder may obtain free of charge a printed copy of our Nominating Committee Charter by sending a written request to Investor Relations, Natural Gas Services Group, Inc., 404 Veterans Airpark Lane, Suite 300, Midland, Texas 79705 or by visiting the “Governance” tab on the investor relations page of our website at www.ngsgi.com. The Committee’s goal is to nominate candidates who possess a range of experiences and backgrounds which will contribute to the board’s overall effectiveness in meeting its duties and forwarding the goals of our company.
The Board is responsible for identifying individuals qualified to become Directors, and nominees are selected by the Board. The Board takes into account many factors, including being highly qualified in terms of business experience, finance and other disciplines relevant to the success of a publicly traded company in today’s business environment; understanding of the Company’s business on a technical level and the industry in which it competes; and educational and professional background. The Board evaluates each individual in the context of the Board as a whole, with the objective of recommending a group that can best support the success of the business and, based on its diversity of experience and backgrounds, represent stockholder interests through the exercise of sound judgment.
The Nominating Committee will consider a Director candidate recommended by a shareholder. A candidate must be highly qualified based on the factors noted above and be both willing and expressly interested in serving on the Board. A shareholder wishing to recommend a candidate for the Committee’s consideration must follow Securities and Exchange Commission Rule 14a-8 or our advance notice provisions contained in our Bylaws.
Director Independence
The Board has determined that each of the following four members of the Board is “independent” within the meaning of applicable listing standards of the NYSE and under the standards, set forth in Exhibit A to our Environmental Social and Governance and Personnel Development Charter which are consistent with the NYSE listing standards: Leslie A. Beyer, Nigel J. Jenvey, David L. Bradshaw, and John Chisholm. The Board has made an affirmative determination that each of Directors named above satisfies these categorical standards. In making its determination, the Board examined relationships between Directors or their affiliates with us and our affiliates and determined that each such relationship, if any, did not impair the Director’s independence. A copy of Exhibit A to our Governance Charter is available at our website,www.ngsgi.com, under the heading “Investor Relations-Governance.”
Board of Directors Diversity
The Company values diversity and the benefits that a diverse workforce can bring to the Company and to the Board of Directors. Diversity can promote the inclusion of different perspectives and ideas which can lead to more robust discussion regarding strategic and governance policy alternatives and, ultimately, result in better corporate governance and decision making.
The Company seeks to maintain a Board comprised of talented and dedicated Directors with a diverse mix of expertise, experience, skills and backgrounds. The skills and backgrounds collectively represented on the Board should reflect the diverse nature of the business environment in which the Company operates. As new members of the Board are considered, diversity considerations should include - but not be limited to - business expertise, geography, age, gender and ethnicity.
The Company is committed to a merit-based system for Board composition within a diverse and inclusive culture which solicits multiple perspectives and views and is free of conscious or unconscious bias. When assessing Board composition or identifying suitable candidates for appointment to the Board, the Company will consider candidates on merit with due consideration to the benefits of diversity and the needs of the Board. The Board and its Nominating Committee are especially cognizant of the benefits of gender and ethnic diversity and will continue to focus on important diversity metrics in future searches.
Item 11. Executive Compensation
The table below sets forth the compensation earned by our CEO, Stephen C. Taylor, and our other named executive officers for services rendered to us for the fiscal years ended December 31, 2021, 2020 and 2019.
Summary Compensation Table
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Name and Principal Position | Year | Salary(4) | Bonus (5) | Stock Awards(6) | Option Awards(7) | Non-Equity Incentive Plan Compensation(8) | Change in Pension Value and Nonqualified Deferred Compensation Earnings(9) | All Other Compensation(10) | Total |
| (a) | (b) | (c) | (d) | (e) | (f) | (g) | (h) | (i) | (j) |
| Stephen C. Taylor, Chairman, President & CEO | 2021 | $ | 612,000 | | $ | — | | $ | 722,160 | | $ | — | | $ | 397,800 | | $ | — | | $ | 17,319 | | $ | 1,749,279 | |
| 2020 | 612,000 | | — | | 973,079 | | — | | 1,585,080 | | — | | 18,790 | | 3,188,949 | |
| 2019 | 607,181 | | — | | 530,910 | | — | | 1,289,513 | | — | | 15,733 | | 2,443,337 | |
| James R. Hazlett, Vice President-Technical Services | 2021 | 225,100 | | — | | 184,025 | | — | | 73,158 | | — | | 30,726 | | 513,009 | |
| 2020 | 225,100 | | — | | 178,200 | | — | | 112,550 | | — | | 23,619 | | 539,469 | |
| 2019 | 224,596 | | — | | 56,400 | | — | | 42,112 | | — | | 34,824 | | 357,932 | |
Micah C. Foster, VP & Chief Financial Officer(1) | 2021 | 153,863 | | — | | 196,300 | | — | | 78,000 | | — | | 16,312 | | 444,475 | |
| 2020 | — | | — | | — | | — | | — | | — | | — | | — | |
| 2019 | — | | — | | — | | — | | — | | — | | — | | — | |
G. Larry Lawrence, Former VP & Chief Financial Officer(2) | 2021 | 35,000 | | 10,000 | | — | | — | | — | | — | | — | | 45,000 | |
| 2020 | — | | — | | — | | — | | — | | — | | — | | — | |
| 2019 | 198,858 | | — | | — | | — | | 32,871 | | — | | 15,461 | | 247,190 | |
James R. Lawrence, VP & Chief Financial Officer(3) | 2021 | — | | — | | — | | — | | — | | — | | — | | — | |
| 2020 | 205,346 | | — | | — | | — | | — | | — | | 19,022 | | 224,368 | |
| 2019 | 45,385 | | — | | 61,300 | | — | | — | | — | | 4,381 | | 111,066 | |
(1) Mr. Foster was appointed as our Vice President and Chief Financial Officer on May 11, 2021.
(2) Mr. G.L. Lawrence retired from the Company on November 15, 2019. Mr. G.L. Lawrence rejoined the Company in January 2021 and was appointed our interim Vice President and Chief Financial Officer until the appointment of Mr. Foster on May 11, 2021.
(3) Mr. J.R. Lawrence joined the Company on October 1, 2019 and was appointed as our Vice President and Chief Financial Officer on November 16, 2019. Mr. J.R. Lawrence gave notice of his resignation in December 2020.
(4) The amounts in column (c) includes amounts deferred under our Deferred Compensation Plan and 401(k) Plan. The Company has not made any contributions to the Deferred Compensation Plan.
(5) The amounts reflected in column (d) reflect discretionary bonus payments not covered under our Annual Incentive Bonus Plan.
(6) The amounts in column (e) reflect the grant date fair value of restricted stock/unit awards in accordance with FASB ASC Topic 718. The amounts shown for 2021 reflect the grant date fair value of stock granted contingent upon the approval by our shareholders of a proposal to increase the number of shares of our common stock reserved for issuance under the Natural Gas Services Group, Inc. 2019 Equity Incentive Plan (the "2019 Plan") that we intend to submit for a vote at our 2022 annual meeting of shareholders. To the extent that we are unable to obtain shareholder approval to increase the reserved shares under the 2019 Plan, we intend to pay the value of the awards in cash as they vest.
(7) The amounts in column (f) reflect the dollar amounts recognized for financial statement reporting purposes for the fiscal years ended December 31, 2021, 2020 and 2019, in accordance with FASB ASC Topic 718, associated with stock option grants under our Stock Option Plan.
(8) The amounts in column (g) reflect the cash bonus awards to the named executive officers under our Annual Incentive Bonus Plan, including amounts deferred under our Deferred Compensation Plan. The amount in column (g) for Mr. Taylor also includes a partylong-term incentive award for 2020 and 2019 of $973,080 and $1,061,820 (50% of his long-term incentive awards earned for each year), respectively, payable in either cash or a variable number of shares at the discretion of the Compensation Committee. These fixed value awards are subject to various legal proceedingsthree-year vesting in equal, annual tranches.
(9) The Deferred Compensation Plan referred to column (h) does not pay above-market or preferential earnings.
(10) The amounts shown in column (i) include matching contributions made by Natural Gas Services Group to each named executive officer under our 401(k) plan and the aggregate incremental cost to Natural Gas Services Group of perquisites provided to our named executive officers as shown in the ordinary coursetable below.
All Other Compensation Table
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Name | Year | Automobile Allowance | Personal Use of Company Provided Automobiles | Additional Incremental Portion of Health Insurance Premiums Paid for Officers Only | 401(k) Plan | Total |
| Stephen C. Taylor | 2021 | $ | — | | $ | 1,800 | | $ | 7,698 | | $ | 7,821 | | $ | 17,319 | |
| 2020 | — | | 1,800 | | 8,440 | | 8,550 | | 18,790 | |
| 2019 | — | | 1,800 | | 8,103 | | 5,830 | | 15,733 | |
| James R. Hazlett | 2021 | 10,200 | | — | | 13,467 | | 7,059 | | 30,726 | |
| 2020 | 10,200 | | — | | 6,360 | | 7,059 | | 23,619 | |
| 2019 | 10,200 | | — | | 17,580 | | 7,044 | | 34,824 | |
| Micah C. Foster | 2021 | 5,538 | | — | | 8,619 | | 2,155 | | 16,312 | |
| 2020 | — | | — | | — | | — | | — | |
| 2019 | — | | — | | — | | — | | — | |
| G. Larry Lawrence | 2021 | — | | — | | — | | — | | — | |
| 2020 | — | | — | | — | | — | | — | |
| 2019 | 9,219 | | — | | — | | 6,242 | | 15,461 | |
| James R. Lawrence | 2021 | — | | — | | — | | — | | — | |
| 2020 | 9,000 | | — | | 3,567 | | 6,455 | | 19,022 | |
| 2019 | 2,008 | | — | | 1,650 | | 723 | | 4,381 | |
Grants of Plan-Based Awards
The table below sets forth the estimated future payouts under non-equity incentive plan awards and restricted stock/unit awards granted and the grant date fair value of such awards.
Grants of Plan-Based Awards for 2021
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| | | Estimated Future Payouts Under Non-Equity Incentive Plan Awards | Estimated Future Payouts Under Equity Incentive Plan Awards | | | | |
| Name | Grant Date | Threshold ($) | Target ($) | Maxi-mum ($) | Threshold (#) | Target | Maxi-mum ($) | All Other Stock Awards: Number of Shares of Stock or Units (#) | All Other Option Awards: Number of Securities Underlying Option (#) | Exercise or Base Price of Option Awards ($/Sh) | Grant Date Fair Value of Stock and Option Awards ($) |
| (a) | (b) | (c) | (d) | (e) | (f) | (g) | (h) | (i) | (j) | (k) | (l) |
| Stephen C. Taylor | 4/25/2022(1) | $ | — | | $ | — | | $ | — | | — | — | $ | — | | 60,839 | | — | $ | — | | $ | 722,160 | |
3/29/2021(2) | 474,300 | | 612,000 | | 749,700 | | — | — | — | — | | — | — | — |
| James R. Hazlett | 3/18/2021(1) | — | | — | | — | | — | | — | | — | | 15,503 | | — | | — | | 184,025 | |
3/29/2021(2) | 87,188 | | 112,500 | | 137,813 | | — | | — | | — | | — | | — | | — | | — | |
| Micah C. Foster | 4/25/2022(1) | — | | — | | — | | — | | | — | | 16,537 | | — | | — | | 196,300 | |
3/29/2021(2) | 93,000 | | 120,000 | | 147,000 | | — | | — | | — | | — | | — | | — | | — | |
(1) The amounts shown on these rows reflects the awards of restricted stock or units earned in 2021, to be issued in 2022, contingent upon the approval by our shareholders of a proposal to increase the number of shares of common stock reserved for issuance under the 2019 Plan that we intend to submit for a vote at our 2022 annual meeting of shareholders. To the extent we are unable to obtain shareholder approval to increase the reserved shares under the 2019 Plan, we intend to pay the value of the award in cash as they vest.
(2) The amounts on these rows assume, under the structure of our Annual Incentive Bonus Plan, that each of the metrics are achieved under threshold (75% payout), target (100% payout), and maximum / stretch (125% payout) levels. The actual payouts in April 2022 that were earned in 2021 were as follows: Mr. Taylor - $397,800, Mr. Hazlett - $73,158 and Mr. Foster $78,000.
Short-Term Incentives - Annual Incentive Bonus Plan
In 2006, the Committee adopted an Annual Incentive Bonus Plan or, the “IBP,” that provides guidelines for the calculation of annual non-equity incentive based compensation in the form of cash bonuses to our executives, subject to Committee oversight and modification. The bonuses awarded under the IBP are short-term awards in recognition of the overall performance and efforts made by certain of our executives during a particular year. Each year, the Committee approves the group of executives eligible to participate in the IBP and establishes target award opportunities for such executives. For 2021, the Committee maintained Mr. Taylor’s target award opportunity at 100% of his base salary. Target award opportunity was 50% of average base salary for Mr. Hazlett and Mr. Foster.
For 2021, 100% of an executive officer’s IBP award was based on achievement of company financial and other objectives relating to:
•Cash flow from operations;
•Total revenues;
•ESG objectives; and
•Strategic and tactical initiatives.
Cash flow from operations accounts for 35% of the IBP, total revenues accounts for 25% of the IBP, ESG objectives accounts for 20% of the IBP and strategic and tactical initiatives accounts for the remaining 20%.
Each year, the Committee sets the performance levels for each component of the company objective portion of the IBP. The payment of awards under the IBP is based upon whether these performance levels are achieved for the year. Payout on each of the three financial objectives is as follows:
•75% of the bonus amount attributable to a financial component will be paid if we achieve the "threshold" amount;
•100% of the bonus amount attributable to a financial component will be paid if we achieve the "target" amount; and
•125% of the bonus amount attributable to a financial component will be paid if we achieve the "stretch" amount.
2021 Annual Incentive Bonus Plan
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| 2021 Executive Bonus Criteria | Cash Flow from Operations (1) | Revenue |
| Threshold achievement pays 75% of bonus | $ | 22,398,000 | | $ | 69,672,000 | |
| Target achievement pays 100% of bonus | 22,973,000 | | 71,458,000 | |
| Stretch achievement pays 125% of bonus | 23,547,000 | | 73,245,000 | |
(1) Cash flow from operations is an indicator of operating performance and is defined as the Company's rental and service and maintenance gross margins, before depreciation, less selling, general and administrative expenses adjusted to exclude (i) non-cash charges related to the Company's Non-qualified Deferred Compensation Plan, (ii) non-cash stock compensation expenses and (iii) director and officer cash long-term incentive compensation expenses.
The following table sets forth the maximum bonus eligibility set by the Committee for 2021 for each of our named executive officers, and based upon the payout percentages noted in the table above, the bonus payout amount earned by each named executive for 2021 under our Annual Incentive Bonus Plan: | | | | | | | | | | | | | | | | | | | | | | | | |
| Criteria | | Actual 2021 Performance | | Target Metric | | Stretch Metric | Eligible Bonus Payment
Percentage | Bonus Component | | Payable Bonus |
Cash flow from operations (1) | | $ | 20,344,000 | | | $ | 22,973,000 | | | $ | 23,547,000 | | — | % | 35 | % | | — | % |
| Revenue | | 72,420,000 | | | 71,458,000 | | | 73,245,000 | | 100 | % | 25 | % | | 25.0 | % |
| ESG objectives | | | | | | | 100 | % | 20 | % | | 20.0 | % |
| Strategic and tactical initiatives | | | | | | | 100 | % | 20 | % | | 20.0 | % |
| Total | | | | | | | | | | 65.0 | % |
(1)Cash flow from operations is an indicator of operating performance and is defined as the Company's rental and service and maintenance gross margins, before depreciation, less selling, general and administrative expenses adjusted to exclude (i) non-cash charges related to the Company's Non-qualified Deferred Compensation Plan, (ii) non-cash stock compensation expenses and (iii) director and officer cash long-term incentive compensation expenses.
In 2021, our executives received (i) no payout on cash flow from operations, as the Company's $20.3 million in cash flow from operations did not exceed its threshold achievement level of $22.4 million; (ii) a threshold financial metric payout on revenues, as the Company's $72.4 million in revenue met the target of $71.5 million but was below the stretch revenue of $73.2 million; (iii) a threshold payout on ESG objectives as management's performance met the board approved metrics; and (iv) a threshold payout on strategic and tactical initiatives as the committee considered the Company's 2021financial and operational performance as the individual performance of all three executives related to ensuring safe and continuous operations of the Company during the economic, industry and public health challenges presented by the COVID-19 pandemic.
The following table summarizes the bonuses awarded under the IBP for 2021:
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| Name | Title | Base Salary | Max Bonus Eligibility | Bonus Base | Bonus Payout % | Bonus Payouts |
| Stephen C. Taylor | President & CEO | $ | 612,000 | | | 100.0 | % | | $ | 612,000 | | | 65 | % | | $ | 397,800 | | |
| Micah C. Foster | VP & CFO | | 153,863 | | | 50.0 | % | | | 240,000 | | | 65 | % | | | 78,000 | | |
| James R. Hazlett | VP- Technical Services | | 225,100 | | | 50.0 | % | | | 225,100 | | | 65 | % | | | 73,158 | | |
1998 Stock Option Plan
Our 1998 Stock Option Plan, as amended and restated, provides for the issuance of stock options to purchase up to 1,000,000 shares of our common stock. The purpose of this plan is to attract and retain the best available personnel for positions of substantial responsibility and to provide long-term incentives to employees and consultants and to promote the long-term growth and success of our business. While managementThe plan is unableadministered by the Compensation Committee of the Board of Directors. At its discretion, the Compensation Committee determines the persons to predictwhom stock options may be granted and the ultimate outcometerms upon which options will be granted. In addition, the Compensation Committee may interpret the plan and may adopt, amend and rescind rules and regulations for its administration. Option awards are generally granted with an exercise price equal to the closing price of our common stock at the date of grant and generally vest based on three years of continuous service and have ten-year contractual terms.
As of December 31, 2021, stock options to purchase a total of 200,834 shares of our common stock were outstanding under the 1998 Stock Option Plan, as amended and restated, and a total of 345,003 shares of common stock were available at December 31, 2021 for future grants of stock options under the plan. Since the beginning of 2022, we have issued 2,500 stock options to purchase shares of our common stock with an additional 12,500 stock options that were either forfeited or expired, leaving 355,003 shares available under the 1998 Stock Option Plan as of April 29, 2022.
2019 Equity Incentive Plan
On June 20, 2019, the Company's shareholders approved our 2019 Equity Incentive Plan ("2019 Plan"). Except with respect to awards then outstanding, unless sooner terminated by the Board, the Plan will expire on the tenth anniversary of the date it was approved by shareholders (June 20, 2029) and no further awards may be granted after such date. The purposes of the 2019 Plan are to enable the Company to attract and retain the types of employees, consultants and Directors who will contribute to the Company’s long range success; provide incentives that align the interests of employees, consultants and Directors with those of the shareholders of the Company; and promote the success of the Company’s business.
The following summary of the material terms of the 2019 Plan is qualified in its entirety by the full text of the 2019 Plan, a copy of which was filed with our proxy statement for 2019 and may be obtained, free of charge, by writing to the Company, Attention: Alicia Dada, Investors Relations, 404 Veterans Airpark Lane, Suite 300, Midland, Texas 79705.
Shares Available for Awards and Limits on Awards. The Company has reserved an aggregate of 500,000 shares of common stock to be awarded under the 2019 Plan. Up to 250,000 of these actions, it believesshares may be issued under the 2019 Plan, in the aggregate, through the exercise of incentive stock options. No non-employee Director may be granted awards, during any fiscal year, with respect to shares of common stock that, together with any ultimate liability arising fromcash fees paid to the Director during the fiscal year, have a total value that exceeds $250,000 (calculating the value of any awards based on the grant date fair value for financial reporting purposes).
As of March 31, 2022, we have issued 456,198 shares under the 2019 Plan. Of these actionsshares, 287,011 have vested and are no longer subject to any restrictions or possible forfeiture and 3,333 shares were forfeited and returned to the pool. Vested shares include shares that were withheld for taxes and, under the terms of the 2019 Plan, cannot be re-issued. 165,854 unvested shares of common stock remain reserved for potential issuance under outstanding awards and may be issued if the vesting terms of such outstanding awards are met. Accordingly, 47,135 shares are available to be issued under the 2019 Plan as of March 31, 2022.
If any outstanding award expires or is canceled, forfeited, or terminated without issuance or vesting of the full number of shares of common stock to which the award related, then such number of shares that expired, or were canceled, forfeited or terminated will be available for future awards under the 2019 Plan. Shares tendered in payment of the option exercise price, shares delivered or withheld by the Company to satisfy any tax withholding obligation, or shares covered by a stock-settled stock appreciation right or other awards that used shares upon the settlement of the award will not again become available for future grants under the 2019 Plan.
Awards may be granted under the 2019 Plan in assumption of, or in substitution for, outstanding awards previously granted by an entity acquired by the Company or with which the Company combines. The Committee (as defined below) will make appropriate adjustments to these limits to prevent dilution or enlargement of the rights of participants under the 2019 Plan.
Administration and Amendment. The 2019 Plan is administered by the Compensation Committee (the "Committee"), or, in the Board’s discretion, by the Board. The Committee will have the authority to, among other things, interpret the 2019 Plan; determine who will be granted awards under the 2019 Plan; prescribe the terms and conditions of each award; interpret, administer, reconcile any inconsistency in, correct any defect in, and supply any omission in the 2019 Plan; and exercise discretion to make any and all other determinations which it determines to be necessary or advisable for the administration of the 2019 Plan.
The Committee may also amend the terms of any one or more awards. However, the Committee may not affect any amendment which would otherwise constitute an impairment of the rights under any award unless the Company requests the consent of the participant and the participant consents in writing.
The Board may amend the 2019 Plan. However, except in the case of adjustments upon changes in common stock, no material amendment will be effective unless approved by the shareholders of the Company to the extent shareholder approval is necessary to satisfy any applicable laws.
Eligibility. The Board selects participants from among the key employees, consultants and Directors of the Company and its affiliates. Only employees are eligible to receive incentive stock options.
Available Awards. Awards that may be granted under the 2019 Plan include restricted stock, restricted stock units (RSUs), performance awards, stock options (including both incentive stock options (ISOs) and nonqualified stock options), stock appreciation rights (SARs), and other stock-based awards. The terms of each award will be set forth in a written agreement.
Restricted Stock. A restricted stock award is an award of actual shares of common stock which are subject to certain restrictions for a period of time determined by the Committee. Restricted stock may be held by the Company in escrow or delivered to the participant pending the release of the restrictions. The participant generally has the rights and privileges of a shareholder as to such restricted stock during the restricted period, including the right to vote the restricted stock and the right to receive dividends
Restricted Stock Units. An RSU is an award of hypothetical common stock units having a value equal to the fair market value of an identical number of shares of common stock, which are subject to certain restrictions for a period of time determined by the Committee. No shares of common stock are issued at the time an RSU is granted, and the Company is not required to set aside any funds for the payment of any RSU award. Prior to settlement of an RSU award and the receipt of shares, the participant does not have any rights as a shareholder with respect to such shares. The Committee may grant RSUs with a deferral feature (deferred stock units or DSUs), whereby settlement of the RSU is deferred beyond the vesting date until a future payment date or event set out in the participant’s award agreement. The Committee has the discretion to credit RSUs or DSUs with dividend equivalents.
Performance Share Awards. A performance share award is an award of shares of common stock that are only earned if certain conditions are met. The Committee has the discretion to determine the following: the number of shares of common stock or stock-denominated units subject to a performance share award; the applicable performance period; the conditions that must be satisfied for a participant to earn an award; and the other terms, conditions and restrictions of the award. The number of performance shares earned by a participant depends on the extent to which the performance goals established by the Committee are attained within the applicable performance period. No payout is made with respect to any performance share award except upon written certification by the Committee that the minimum threshold performance goal(s) have been achieved.
Stock Options. A stock option is the right to purchase shares of common stock at a future date at a specified price per share called the exercise price. An option may be either an ISO or a nonqualified stock option. ISOs and nonqualified stock options are taxed differently. Except in the case of options granted pursuant to an assumption or substitution for another option, the exercise price of a stock option may not be less than the fair market value (or in the case of an ISO granted to a ten percent shareholder, 110% of the fair market value) of a share of common stock on the grant date. As of the record date, the closing price of our common stock was $9.05. Full payment of the exercise price must be made at the time of such exercise either in cash or bank check or in another manner approved by the Committee.
Stock Appreciation Rights. A SAR is the right to receive payment of an amount equal to the excess of the fair market value of a share of common stock on the date of exercise of the SAR over the exercise price. The exercise price of a SAR may not be less than the fair market value of a share of common stock on the grant date. SARs may be granted alone ("freestanding rights”) or in tandem with options ("related rights”).
Other Equity-Based Awards. The Committee may grant other equity-based awards, either alone or in tandem with other awards, in amounts and subject to conditions as determined by the Committee as set out in an award agreement.
Vesting. The 2019 Plan allows for awards subject to either time-based vesting or performance-based vesting, or both. All awards granted under the 2019 Plan must have a minimum vesting period of at least one year. The Committee has the authority to determine the vesting schedule of each award (subject to the minimum one-year requirement), and to accelerate the vesting and ability to exercise any award. The Company’s practice over the last several years has been to grant restricted stock/unit awards to its executive officers and independent Directors, and stock options to selected non-executive employees. Restricted stock/unit awards to our (i) executive officers have been subject to time-based vesting in equal one-third installments over a three-year period from the grant date and (ii) independent Directors were subject to time-based vesting in equal quarterly installments beginning in the year following the year in which they are granted. However, starting in 2020, the awards to independent Directors are subject to one-year cliff vesting. Stock options granted to our non-executive employees typically vest in equal, one-third tranches over a three-year period. Past vesting requirements may not be indicative of future vesting requirements set by the Committee, which may be less or more onerous than in prior years.
Clawback and Recoupment. The Company may cancel any award or require the participant to reimburse any previously paid compensation provided under the 2019 Plan or an award agreement in accordance with the Company’s clawback policy.
Termination of Service. Unless otherwise set forth in an individual award agreement or in an employment agreement approved by the Committee, any unvested restricted shares, performance shares, RSUs, PSUs and other equity-based awards will immediately be forfeited upon termination of continuous service under the 2019 Plan. Under the Company's restricted
stock and RSU award agreements, if the grantee's continuous service terminates as a result of the grantee's death, Disability (as defined in the 2019 Plan), termination without Cause (as defined in the 2019 Plan and below) or termination for Good Reason (as defined), 100% of the grantee's unvested shares will vest.
Unless otherwise set forth in an individual award agreement or in an employment agreement approved by the Committee, in the event an option holder's continuous service terminates, an option holder may exercise his or her option (to the extent the option holder was entitled to exercise such option at the date of termination) within the earlier of three months following the date of termination or the expiration of the option term. Unless otherwise set forth in an individual award agreement, in the event an option holder's continuous service terminates upon his or her death or Disability (as defined), an option holder or his or her estate may exercise his or her option (to the extent the option holder was entitled to exercise such option at the date of termination), within the earlier of 12 months following the date of termination or the expiration of the option term.
In regard to the definition of Cause under the 2019 Plan, if a participant is under an employment or service agreement with the Company and such agreement provides for a definition of Cause, that definition should be used. If no such agreement exists, or if such agreement does not define Cause, then Cause is defined as (i) the conviction of, or plea of guilty or no contest to, a felony or a crime involving moral turpitude or the commission of any other act involving willful malfeasance or material effectfiduciary breach with respect to the Company or an Affiliate; (ii) conduct that results in or is reasonably likely to result in harm to the reputation or business of the Company or any of its Affiliates; (iii) gross negligence or willful misconduct with respect to the Company or an Affiliate; or (iv) material violation of state or federal securities laws.
In regard to the definition of Good Reason under the 2019 Plan, if a participant is under an employment or service agreement with the Company and such agreement provides for a definition of Good Reason, that definition should be used. If no such agreement exists, or if such agreement does not define Good Reason, Good Reason is defined as the occurrence of one or more of the following without the participant’s express written consent, which circumstances are not remedied by the Company within thirty (30) days of its receipt of a written notice from the participant describing the applicable circumstances (which notice must be provided by the participant within ninety (90) days of the participant's knowledge of the applicable circumstances): (i) any material, adverse change in the participant's duties, responsibilities, authority, title, status or reporting structure; (ii) a material reduction in the participant’s base salary or bonus opportunity; or (iii) a geographical relocation of the participant's principal office location by more than fifty (50) miles.
Change in Control. A Change in Control is defined as (a) the acquisition by one person or more than one person acting as a group, of Company stock representing more than 50% of the total fair market value or total voting power of the Company’s stock; (b) a merger, consolidation or other reorganization in which the Company is not the surviving entity unless the Company’s shareholders immediately prior to the merger, consolidation or other reorganization maintain at least 50% of the voting power; (c) a majority of the incumbent members of the Board are replaced by Directors whose appointment or election is not endorsed by at least two-thirds of the Board; or (d) the acquisition by one person or more than one person acting as a group, of all or substantially all of the Company’s assets.
Unless otherwise provided in an award agreement, in the event of a participant’s termination of service without Cause or for Good Reason during the 18-month period following a Change in Control, the vesting of all awards will fully accelerate and all outstanding options and SARs will become immediately exercisable as of the date of the participant’s termination of service.
In the case of performance awards, in the event of a participant’s termination of service without Cause or for Good Reason, in either case, within 18 months following a Change in Control, all performance goals or other vesting criteria will be deemed achieved at 100% of target levels and all other terms and conditions will be deemed met as of the date of the participant’s termination of service.
In the event of a Change in Control, the Committee may in its discretion and upon at least 10 days’ advance notice to the affected persons, cancel any outstanding awards and pay to the holders the value of the awards based upon the price per share of common stock received or to be received by other shareholders of the Company in the event. In the case of any option or SAR with an exercise price that equals or exceeds the price paid for a share of common stock in connection with the change in control, the Committee may cancel the option or SAR without the payment of any consideration.
Outstanding Equity Awards at Fiscal Year-End
The following table shows certain information about unvested restricted stock/units and unexercised stock options outstanding as of December 31, 2021 and held by our Chief Executive Officer, Stephen C. Taylor, and each other named executive officer.
Outstanding Equity Awards at 2021 Fiscal Year-End
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | Option Awards | Stock Awards |
Name | Number of Securities Underlying Unexercised Options (#) Exercisable | Number of Securities Underlying Unexercised Options (#) Unexercisable | Equity Incentive Plan Awards: Number of Securities Underlying Unexercised Options (#) | Option Exercise Price ($) | Option Expiration Date | Number of Shares of Stock That Have Not Vested (#) | Market Value of Shares of Stock that Have Not Vested ($) | Equity Incentive Plan Awards: Number of Unearned Shares or Other Rights that Have Not Vested (#) | Equity Incentive Plan Awards: Market or Payout Value of Unearned Shares or Other Rights that Have Not Vested ($) |
| (a) | (b) | (c) | (d) | (e) | (f) | (g) | (h) | (i) | (j) |
| Stephen C. Taylor | — | — | — | — | — | 43,891 | $ | 459,539 | | — | — |
| — | — | — | — | — | 62,755 | 657,045 | — | — |
| — | — | — | — | — | 109,212 | 1,143,450 | — | — |
| James R. Hazlett | — | — | — | — | — | 6,667 | 69,803 | — | — |
| — | — | — | — | — | 6,667 | 69,803 | — | — |
| — | — | — | — | — | 20,000 | 209,400 | — | — |
| Micah C. Foster | — | — | — | — | — | 5,000 | 52,350 | — | — |
Option Exercises and Stock Vested in 2021
In the table below, we show certain information about (i) the number of shares of common stock acquired upon exercise of stock options by each of the named executive officers in 2021 and the value realized on exercise of the stock options and (ii) stock awards.
| | | | | | | | | | | | | | |
| | Option Awards | Stock Awards |
| Name | Number of Shares Acquired on Exercise (#) | Value Realized on Exercise ($) | Number of Shares Acquired on Vesting(1) | Value Realized on Vesting(1) |
| (a) | (b) | (c) | (d) | (e) |
| Stephen C. Taylor | — | | $ | — | | 80,075 | $ | 744,316 | |
| James R. Hazlett | — | | — | | 15,332 | 143,601 |
(1) Excludes the following shares that vested (with values upon vesting) and were contributed to the Company's nonqualified deferred compensation plan as follows: Mr. Taylor - 23,428 shares for $220,208; and Mr. Hazlett - 1,333 shares for $12,983.
Nonqualified Deferred Compensation
We adopted a Deferred Compensation Plan in December 2015, which permits eligible employees, including our NEOs, and our Directors to annually elect to defer a portion of their salary, commissions, cash bonus, Director fees and/or stock awards they would otherwise have received when earned. Under this plan, participants can defer up to 90% of their salary, commissions, cash bonus, Director fees and stock awards. Cash amounts deferred under the Deferred Compensation Plan are deemed invested in the investment funds selected by the participant with similar options as available under the Company’s 401(k) Plan. We have option to contribute but do not currently contribute to the Deferred Compensation Plan on behalf of its participants or match the deferrals made by participants.
At the time of deferral, a participant must indicate whether he or she wishes to receive the amount deferred while in-service or upon separation of service. In either case, the payment will be in either a lump sum or in substantially equal annual installments. In-service installments cannot exceed five years, while installments elected to start upon separation of service cannot exceed ten years. If separation is due to a disability or a change in control, deferrals will be paid similar to deferrals paid upon separation of service, while deferrals related to death will be paid in a lump sum to the participant’s beneficiary. If a participant experiences an unforeseeable emergency during the deferral period, the participant may petition to receive a partial or full payout from the Deferred Compensation Plan. All distributions are made in cash, except for deferred stock awards which are settled in Company stock.
Deferred Compensation Table
| | | | | | | | | | | | | | | | | | | | |
| Name | Beginning Aggregate Balance | Executive Contributions in Last FY ($) (1) | Registrant Contributions in Last FY ($) | Aggregate Earnings in Last FY ($) | Aggregate Withdrawals/Distributions ($) | Aggregate Balance at Last Fiscal Year End ($) |
| Stephen C. Taylor | $ 2,573,055 | $ 278,251 | $ — | $ 551,250 | $ — | $ 3,402,556 |
| G. Larry Lawrence | 157,550 | — | — | 18,651 | (65,865) | 110,336 |
| James R. Hazlett | 339,004 | 24,672 | — | 63,469 | — | 427,145 |
(1) All contributions were from salary, bonus and stock deferrals in 2021. The Company has made no contributions to the Deferred Compensation Plan.
Compensation of Directors
We use a combination of cash and equity-based incentive compensation to attract and retain qualified candidates to serve on our Board of Directors. In setting compensation for our Directors, we consider the substantial amount of time that Directors expend in fulfilling their duties to us and our shareholders, as well as the skill-sets required to fulfill these duties.
The following table discloses the cash, equity awards and other compensation earned, paid or awarded, as the case may be, to each of our non-employee Directors during the fiscal years ended December 31, 2021, 2020 and 2019:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
| Name | Year | Fees Earned Or Paid ($)(1) | Stock Awards ($)(2) | Option Awards ($) | Non-Equity Incentive Plan Compensation ($) | Change in Pension Value and Nonqualified Deferred Compensation Earnings | All Other Compensation ($) | Total ($) |
| (a) | | (b) | (c) | (d) | (e) | (f) | (g) | (h) |
| Leslie A. Beyer | 2021 | $ | 66,250 | | $ | 50,003 | | $ | — | | $ | 50,000 | | $ | — | | $ | — | | $ 166,253 |
| 2020 | 27,500 | 12,499 | — | 25,000 | — | — | 64,999 |
| 2019 | — | — | — | — | — | — | — |
| David L. Bradshaw | 2021 | 68,750 | 50,003 | — | 50,000 | — | — | 168,753 |
| 2020 | 65,000 | 24,996 | — | 50,000 | — | — | 139,996 |
| 2019 | 65,000 | 100,005 | — | — | — | — | 165,005 |
| John Chisholm | 2021 | 68,750 | 50,003 | — | 50,000 | — | — | 168,753 |
| 2020 | 60,000 | 24,996 | — | 50,000 | — | — | 134,996 |
| 2019 | 55,000 | 100,005 | — | — | — | — | 155,005 |
| Charles G. Curtis | 2021 | — | — | — | — | — | — | — |
| 2020 | 32,500 | 24,996 | — | — | — | — | 57,496 |
| 2019 | 60,000 | 100,005 | — | — | — | — | 160,005 |
| William F. Hughes, Jr. | 2021 | 16,250 | — | — | — | — | — | 16,250 |
| 2020 | 65,000 | 24,996 | — | 50,000 | — | — | 139,996 |
| 2019 | 65,000 | 100,005 | — | — | — | — | 165,005 |
| Nigel J. Jenvey | 2021 | 52,500 | 50,000 | — | 50,000 | — | — | 152,500 |
| 2020 | — | — | — | — | — | — | — |
| 2019 | — | — | — | — | — | — | — |
(1) Our non-employee Directors are paid a quarterly cash fee. The cash fee payable to our non-employee Directors was $13,750 per quarter for 2021 and $12,500 per quarter for 2020 and 2019. In addition, the Chairman of the Audit Committee, David L. Bradshaw, the Chairman of the Compensation Committee, Leslie A. Beyer, the Chairman of the ESG and Personnel Development Committee, Nigel J. Jenvey and the Chairman of the Nominating Committee and Lead Director, John Chisholm, were entitled to an additional quarterly cash fee in the amount of $3,750.
(2) On March 18, 2021, each of our non-employee Directors were granted 5,612 restricted shares at an issue price of $8.91 per share; on April 1, 2021, Mr. Jenvey was granted 5,291 restricted shares at an issue price of $9.45; on April 28, 2020, each of our non-employee Directors were granted 4,432 restricted shares at an issue price of $5.64 per share; on October 15, 2020, Ms. Beyer was granted 1,324 restricted shares at an issue price of $9.44; and on March 29, 2019, each of our non-employee Directors were granted 5,784 restricted shares/units at an issue price of $17.29 per share.
Cash Compensation Paid to Independent Directors
We pay our non-employee Directors a quarterly cash fee for their attendance at each meeting of our Board of Directors. The cash fee payable to our non-employee Directors for 2021 was $13,750 per quarter and $12,500 per quarter for 2020 and 2019. In addition, the Chairmen of the Audit, Compensation, ESG and Nominating Committees were entitled to an additional quarterly cash fee in the amount of $3,750.
Equity Based Compensation Paid to Independent Directors
Our compensation policy for independent Directors is to grant an annual award of restricted shares based upon a review of equity award values paid by other public companies in the Company's peer group and the Company's market and financial performance in comparison to such peer group companies. For 2021, based upon the Company's performance compared to its peer group, the Compensation Committee recommended and the Board approved an equity award value of
approximately $100,000 in restricted stock. However, because of the depressed nature of the energy industry and dilutive nature of the Company's stock at then current market prices, the Board determined to modify the award into a 50/50 split of stock and cash. In connection therewith, on March 18, 2021, each of our three independent Directors were granted the following:
•An award of $50,000 in cash (50% of the total) that vests one year from the date of grant; and
•An award of 5,612 shares of restricted stock, which was calculated by dividing $50,000 by the closing share price of $8.91 on that day. These awards of restricted stock vest one year from the date of grant and are subject to acceleration in certain events.
On April 1, 2021, William F. Hughes retired and resigned from his position resultsas a member of operationsthe Board of Directors of the Company. In recognition of Mr. Hughes’ longstanding service, the Compensation Committee voted to accelerate the vesting of the following unvested shares, free of any further restrictions:
•3,989 restricted stock units
•443 restricted stock awards
On April 1, 2021, the Board appointed Nigel J. Jenvey as a Director of the Company. Consistent with the compensation of the other non-employee Directors, the Compensation Committee awarded Mr. Jenvey the following:
•An award of $50,000 in cash (50% of the total) that vests one year from the date of grant; and
•An award of 5,291 shares of restricted stock, which was calculated by dividing $50,000 by the closing share price of $9.45 on that day. These awards of restricted stock vest one year from the date of grant and are subject to acceleration in certain events.
On April 25, 2022, the Compensation Committee recommended and the Board approved the continuation of its annual equity award policy of $100,000 in value of restricted stock and cash, for 2022. In connection therewith, four independent Directors were granted the following:
•An award of $50,000 in cash (50% of the total) that vests one year from the date of grant; and
•An award of 4,212 shares of restricted stock, which was calculated by dividing $50,000 by a deemed share price of $11.87. These awards of restricted stock vest one year from the date of grant and are subject to acceleration in certain events.
Directors who are our employees do not receive any compensation for their services as Directors.
Other
All Directors are reimbursed for their expenses incurred in connection with attending meetings. We provide liability insurance for our Directors and officers. The cost of this coverage for 2021 was $221,723. We do not offer non-employee Directors travel accident insurance, life insurance, or a pension or retirement plan.
Compensation Agreements with Management
On October 23, 2013, Stephen C. Taylor entered into a new employment agreement with us (the “Employment Agreement”), pursuant to which Mr. Taylor continues his employment as our President and Chief Executive Officer. The new Employment Agreement became effective on the same date and Mr. Taylor’s previous employment agreement with us, which was set to expire on October 25, 2013, was terminated in connection therewith.
On April 24, 2015, we entered into an amendment with Mr. Taylor to his Employment Agreement pursuant to which the "modified single trigger" change of control provision was changed to a "double trigger" change of control. Under the "modified single trigger provision", Mr. Taylor could voluntarily terminate the Employment Agreement for any reason and collect severance benefits. Under the new "double trigger" change of control provision, a change of control must occur followed by the Company or its successor terminating Mr. Taylor's employment other than for cause, death, or disability, or by Mr. Taylor terminating his employment for Good Reason. We discuss the definitions of "Change of Control" and "Good Reason" below, along with Mr. Taylor's severance benefits in connection with these events.
The term of the Employment Agreement is for three years but the agreement contains an “evergreen” feature whereby the agreement is automatically extended on a monthly basis on the last day of each month so that the term of the agreement will always be three years unless written notice of nonrenewal is given by the Company. If a notice of nonrenewal is given, the term of employment then ends three years from the date of that written notice of nonrenewal unless terminated earlier as described below. The Employment Agreement provides for Mr. Taylor to receive a base salary, potential cash flow. bonus, equity compensation, and certain other benefits, which are summarized below.
Base Salary. Mr. Taylor is entitled to Base Salary which is reviewed annually at the beginning of the year by, and may be increased at the discretion of, the Compensation Committee of the Board of Directors of the Company (the “Compensation Committee”).
Bonus. Mr. Taylor will continue to be eligible for an annual cash bonus under the Company’s current Annual Incentive Bonus Plan. Mr. Taylor’s annual bonus opportunity payable upon achievement of “target” levels shall be at least ninety percent (90%) of Base Salary for 2013 and at least one hundred percent (100%) thereafter. The performance metrics, weighting and thresholds for each annual bonus opportunity will be determined by the Company’s Board of Directors or Compensation Committee in good faith following consultation with Mr. Taylor.
Annual Equity Compensation. Mr. Taylor is eligible for annual grants of equity-based incentive awards under the Company’s equity compensation plans. While the agreement provides an annual equity award grant to Mr. Taylor with an aggregate minimum value equal to 175% of his Base Salary, subject to one-year vesting terms, Mr. Taylor has waived the 175% and one-year vesting requirement for the past four years in order to enable the Compensation Committee to make discretionary and performance based awards with a three-year vesting term (subject to customary acceleration) in keeping with current public company pay practices.
Benefits. The Company will provide Mr. Taylor such retirement, and other benefits as are customarily provided to similarly situated executives of the Company, including paid vacation, coverage under the Company’s medical, life, disability and other insurance plans, and reimbursement for all reasonable business expenses in accordance with the Company’s expense reimbursement policy.
Termination. The Company or Mr. Taylor may terminate the agreement prior to the expiration of its Term at any time upon written notice.
Severance upon Early Termination. Mr. Taylor will be entitled to the following severance benefits during the first ten years of his employment:
(A) If (i) the Company terminates Mr. Taylor's agreement without Cause (ii) Mr. Taylor terminates the agreement for Good Reason or due to a Change of Control event (as defined below) followed by the Company or its successor terminating Mr. Taylor's agreement without cause or Mr. Taylor terminating the agreement for Good Reason or (iii) Mr. Taylor's employment is terminated due to death or disability, then he will receive (a) a lump sum payment equal to 300% of Base Salary and Annual Bonus; (b) vesting of all unvested equity awards or other long-term incentive compensation; (c) continuation of health insurance benefits and payment of any life insurance premiums for a period of 36 months after termination; and (d) receipt of any other vested benefits which had not yet been paid prior to the date of termination.
(B) If Mr. Taylor's employment is terminated for Cause or he voluntarily resigns, then he will be entitled to any unpaid compensation earned through the date of termination and receipt of any other vested benefits which had not yet been paid prior to the date of termination.
(C) If Mr. Taylor retires in compliance with the Company's retirement policy, then he will be entitled to (i) any unpaid compensation earned through the date of retirement; (ii) vesting of all unvested equity awards or other long-term incentive compensation; and (iii) receipt of any other vested benefits which had not yet been paid prior to the date of termination.
After the tenth anniversary date of Mr. Taylor's employment agreement, in the event the Company delivers to Mr. Taylor a Notice of Nonrenewal and:
(A) his employment is automatically terminated upon the expiration of the remaining three year term, Mr. Taylor shall be entitled to (i) any unpaid compensation earned through the date of retirement; (ii) vesting of all unvested equity awards or other long-term incentive compensation; and (iii) receipt of any other vested benefits which had not yet been paid prior to the date of; or
(B) his employment is terminated prior to the expiration of the remaining three year term, unless said termination is due to Cause, voluntary resignation or retirement, then Mr. Taylor shall be entitled to (i) lump sum payment of his Base Salary at the time of termination for the remainder of the three year term of the agreement; (ii) a lump sum cash payment equal to 100% of the Annual Bonus for each full year (if any) remaining in the three year term, plus a pro rata portion of such Annual Bonus for any partial remaining year in the three year term; (iii) vesting of all unvested equity awards or other long-term incentive compensation; (iv) continuation of health insurance benefits and payment of any life insurance premiums for the remainder of the three year term of the agreement; and (v) receipt of any other vested benefits which had not yet been paid prior to the date of termination.
Under the Employment Agreement, a "Change of Control" event includes (i) the acquisition by a person, entity or group of related persons or entities of more than 30% of the total voting power in the Company (excluding sales to underwriters in a public offering); (ii) consummation of the sale of 50% or more of the Company's assets; (iii) consummation of a merger or consolidation of the Company with or into an entity unless the voting securities of the Company immediately prior to the merger or consolidation continue to represent more the 70% of the voting power of the surviving entity after the merger or consolidation; and (iv) replacement of at least a majority of the incumbent members of the Company's Board of Directors, excluding Directors whose election to the Board was approved by at least a majority of the then incumbent Directors, subject to further limited exceptions as set forth in the "Change of Control" definition in Employment Agreement.
Under the Employment Agreement, a "Good Reason" event includes (i) a material diminution of Mr. Taylor's duties, control, authority or status or position or a requirement that the Executive report to a corporate officer or employee instead of reporting directly to the Board of Directors; (ii) a material reduction in Mr. Taylor's compensation; (iii) a material breach by the Company of the Employment Agreement; or (iv) a relocation of more than 50 miles of Mr. Taylor's principal office with the
Company or its successor. And in connection with a termination due to Change of Control, the following provisions also constitute “Good Reason” events: (i) a material diminution of Mr. Taylor's duties, control, authority or status or position or a requirement that Mr. Taylor report to a corporate officer or employee instead of reporting directly to the Company's or successor’s Board of Directors depending on its composition after the change in control; (ii) the failure of the Company or successor to continue in effect any plan in which Mr. Taylor participates immediately prior to the Change in Control which is material to the Executive’s total compensation, unless an equitable arrangement has been made with respect to any such plan on a basis not less favorable, both in terms of the amount or timing of payment of benefits provided; and (iii) a material breach by the Company or its successor of the Employment Agreement or any other material agreement between Mr. Taylor and the Company or its successor.
Non-Competition and Non-Solicitation. In connection with the payment of the severance benefits described above, for a period of two years following Mr. Taylor’s separation from the Company, he may not compete with the Company in any geographic area within a 100 mile radius of a Company owned or leased facility which is Company staffed and actively engaging in business on behalf of the Company.
We do not have any written employment agreements with our other named executive officers.
Limitation on Directors’ and Officers’ Liability
Our Articles of Incorporation provide our Directors and Officers with certain limitations on liability to us or any of our shareholders for damages for breach of fiduciary duty as a Director or officer involving certain acts or omissions of any such Director or Officer.
This limitation on liability may have the effect of reducing the likelihood of derivative litigation against Directors and Officers, and may discourage or deter shareholders or management from bringing a lawsuit against Directors and Officers for breach of their duty of care even though such an action, if successful, might otherwise have benefited our shareholders and us.
Our Articles of Incorporation and bylaws provide certain indemnification privileges to our Directors, employees, agents and officers against liabilities incurred in legal proceedings. Also, our Directors, employees, agents or officers who are successful, on the merits or otherwise, in defense of any proceeding to which he or she was a party, are entitled to receive indemnification against expenses, including attorneys’ fees, incurred in connection with the proceeding.
We are not currently a party
aware of any pending litigation or proceeding involving any of our Directors, officers, employees or agents as to any bankruptcy, receivership, reorganization, adjustmentwhich indemnification is being or similar proceeding,may be sought, and we are not aware of any materialother pending or threatened litigation.litigation that may result in claims for indemnification by any of our Directors, officers, employees or agents.
ITEM 4. MINE SAFETY DISCLOSURES
Not applicable.
PART II
ITEM 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND
ISSUER PURCHASES OF EQUITY SECURITIES
Our common stock currently trades onFor purposes of the New York Stock Exchangefollowing tables, "beneficial ownership" is determined in accordance with Rule 13d-3 under the symbol “NGS”. AsSecurities Exchange Act of December 31, 2021 as reflected by our transfer agent records, we had 15 record holders1934, pursuant to which a person or group of persons is deemed to have "beneficial ownership" of any shares of Common Stock that such person has the right to acquire within 60 days.
The following table indicates the beneficial ownership of our common stock. ThisCommon Stock as of April 29, 2022 by: (1) each of our Directors and nominees for election; (2) our Chief Executive Officer, principal accounting officer and our other named executive officers (as defined in Item 402(a) (3) of Regulation S-K) (together as a group, the "Named Executive Officers "); and (3) all of our current Directors, nominees and executive officers as a group, based on our records and data supplied by each of the current Directors, nominees and executive officers.
Schedule of Beneficial Ownership
| | | | | | | | |
| Name of Beneficial Owner and Position | Amount and Nature of Beneficial Ownership (1) | Percent of Class |
Directors & Nominees Who Are Not Named Executive Officers | | |
| | | |
| Leslie A. Beyer - Current Director | 11,148 | * |
| David L. Bradshaw - Current Director | 36,256 | * |
| John W. Chisholm - Director Nominee | 13,004 | * |
| Nigel J. Jenvey - Current Director | 9,503 | * |
| | | |
| Named Executive Officers | | |
| | | |
Stephen C. Taylor - Chief Executive Officer and Current Director(2) | 656,852 | 5.17% |
James R. Hazlett - Vice President - Technical Services(3) | 96,030 | * |
| Micah C. Foster - Vice President and Chief Financial Officer | 5,000 | * |
| All Directors (and nominees) and executive officers as a group (7 persons) | 827,793 | 6.58% |
* Less than one percent.
(1) The number does not include any beneficial owners for whomof shares listed includes all shares of common stock may be heldowned or indirectly owned by, which vest within 60 days of April 29, 2022, under outstanding restricted stock units. Beneficial ownership is calculated in “nominee” or “street” name. On March 14, 2022,accordance with the last reported sale pricerules of ourthe Securities and Exchange Commission. Unless otherwise indicated, all shares of common stock as reportedare held directly with sole voting and investment powers. As of April 29, 2022, none of the shares of common stock owned by the New York Stock Exchange was $11.82 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 agreement also contains restrictions on our paying dividends under certain circumstances.
Equity Compensation Plans
The following table summarizes certain information regarding our equity compensation plans as of December 31, 2021:
| | | | | | | | | | | | | | | | | | | | | | | | | | |
Plan Category | | (a) Number of securities to vest or be issued upon exercise of outstanding options | | (b) Weighted-average issuance or exercise price of outstanding options | | (c) Number of securities remaining available for future issuance under equity compensation plans (excluding securities reflected in column (a)) |
| Equity compensation plans approved by security holders: | | | | | | | | |
| Stock Option Plan | | 200,834 | | | (1) | | $ | 21.17 | | | 345,003 | |
| 2019 Equity Incentive Plan | | 276,319 | | | | | $ | 9.67 | | | 47,135 | |
| Total | | 477,153 | | | | | | | 392,138 | |
(1) Total number of shares to be issued upon exercise of options granted to employees, officers and directors under our 1998 Stock OptionDirectors had been pledged as collateral to secure repayment of loans.
(2) Includes 130,563 shares of common stock held indirectly by a “rabbi trust” the receipt of which has been deferred by Mr. Taylor pursuant to the Company’s Nonqualified Deferred Compensation Plan.
(3) Includes 19,000 shares of common stock held indirectly by a “rabbi trust” the receipt of which has been deferred by Mr. Hazlett pursuant to the Company’s Nonqualified Deferred Compensation Plan.
SaleThe following table sets forth information as of UnregisteredApril 29, 2022 regarding the beneficial owners of more than five percent of the outstanding shares of our Common Stock. To our knowledge, there are no beneficial owners of more than five percent of the outstanding shares of our Common Stock as of April 29, 2022 other than those set forth below.
| | | | | | | | |
| Name and Address of Beneficial Owner | Amount and Nature of Beneficial Ownership | Percent of Class |
| | | |
FMR LLC(1) | 1,315,540 | 10.47% |
| 245 Summer Street | | |
| Boston, Massachusetts 02210 | | |
| | |
Dimensional Fund Advisors LP(2) | 943,255 | 7.51 |
| Palisades West, Building One, 6300 Bee Cave Road | | |
| Austin, Texas 78746 | | |
| | |
Mill Road Capital III, LP(3) | 839,445 | 6.68% |
| 382 Greenwich Avenue, Suite One | | |
| Greenwich, CT 06830 | | |
| | |
Franklin Mutual Advisors, LLC(4) | 768,834 | 6.12% |
| 101 John F. Kennedy Parkway | | |
| Short Hills, New Jersey 07078 | | |
| | |
AWM Investment Company, Inc.(5) | 678,008 | 5.40% |
| c/o Special Situations Funds | | |
| 527 Madison Avenue, Suite 2600 | | |
| New York, New York 10022 | | |
(1) As reported in Amendment No. 3 to Schedule 13G filed with the Securities and Exchange Commission on March 10, 2022. According to the filing, FMR LLC holds voting and/or investment power over the shares, but economic ownership is beneficially held by two investment companies. FMR LLC has sole dispositive and voting power over all of the shares reported in the table above.
We made no sales(2) As reported in Amendment No. 10 to Schedule 13G filed with the Securities and Exchange Commission on February 8, 2022. According to the filing, Dimensional Fund Advisors holds voting and/or investment power over the shares, but economic ownership is beneficially held by four investment companies. Dimensional Fund Advisors has sole dispositive power over all and sole voting power over 916,154 of unregisteredthe shares reported in the table above.
(3) As reported in Schedule 13D filed with the Securities and Exchange Commission on January 4, 2021.
(4) As reported in Amendment No. 4 to Schedule 13G filed with the Securities and Exchange Commission on February 2, 2022. According to the filing, Franklin Advisory Services, LLC is an indirect wholly owned subsidiary of Franklin Resources, Inc., and it holds investment power over all the securities and sole voting power over 732,020 of the shares reported in the table above. However, economic ownership is held by one or more open-end investment companies or other managed accounts that are investment management clients of Franklin Advisory Services, LLC or affiliated companies.
(5) As reported in Schedule 13G filed with the Securities and Exchange Commission on February 11, 2022. According to the filing, AWM Investment Company Inc. holds voting and/or investment power over the shares, but economic ownership is beneficially held by three investment companies. AWM Investment Company Inc. has sole dispositive and voting power over all of the shares reported in the table above.
Delinquent Section 16(a) Reports
Section 16(a) of the Securities Exchange Act of 1934, as amended, requires our Directors, officers and persons who beneficially own more than 10% of our Common Stock to file certain reports of beneficial ownership with the Securities and Exchange Commission. These reports show the Directors’, officers’ and greater than 10% shareholders' ownership and the changes in ownership of our common stock and other equity securities. The SEC regulations also require that a copy of all such Section 16(a) forms filed must be furnished to us by the person or entity filing the report. To the Company’s knowledge, during the fiscal year ended December 31, 2021. The following table summarizes our purchases of shares of common stock during the three months ended December 31, 2021.2021, all reports required to be filed pursuant to Section 16(a) were filed on a timely basis.
| | | | | | | | | | | | | | | | | | | | | | | | | | |
ISSUER PURCHASES OF EQUITY SECURITIES1,2 |
| | (a) | | (b) | | (c) | | (d) |
| For the Three Months Ended December 31, 2021 | | Total Number of Shares Purchased | | Average Price Paid per Share | | Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs | | Approximate Dollar Value of Shares that may yet be Purchased Under Plans or Programs3 |
| Common Stock |
| | | | | | | | (dollars in thousands) |
| October 1, 2021 to October 31, 2021 | | 101,481 | | | $11.57 | | 101,481 | | | $8,908 |
| November 1, 2021 to November 30, 2021 | | 110,243 | | | $11.53 | | 110,243 | | | $7,637 |
| December 1, 2021 to December 31, 2021 | | 92,950 | | | $10.51 | | 92,950 | | | $6,660 |
1 The table summarizes repurchases of (and remaining authority to repurchase) shares of our Common Stock.
2 The figures in the table reflect transactions according to the settlement dates. For purposes of our consolidated financial statements included in this Form 10-K, the impact of these repurchases is recorded according to the settlement dates.
3 On September 30, 2021, our Board of Directors authorized the repurchase of up to $10.0 million of our outstanding Common Stock in the open market (pursuant to Rule 10b5-1 plans or otherwise), block trades or privately negotiated transactions. This repurchase program is set to expire on September 30, 2022. The amounts in this column indicate the remaining amounts that may yet be expended to repurchase shares under these authorizations.
ITEM 6. SELECTED FINANCIAL DATA
Not applicable.
Director Independence
ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
The following discussion is intended to assist you in understanding our financial position and results of operations forBoard has determined that each of the yearsfollowing four members of the Board is “independent” within the meaning of applicable listing standards of the NYSE and under the standards, set forth in Exhibit A to our Environmental Social and Governance and Personnel Development Charter which are consistent with the NYSE listing standards: Leslie A. Beyer, Nigel J. Jenvey, David L. Bradshaw, and John Chisholm. The Board has made an affirmative determination that each of Directors named above satisfies these categorical standards. In making its determination, the Board examined relationships between Directors or their affiliates with us and our affiliates and determined that each such relationship, if any, did not impair the Director’s independence. A copy of Exhibit A to our Governance Charter is available at our website,www.ngsgi.com, under the heading “Investor Relations-Governance.”
Procedures for Reviewing Certain Transactions
On March 7, 2007, we adopted a written policy for the review, approval or ratification of related party transactions. All of our officers, Directors and employees are subject to the policy. Under this policy, the Audit Committee will review all related party transactions for potential conflict of interest situations. Generally, our policy defines a “related party transaction” as a transaction in which we are a participant and in which a related party has an interest. A “related party” is:
•any of our Directors, Officers or employees or a nominee to become a Director;
•an owner of more than 5% of our outstanding common stock;
•certain family members of any of the above persons; and
•any entity in which any of the above persons is employed or is a partner or principal or in which such person
has a 5% or greater ownership interest.
Approval Procedures
Before entering into a related party transaction, the related party or our department responsible for the potential transaction must notify the CEO or the Audit Committee of the facts and circumstances of the proposed transaction. If the amount involved is equal to or less than $100,000, the proposed transaction will be submitted to the CEO. If the amount involved exceeds $100,000, the proposed transaction will be submitted to the Audit Committee. Matters to be submitted will include:
•the related party’s relationship to us and interest in the transaction;
•the material terms of the proposed transaction;
•the benefits to us of the proposed transaction;
•the availability of other sources of comparable properties or services; and
•whether the proposed transaction is on terms comparable to terms available to an unrelated third party or to employees generally.
The CEO or the Audit Committee, as applicable, will then consider all of the relevant facts and circumstances available, including the matters described above and, if applicable, the impact on a Director’s independence. Neither the CEO nor any member of the Audit Committee is permitted to participate in any review, consideration or approval of any related party transaction if such person or any of his or her immediate family members is the related party. After review, the CEO or the Audit Committee, as applicable, may approve, modify or disapprove the proposed transaction. Only those related party transactions that are in, or are not inconsistent with, our best interests and that of our shareholders will be approved.
Ratification Procedures
If one of our officers or Directors becomes aware of a related party transaction that has not been previously approved or ratified by the CEO or the Audit Committee, if the transaction is pending or ongoing, the transaction must be submitted, based on the amount involved, to either the CEO or the Audit Committee to consider the matters described above. Based on the conclusions reached, the CEO or the Audit Committee, as applicable, will evaluate all options, including ratification, amendment or termination of the related party transaction. If the transaction is completed, the CEO or the Audit Committee will (i) evaluate the transaction, taking into account the same factors as described above, to determine if rescission of the transaction or any disciplinary action is appropriate; and (ii) will request that we evaluate our controls and procedures to determine the reason the transaction was not submitted to the CEO or the Audit Committee for prior approval, and whether any changes to the procedures are recommended.
We did not have any related party transactions in 2021 with our officers or Directors.
Item 14. Principal Accountant Fees and Services
Fees Paid to Moss Adams LLP
Our principal accountant for the fiscal year ended December 31, 2021 and 2020. You should read2020, was Moss Adams; and for the following discussion and analysis in conjunction withfiscal years ended December 31, 2019 was our audited financial statements and the related notes.former Principal Accountant, BDO USA, LLP.
Audit Fees
The following discussion contains forward-looking statements. For a description of limitations inherent in forward-looking statements, see “Special Note Regarding Forward-Looking Statements” on page ii.
Overview
We fabricate, manufacture, rent and sell natural gas compressors and related equipment. Our primary focus is on the rental of natural gas compressors. Our rental contracts generally provideaggregate fees billed for initial terms of six to 60 months, with our larger horsepower units having longer initial terms. 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 compressors. As of December 31, 2021, we had 1,254 natural gas compressors totaling 297,808 horsepower rented to 83 customers, compared to 1,274 natural gas compressors totaling 287,646 horsepower rented to 80 customers at December 31, 2020. Of the 1,254 compressors rented at December 31, 2021, 827 were rented on a month-to-month basis.
We also fabricate natural gas compressors for sale to our customers, designing compressors to meet unique specifications dictatedprofessional services rendered by well pressures, production characteristics and particular applications for which compression is sought. Fabrication of compressors involves our purchase of engines, compressors, coolers and other components, and our assembling of these components on skids for delivery to customer locations. These major components of our compressors are acquired through periodic purchase orders placed with third-party suppliers on an “as needed” basis, which presently requires a a minimum three to six month lead time with delivery dates scheduled to coincide with our estimated production schedules. Although we do not have formal continuing supply contracts with any major supplier, 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 the results of our operations and financial condition, particularly if we were unable to increase our rental rates and sales prices proportionate to any such component price increases.
We also manufacture a line of compressor frames, cylinders and parts, known as our CiP (Cylinder-in-Plane) product line. We use finished CiP component products in the fabrication of compressor units for sale or rental by us or sell the finished component products to other compressor fabricators. We also design, fabricate, sell, install and service flare stacks and related ignition and control devices for onshore and offshore incineration of gas compounds such as hydrogen sulfide, carbon dioxide, natural gas and liquefied petroleum gases. To provide customer support for our compressor and flare sales businesses, we stock varying levels of replacement parts at our Midland, Texas facility and at field service locations. We also provide an exchange and rebuild program for screw compressors and maintain an inventory of new and used compressors to facilitate this business.
We provide service and maintenance to our non-rental customers under written maintenance contracts or on an as-required basis in the absence of a service contract. Maintenance agreements typically have terms of six months to one year and require payment of a monthly fee.
The following table sets forth our revenues from each of our three operating categoriesMoss Adams for the periods presented:
| | | | | | | | | | | | | | |
| | | Year Ended December 31, |
| | | 2021 | | 2020 |
| | | (in thousands) |
| Rental | | $ | 63,624 | | | $ | 60,826 | |
| Sales | | 6,882 | | | 5,657 | |
| Service and maintenance | | 1,914 | | | 1,572 | |
| Total | | $ | 72,420 | | | $ | 68,055 | |
Our strategy for growth is focused on our compressor rental business. Margins, exclusiveaudit of depreciation and amortization, for our rental business historically run in the mid-40% to low-60% range, while margins for the compressor sales business tend to be in the mid-20% range. If our rental business grows and contributes a larger percentage of our total revenues, we expect our overall company-wide margins, exclusive of depreciation and amortization, to improve over time.
The oil and natural 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 natural gas and the corresponding changes in commodity prices. As demand and prices increase, oil and natural 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 ultimately result in greater revenues and profits for service and equipment companies.
In general, we expect our overall business activity and revenues to track the level of activity in the oil and natural gas industry, 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; an increased focus by producers on artificial lift applications, e.g., production enhancement with compression assisted gas lift; and declining reservoir pressure in maturing natural gas producing fields, especially non-conventional production. These 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 larger horsepower compressor packages. We recognized this need in recent years and have shifted our cash and fabrication resources towards designing, fabricating and renting gas compressor packages that range from 400 horsepower up to 1,500 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 provider.
We typically experience a decline in demand during periods of low crude oil and natural gas prices. During 2019, we witnessed a moderation of crude oil prices as well as drilling and completion activity levels. During the first quarter of 2020, we saw a substantial decline in the prices for oil and natural gas. Activity levels of exploration and production companies have been and will continue to be dependent not only on commodity prices, but also on their ability to generate sufficient operational cash flow to fund their activities. Generally, though, we feel that production activities (in which we are involved) will fare better than drilling activity.
For fiscal year 2022, our forecasted capital expenditures will be directly dependent upon our customers’ compression requirements and are not anticipated to exceed our internally generated cash flows. Any required capital will be for additions to our compressor rental fleet and/or addition or replacement of service vehicles. We believe that cash on hand and cash flows from operations will be sufficient to satisfy our capital and liquidity requirements through 2022. 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, might not be available to us when we need it, or might not be on acceptable terms.
Critical Accounting Policies and Practices
We have identified the policies below as critical to our business operations and the understanding of our results of operations. 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 financial statements in conformity with accounting
principles generally accepted in the United States. Actual results could differ significantly from those estimates under different assumptions and conditions. We believe that the following discussion addresses our most critical accounting policies, which are those that are most important to the portrayal of our financial condition and results of operations 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. We describe our significant accounting policies more fully in Note 2 ("Summary of Significant Accounting Policies") to our consolidated financial statements.
Our critical accounting policies are as follows:
•revenue recognition;
•estimating the allowance for doubtful accounts receivable;
•accounting for income taxes;
•accounting for long-lived assets; and
•accounting for inventory.
Revenue Recognition Policy
The Company adopted ASC 606, Revenue from Contracts with Customers ("ASC 606") on January, 1, 2018. Revenue is measured based on a consideration specified in a customer’s contract, excluding any sale incentives and taxes collected on behalf of third parties (i.e. sales and property taxes). We recognize revenue once a performance obligation has been satisfied and control over a product or service has transferred to the customer. Shipping and handling costs incurred are accounted for as fulfillment costs and are included in cost of revenues in our Consolidated Statements of Operations.
Nature of Goods and Services
Rental Revenue. The Company generates revenue from renting compressors and flare systems to our customers. These contracts may also include a fee for servicing the compressor or flare during the rental contract. Our rental contracts typically range from six to 60 months, with our larger horsepower compressors having longer minimum contract terms. Our rental revenue is recognized over time, with equal monthly payments over the term of the contract. After the terms of the contract have expired, a customer may renew their contract or continue renting on a monthly basis thereafter.
Sales Revenue. The Company generates revenue by the sale of custom/fabricated compressors, flare systems and parts, as well as, exchange/rebuilding customer owned compressors and sale of used rental equipment. The Company designs and fabricates compressors and flares based on the customer’s specifications outlined in their contract. Though the equipment being built is customized by the customer, control under these contracts does not pass to the customer until the compressor or flare package is completed and shipped, or, in accordance with a bill and hold arrangements, the customer accepts title and assumes the risk and rewards of ownership. We request some of our customers to make progressive payments as the product is being built; these payments are recorded as a contract liability on the Deferred Income line on the consolidated balance sheet until control has been transferred. These contracts also may include an assurance warranty clause to guarantee the product is free from defects in material and workmanship for a set duration of time; this is a standard industry practice and is not considered a performance obligation.
Allowance for Doubtful Accounts Receivable
We perform ongoing credit evaluations of our customers and adjust credit limits based on management's assessment of the customer's financial condition and payment history, as well as industry conditions and general economic conditions. We continuously monitor collections and payments from our customers and maintain a provision for estimated credit losses based upon our historical experience and any specific customer collection issues that we have identified. While such credit losses have historically been within our expectations and the provisions established, we cannot guarantee that we will continue to experience the same credit loss rates that we have in the past. Management believes that its allowance for doubtful accounts is adequate; however, actual write-offs may exceed the recorded allowance.
Accounting for Income Taxes
As part of 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 tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are included in our consolidated balance
sheet. 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 in a period, we must include an expense in the tax provision in the statement of income.
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. We currently have no valuation allowance and fully expect to utilize all of our deferred tax assets.
ASC 740 also prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. In order to record any financial statement benefit, we are required to determine, based on technical merits of the position, whether it is more likely than not (a likelihood of more than 50 percent) that a tax position will be sustained upon examination, including resolution of any related appeals or litigation processes. If that step is satisfied, then we must measure the tax position to determine the amount of benefit to recognize in the financial statements. The tax position is measured at the largest amount of the benefit that is greater than 50 percent likely of being realized upon ultimate settlement. Our policy regarding income tax interest and penalties is to expense those items as other expense.
Long-Lived Assets
Rental Equipment, Property and Equipment (Including Retirement of Rental Equipment)
Rental equipment and property and equipment are recorded at cost less accumulated depreciation, except for work-in-progress on new rental equipment which is recorded at cost until it’s complete and added to the fleet. Depreciation is computed using the straight-line method over the estimated useful lives of the assets. Our rental equipment has an estimated useful life between 15 and 25 years, while our property and equipment has an estimate useful lives which range from 3 to 39 years. The majority of our property and equipment, including rental equipment, is a direct cost to generating revenue.
We assess the impairment of rental equipment and property and equipment whenever events or changes in circumstances indicate that the net recorded amount 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 asset (or asset group) is being used or its condition, including a meaningful drop in fleet utilization over the prior four quarters; 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 companies, as well as significant declines in oil and natural gas prices; legislative changes prohibiting us from leasing our units or flares; or poor general economic conditions. 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.
Inventories
We value our total inventory (current and long-term) at the lower of the actual cost and net realizable value of the inventory. We regularly review inventory quantities on hand and record a provision for excess and obsolete inventory based primarily on current and anticipated customer demand and production requirements. The Company accesses anticipated customer demand based on current and upcoming capital expenditure budgets of its major customers as well as other significant companies in the industry, along with oil and natural gas price forecasts and other factors affecting the industry. For the year ended December 31, 2021, inventory allowance and write-off totaled $0.2 million. We ended 2021 with an inventory allowance balance of $64,000.
Our Performance Trends and Outlook
On January 30, 2020, the World Health Organization (“WHO”) announced a global health emergency because of a new strain of coronavirus known as COVID-19 due to the risks it imposes on the international community as the virus spreads globally. In March 2020, the WHO classified the COVID-19 outbreak as a pandemic, based on the rapid increase in exposure globally. During this time, the market began to experience a decline in oil prices in response to oil demand concerns due to the global economic impacts of COVID-19. These developments led to significant weaknesses in oil prices and ensuing reductions of exploration and production company capital and operating budgets. Oil markets largely recovered in 2021, and prices have continued to rise in the early months of 2022.
With the increases in oil prices, we expect rental demand for our large and medium horsepower units to remain strong for the remainder of 2022. In terms of sales, we expect minimal compressor sales for the year due to shifts in capital
expenditure budget concentrations throughout the industry, including those of our major customers, as many upstream producers prefer to rent compression as opposed to purchasing units as part of their capital budget allocations. Finally, we have recently experienced and expect to continue to experience supply chain disruptions. While we believe we have a strong vendor network that provides flexibility in sourcing needed materials, we have incurred longer than normal wait times for certain components as well as increases in costs. Lastly, our relationship with our major customers continues to be strong, and they have continued to pay our invoices in a timely, consistent manner. Nevertheless, if any of these circumstances change, our business could be adversely affected.
While management anticipates that the industry and economic impact of the pandemic may have a negative effect on its results of operations in 2022 and perhaps beyond, the degree to which these factors will impact our business remains uncertain. Please read Item 1A, Risk Factors, in this report.
Results of Operations
Year Ended December 31, 2021 Compared to the Year Ended December 31, 2020
The table below shows our revenues and percentage of total revenues for each of our product lines for the years ended December 31, 2021 and 2020. | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | Revenue |
| | | Year Ended December 31, |
| | | 2021 | | 2020 |
| | (dollars in thousands) |
| Rental | | $ | 63,624 | | | 87.9 | % | | $ | 60,826 | | | 89.4 | % |
| Sales | | 6,882 | | | 9.5 | % | | 5,657 | | | 8.3 | % |
| Service & Maintenance | | 1,914 | | | 2.6 | % | | 1,572 | | | 2.3 | % |
| Total | | $ | 72,420 | | | | | $ | 68,055 | | | |
Total revenue increased to $72.4 million from $68.1 million, or 6.4%,2020, and the review of the financial statements on Forms 10-Q for the year ended December 31, 2021 compared to 2020. This increase was mainly a result of increased rental revenue (4.6% increase) primarily due to a greater number of large horsepower units being rented as well as higher sales revenue (21.7% increase) primarily due to increased parts sales partially offset by decreased compressor sales.quarters in such years were approximately $242,250 and $257,575, respectively.
Rental revenue increased to $63.6 million (4.6%) from $60.8 million for the year ended December 31, 2021 compared to 2020. As of December 31, 2021, we had 2,023 natural gas compressors in our rental fleet, down from 2,224 units at year end 2020. In addition, the Company's total unit horsepower decreased by 4.7% to 418,041 at December 31, 2021 compared to 438,524 horsepower year end 2020. However, as of December 31, 2021, we had 1,254 natural gas compressors totaling 297,808 horsepower rented to 83 customers, compared to 1,274 natural gas compressors totaling 287,646 horsepower rented to 80 customers as of December 31, 2020. This increase in rented horsepower reflects the addition of 25 high horsepower compressors with 10,020 horsepower to the Company's fleet during 2021. The rental fleet had a unit utilization as of December 31, 2021 and 2020 of 62.0% and 57.3%, respectively, while our horsepower utilization for the same periods was 71.2% and 65.6%, respectively. The increase in both utilization metrics was mainly the result of the addition and increased demand for our higher horsepower units.Audit Related Fees
Sales revenue increased to $6.9 million from $5.7 million for the year ended December 31, 2021, compared to 2020. This increase in largely attributable to an increase in parts sales during 2021. Sales are subject to fluctuations in timing of industry activity related to capital projects and, as such, can vary substantially between periods.
Company management routinely reviews its inventory balances for obsolescence. Due to the slow moving nature or obsolescence of a portion of the Company's long-term inventory and inventory related to the retirement of certain rental equipment, management recorded an increase of $208,000 in the inventory allowance reserve for costs that may not be recoverable in the future. We ended 2021 with an inventory allowance balance of $64,000.
Company management routinely reviews its 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. As a result of this review, we determined 263 units should be retired from our rental fleet. Accordingly, we recorded a $3.1 million loss on retirement of rental equipment during the year ended December 31, 2021.
Operating loss increased to $12.4 million for the year ended December 31, 2021 compared to an operating loss of $3.6 million for the year ended December 31, 2020. The increase in operating loss was mainly due to 1) an $8.1 million increase in costs of rentals primarily related to a significant increase in repair and maintenance work on our rental fleet as well as increased costs related to newly set units which experience higher upfront costs than typical run rates and 2) a $2.8 million increase in loss related to the retirement of 263 units. During the year ended December 31, 2021 we had 233 newly set units during the year, of which 51 units were 400 horsepower or larger. Upon initial installation, these units require oil volumes and other materials that exceed general run rate costs. In addition, we experienced higher than normal repair and maintenance needs for our rental fleet during the year. Consistent with our recent shift to a higher horsepower fleet concentration, these large horsepower units are more cost intensive to repair than our legacy fleet. While we have routine repair and maintenance requirements, we believe a large portion of these costs are one-time in nature. These increases were partially offset by higher rental and sales revenues.
Selling, general, and administrative expenses remained relatively unchanged at $10.8 million for the year ended December 31, 2021, as compared to $10.6 million for 2020. This 2.0% increase was primarily the result of increases in health insurance costs.
Depreciation and amortization expense increased to $25.4 million from $25.2 million, or 0.8%, for the year ended December 31, 2021, compared to 2020. The increase is the result of higher capital expenditures for larger horsepower units being added to the fleet. We added 65 units (approximately 18,035 horsepower) to our fleet during the twelve-month period ended December 31, 2021. Twenty-five of those units were 400 horsepower or larger, representing approximately 56% of the horsepower added.
Income tax benefit decreased to $2.6 million from $4.8 million for the year ended December 31, 2021 compared to 2020. Our effective tax rate for both years differs from the U.S. federal statutory rate of 21%. On March 27, 2020, the Coronavirus Aid, Relief, and Economic Security Act ("CARES Act") was enacted in response to the economic impact caused the COVID-19 pandemic. The CARES Act allows federal net operating losses ("NOL") incurred in 2018, 2019, and 2020 to be carried back to each of the five preceding taxable years to generate a refund of previously paid federal income taxes. The Company generated significant NOLs during 2018 and 2019. The Company filed its NOL carryback claims for 2018 and 2019 during 2020. Accordingly, the Company recorded a federal income tax receivable of $15.0 million and an increase to its deferred income tax liability of $10.1 million on its condensed consolidated balance sheet. During the third quarter of 2020, the Company received refunds totaling $3.9 million related to its 2018 NOLs, which, along with year-end provision adjustments, reduced its federal income tax receivable to $11.5 million on its consolidated balance sheet as of December 31, 2021. In addition, the Company recorded a current income tax benefit of $4.8 million on its consolidated statement of operations for the year ended December 31, 2020. Our income tax benefit in 2021 was largely due to our net loss before income taxes of $11.8 million.
Adjusted Gross Margin Year Ended December 31, 2021 Compared to the Year Ended December 31, 2020
The table below shows our adjusted gross margin and related percentages for each of our product lines for the years ended December 31, 2021 and December 31, 2020. Adjusted gross margin is2020, there were no audit related fees.
Tax Fees
We were not billed by nor was there any tax work performed by Moss Adams during the difference between revenue and cost of revenues, exclusive of depreciation and amortization expense.
| | | | | | | | | | | | | | | | | | | | | | | |
| | Adjusted Gross Margin (1) |
| | Year Ended December 31, |
| | 2021 | | 2020 |
| (dollars in thousands) |
| Rental | $ | 26,986 | | | 42.4 | % | | $ | 32,320 | | | 53.1 | % |
| Sales | (947) | | | (13.8) | % | | (554) | | | (9.8) | % |
| Service & Maintenance | 1,016 | | | 53.1 | % | | 858 | | | 54.6 | % |
| Total | $ | 27,055 | | | 37.4 | % | | $ | 32,624 | | | 47.9 | % |
(1) For a reconciliation of adjusted gross margin to its most directly comparable financial measure calculated and presented in accordance with GAAP, please read "Non-GAAP Financial Measures" below.
Our overall adjusted gross margin percentage decreased to 37.4% for the yearyears ended December 31, 2021 compared to 47.9% for the year ended December 31, 2020, exclusive of depreciation and amortization. Our decrease in gross margins is2020.
mainly due to an increase in costs of rentals. While rental revenues increased 4.6% over 2020,All Other Fees
No other fees were billed by Moss Adams during our costs of rentals increased 28.5% primarily driven by a significant increase in repair and maintenance work on our rental fleet as well as increased costs related to newly set units which experience higher upfront costs than typical run rates. Rental revenues comprised 88% of our total revenues for the yearfiscal years ended December 31, 2021 compared to 89% of total revenues for the year ended December 31, 2020. While rental activity inherently realizes higher adjusted gross margins, the significant increase in costs of rentals beyond the increase in rental revenues resulted in a large reduction in total gross margins. Sales margin decreased to (13.8)% in 2021 from (9.8)% in 2020. While sales revenues increased 21.7%, this increase was attributable to increased parts sales, which realizes a lower gross marginand 2020, other than compressor sales. While many sales costs are variable, certain costs such as labor are less variable as a certain staff level is retained to meet demand when market forces shift. Third party servicedescribed above.
Audit Committee Pre-Approval Policies and maintenance margins decreased to 53.1% from 54.6% for the year ended December 31, 2021 compared to 2020. Service and maintenance only represents 2.6% of our revenue in 2021, providing minimal impact on our overall adjusted gross margin.Procedures
Non-GAAP Financial Measures
Our definition and use of Adjusted EBITDA
“Adjusted EBITDA” is a non-GAAP financial measure that we define as earnings (net (loss) income) before interest, taxes, depreciation and amortization, as well as an increase in inventory allowance and inventory write-offs, retirement of rental equipment and non-cash equity 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 generally accepted accounting principles. Some of these limitations are:
•Adjusted EBITDA does not reflect 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 under “Reconciliation” to see how Adjusted EBITDA reconciles to our net income, the most directly comparable GAAP financial measure.
Reconciliation
The following table reconciles our net (loss) income, the most directly comparable GAAP financial measure, to Adjusted EBITDA:
| | | | | | | | | | | | | | |
| | | Year Ended December 31, |
| | | 2021 | | 2020 |
| | | (in thousands) |
| Net income (loss) | | $ | (9,183) | | | $ | 1,808 | |
| Interest expense | | 65 | | | 14 | |
| Income tax benefit | | (2,603) | | | (4,792) | |
| Depreciation and amortization | | 25,397 | | | 25,198 | |
| | | | |
| Inventory allowance | | 208 | | | 184 | |
| Retirement of rental equipment | | 3,096 | | | 291 | |
| Stock compensation expense | | 1,738 | | | 2,195 | |
| Adjusted EBITDA | | $ | 18,718 | | | $ | 24,898 | |
| | | | |
| | | | |
| | | | |
Our definition and use of 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 expense. We believe adjusted gross margin is important because it focuses on the current operating performance of our operations and excludes the impactAs of the prior historical costsdate of the assets acquired or constructed that are utilized in those operations. Depreciation expense doesthis proxy statement, our Audit Committee has not accurately reflect the costs required to maintainestablished general pre-approval policies and replenish the operational usage of our assets and therefore may not portray the costs from current operating activity. Rather, depreciation expense reflects the systematic allocation of historical property and equipment values over the 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 expense, which is material to our results of operations. Because we use capital assets, depreciation 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.
Reconciliation
The following table calculates gross margin, the most directly comparable GAAP financial measure, and reconciles it to adjusted gross margin:
| | | | | | | | | | | | | | |
| | | Year Ended December 31, |
| | | 2021 | | 2020 |
| | | (in thousands) |
| Total revenue | | $ | 72,420 | | | $ | 68,055 | |
| Costs of revenue, exclusive of depreciation and amortization | | (45,365) | | | (35,431) | |
| Depreciation allocable to costs of revenue | | (24,753) | | | (24,578) | |
| Gross margin | | 2,302 | | | 8,046 | |
| Depreciation allocable to costs of revenue | | 24,753 | | | 24,578 | |
| Adjusted gross margin | | $ | 27,055 | | | $ | 32,624 | |
Liquidity and Capital Resources
Our working capital positions as of December 31, 2021, our Audit Committee had not established pre-approval policies and 2020 are set forth below.
| | | | | | | | | | | | | | |
| | As of December 31, |
| | | 2021 | | 2020 |
| | | (in thousands) |
| Current Assets: | | |
| Cash and cash equivalents | | $ | 22,942 | | | $ | 28,925 | |
| Trade accounts receivable, net | | 10,389 | | | 11,884 | |
| Inventory, net | | 19,329 | | | 19,926 | |
| Federal income tax receivable | | 11,538 | | | 11,538 | |
| Prepaid income taxes | | 51 | | | 66 | |
| Prepaid expenses and other | | 854 | | | 379 | |
| Total current assets | | 65,103 | | | 72,718 | |
| Current Liabilities: | | | | |
| | | | |
| | | | |
| Accounts payable | | $ | 4,795 | | | $ | 2,373 | |
| Accrued liabilities | | 14,103 | | | 6,770 | |
| Line of credit | | — | | | 417 | |
| Current operating leases | | 68 | | | 198 | |
| Deferred income | | 1,312 | | | 1,103 | |
| Total current liabilities | | 20,278 | | | 10,861 | |
| Net working capital | | $ | 44,825 | | | $ | 61,857 | |
Forprocedures for the year ended December 31, 2021, we invested approximately $25.7 million in rental equipment, property and other equipment. During the year, the Company added $24.3 million in new equipment to our rental fleet and $1.4 million in other property and equipment. Our investment in rental equipment includes any changes to work-in-progress related to our rental fleet jobs at the beginning of the year compared to the end of the year. Our rental work-in-progress increased by $1.4 million during 2021. We financed our investment in rental equipment, property and other equipment with cash flows from operations during 2021. We anticipate that our cash flows from operations as well as our borrowing capacity under our New Credit Agreement will provide ample liquidity for our planned capital expenditures during 2022 and beyond.
Cash flows
At December 31, 2021, we had cash and cash equivalents of $22.9 million compared to $28.9 million at year end 2020. Our cash flow from operations of $28.5 million was partially offset by capital expenditures of $25.7 million during 2021. In addition, we expended $7.9 million in connection with our share repurchase program. We also had working capital of $44.8
million at December 31, 2021 compared to $61.9 million at December 31, 2020. We had net cash flow from operating activities of $28.5 million during 2021 compared $32.6 million during 2020. Our cash flow from operating activities of $28.5 million was primarily the resultengagement of our rental and sales gross margins.
At December 31, 2020, we had cash and cash equivalentsprincipal accountant to render audit or non-audit services. However, in accordance with Section 10A(i) of $28.9 million, working capital of $61.9 million and total debt of $417,000, under our credit agreement which was due on March 31, 2021. We had positive net cash flow from operating activities of approximately $32.6 million during 2020.
Senior Bank Borrowings
Previous Credit Agreement
We had a senior secured revolving credit agreement (the "Previous Credit Agreement") with JP Morgan Chase Bank, N.A (the "Lender") that matured on March 31, 2021. Prior to maturation, the outstanding balance of $417,000 was repaid. The Previous Credit Agreement had an aggregate commitment of $30 million, subject to collateral availability.
New Credit Agreement
On May 11, 2021, we entered into a five-year senior secured revolving credit agreement ("New Credit Agreement") with Texas Capital Bank, National Association (the "Lender") with an initial commitment of $20 million and an accordion feature that would increase the maximum commitment to $30 million, subject to collateral availability. We also have a right to request from the Lender, on an uncommitted basis, an increase of up to $30 million on the aggregate commitment; provided, however, the aggregate commitment amount is not permitted to exceed $50 million. The maturity date of the New Credit Agreement is May 11, 2026. The obligations under the New Credit Agreement are secured by a first priority lien on a variety of our assets, including inventory and accounts receivable as well as a variable number of our leased compressor equipment.
Borrowing Base. At any time before the maturity of the New Credit Agreement, we may draw, repay and re-borrow amounts available under the borrowing base up to the maximum aggregate availability discussed above. Generally, the borrowing base equals the sum of (a) 90% of eligible accounts receivable owed to the Company by investment grade debtors, plus (b) 85% of the eligible accounts receivable owing by non-investment grade debtors, plus (c) 50% of the eligible inventory, valued at the lower of cost or market value at such time, subject to a cap of this component not to exceed $2 million, plus (d) the lesser of (i) 95% of the net book value of the compressors that the Lender has determined are eligible for the extension of credit, valued at the lower of cost or market value with depreciation not to exceed 25 years, at such time and (ii) 80% of the net liquidation value percentage of the net book value of the eligible compressors that the Lender has determined are eligible for the extension of credit, valued at the lower of cost or market value with depreciation not to exceed 25 years, at such time, plus (e) 80% of the value at cost (excluding any costs for capitalized interest or other non-cash capitalized costs) of the eligible new compressor fleet, minus (f) any required availability reserves determined by the Lender in its sole discretion. The Lender may adjust the borrowing base components if material deviations in the collateral are discovered in future audits of the collateral. As of December 31, 2021, our allowable borrowing base was $20.0 million.
Interest and Fees. Under the terms of the New Credit Agreement, we have the option of selecting the applicable variable rate for each revolving loan, or portion thereof, of either (a) the Base Rate (as defined below) plus the Applicable Margin, or (b) in the case of a Eurodollar Rate Loan, the Adjusted Eurodollar Rate plus the Applicable Margin. "Base Rate" means, for any day, a rate of interest per annum equal to the highest of (a) the prime rate for such day; (b) the sum of the federal funds rate for such day plus 0.50%; and (c) the Adjusted Eurodollar Rate for such day plus 1.00%. The Applicable Margin is determined based upon the leverage ratio as set forth in the most recent compliance certificate received by the Lender for each fiscal quarter from time to time pursuant to the New Credit Agreement. Depending on the leverage ratio, the Applicable Margin can be 0.25% to 0.75% for Base Rate Loans (as defined in the New Credit Agreement) and 1.25% to 1.75% for Eurodollar Rate Loans and for requested letters of credit. In addition, we are required to pay a monthly commitment fee on the daily average unused amount of the commitment while the New Credit Agreement is in effect at an annual rate equal to 0.25% of the unused commitment amount. Accrued interest is payable monthly on outstanding principal amounts and unused commitment fee, provided that accrued interest on Eurodollar Rate Loans is payable at the end of each interest period, but in no event less frequently than quarterly.
Covenants. The New Credit Agreement contains customary representations and warranties, as well as covenants which, among other things, condition or limit our ability to incur additional indebtedness and liens; enter into transactions with affiliates; make acquisitions in excess of certain amounts; pay dividends; redeem or repurchase capital stock or senior notes; make investments or loans; make negative pledges; consolidate, merge or effect asset sales; or change the nature of our business. In addition, we also have certain financial covenants that are applicable during certain trigger periods specified in the Credit Agreement and require us during such trigger periods to maintain a leverage ratio less than or equal to 3.00 to 1.00 as of the last day of each fiscal quarter and a fixed charge coverage ratio greater than or equal to 1.00 to 1.00 as of the last day of each fiscal quarter.
Events of Default and Acceleration. The New Credit Agreement contains customary events of default for credit facilities of this size and type, and includes, without limitation, payment defaults; defaults in performance of covenants or other
agreements contained in the Credit Agreement and the other transaction documents; inaccuracies in representations and warranties; certain defaults, termination events or similar events; certain defaults with respect to any other Company indebtedness in excess of $1.0 million; certain bankruptcy or insolvency events; the rendering of certain judgments in excess of $1.0 million; certain ERISA events; certain change in control events and the defectiveness of any liens under the secured revolving credit agreement. Obligations outstanding under the Credit Agreement may be accelerated upon the occurrence of an event of default.
As of December 31, 2021, we were in compliance with all financial covenants in our New Credit Agreement. At December 31, 2021, we had no amounts outstanding under the New Credit Agreement.
Components of Our Principal Capital Expenditures
Capital expenditures for the years ended December 31:
| | | | | | | | | | | | | | |
| Expenditure Category | | 2021 | | 2020 |
| | | (in thousands) |
| Rental equipment and property and equipment | | $ | 25,710 | | | $ | 15,257 | |
The level of our 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 our cash on hand, operating cash flow and available line of credit are adequate to fully fund our net capital expenditures requirements for 2022. 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 and our line of credit. However, our financing capacity could be negatively impacted by the COVID-19 pandemic. Please see Item 1A, Risk Factors, of this report.
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, 2021, we did not have any material off-balance sheet arrangements.
Recently Issued Accounting Pronouncements
In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform, which provides temporary optional guidance to companies impacted by the transition away from the London Interbank Offered Rate ("LIBOR"). The guidance provides certain expedients and exceptions to applying GAAP in order to lessen the potential accounting burden when contracts, hedging relationships and other transactions that reference LIBOR as a benchmark rate are modified. This guidance is effective upon issuance and expires on December 31, 2022. We are currently evaluating the impact of the LIBOR transition and this ASU 2020-04 on our consolidated financial statements.
In June 2016, the FASB issued ASU 2016-13, Financial Instruments-Credit Losses (ASC Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments to ASC Topic 326 require immediate recognition of estimated credit losses expected to occur over the remaining life of many financial assets, including trade receivables. For companies that qualify as smaller reporting companies, the amendments in this update are effective for interim and annual periods beginning after January 1, 2023. We are currently evaluating the impact of ASU 2016-13 on our consolidated financial statements and note disclosures.
Environmental Regulations
Various federal, state and local laws and regulations covering the discharge of materials into the environment, or otherwise relating to protection of human safety and health and the environment, affect our operations and costs. Compliance with these laws and regulations could cause us to incur remediation or other corrective action costs or result in the assessment of administrative, civil and criminal penalties and the issuance of injunctions delaying or prohibiting operations. In addition, we have acquired certain properties and plant facilities from third parties whose actions with respect to the management and disposal or release of hydrocarbons or other wastes were not under our control. Under environmental laws and regulations, we could be required to remove or remediate wastes disposed of or released by prior owners. In addition, we could be responsible under environmental laws and regulations for properties and plant facilities we lease, but do not own. Compliance with such laws and regulations increases our overall cost of business, but has not had a material adverse effect on our operations or financial condition. It is not anticipated, based on current laws and regulations, that we will be required in the near future to expend amounts that are material in relation to our total expenditure budget in order to comply with environmental laws and regulations but such laws and regulations are frequently changed and we are unable to predict the ultimate cost of
compliance. We also could incur costs related to the cleanup of sites to which we send equipment and for damages to natural resources or other claims related to releases of regulated substances at such sites.
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
Our consolidated financial statements and supplementary financial data are included in this Annual Report on Form 10-K beginning on page F-1.
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE
None.
ITEM 9A. CONTROLS AND PROCEDURES
Evaluation of Disclosure Controls and Procedures
An evaluation was carried out under the supervision and with the participation of our management, including our President and Chief Executive Officer and our Vice President and Chief Financial Officer, of the effectiveness of the design of our “disclosure controls and procedures” (as such term is defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934, as amended or, the “Exchange Act”) as of December 31, 2021, pursuant to Exchange Act Rule 13a-15. Based upon that evaluation, the President and Chief Executive Officer and our Vice President and Chief Financial Officer concluded that our disclosure controls and procedures as of December 31, 2021, are effective to ensure that information required to be disclosed by us in the reports filed or submitted by us under the Exchange Act, is recorded, processed, summarized, and reported withinour Audit Committee, as a whole, approves the time periods specified in the SEC's rules and forms and include controls and procedures designed to ensure that information required to be disclosed by us in such reports is accumulated and communicated to our management, includingengagement of our principal executive and financial officers as appropriate to allow timely decisions regarding required disclosures. Dueaccountant prior to the inherent limitationsaccountant rendering audit or non-audit services.
Certain rules of control systems, not all misstatements may be detected. Those inherent limitations include the realities that judgments in decision-making can be faulty and that breakdowns can occur because of simple errors or mistakes. Additionally, controls could be circumvented by the individual acts of some persons or by collusion of two or more people. Our controls and procedures can only provide reasonable, not absolute, assurance that the above objectives have been met.
Management’s Report on Internal Control Over Financial Reporting
Our management, including the President and Chief Executive Officer and our Principal Accounting Officer, is responsible for establishing and maintaining adequate internal control over financial reporting, as defined in Rule 13a-15(f) and 15d-15(f) under the Exchange Act. Our internal control system is designed to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. Our internal control over financial reporting includes those policies and procedures that:
•pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions of our assets;
•provide reasonable assurance that transactions are recorded as necessary to permit preparation of financial statements in accordance with accounting principles generally accepted in the United States of America, and that our receipt and expenditures are being made only in accordance with authorizations of management and our Board of Directors; and
•provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use or disposition of our assets that could have a material effect on the financial statements.
All internal control systems, no matter how well designed, have inherent limitations. A system of internal control may become inadequate over time because of changes in conditions or deterioration in the degree of compliance with the policies or procedures. Therefore, even those systems determined to be effective can provide only reasonable assurance with respect to financial statement preparation and presentation.
A material weakness is a deficiency, or a combination of deficiencies, in internal control over financial reporting, such that there is a reasonable possibility that a material misstatement of our annual or interim financial statements will not be prevented or detected on a timely basis.
Management, including our President and Chief Executive Officer and our Vice President and Chief Financial Officer, assessed the effectiveness of the Company’s internal control over financial reporting as of December 31, 2021. In making this assessment, management used the criteria set forth by the Committee of Sponsoring Organizations of the Treadway Commission (COSO) in Internal Control—Integrated Framework (2013). Based on this assessment, management has concluded that our internal control over financial reporting was effective as of December 31, 2021.
Changes in Internal Control Over Financial Reporting
There were no changes in our internal control over financial reporting that occurred during the year ended December 31, 2021, that has materially affected, or is reasonably likely to materially affect, our internal control over financial reporting. We will continue to review and document our disclosure controls and procedures, including our internal control over financial reporting, and may from time to time make changes aimed at enhancing their effectiveness and to ensure that our systems evolve with our business.
ITEM 9B. OTHER INFORMATION
None.
ITEM 9C. DISCLOSURES REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
None.
PART III
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 Securities and Exchange Commission within 120 days after December 31, 2021 or as such period may be extended by actionprovide that an auditor is not independent of an audit client if the Securities and Exchange Commission.
We have adoptedservices it provides to the client are not appropriately approved, subject, however, to a Code of Business Conduct and Ethics that applies to our directors, officers and employees. The Code of Business Conduct and Ethics is posted de minimis exception contained 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
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 Securities and Exchange Commission within 120 days after December 31, 2021 or as such period may be extended by action of the Securities and Exchange Commission.
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 Securities and Exchange Commission within 120 days after December 31, 2021 or as such period may be extended by action of the Securities and Exchange Commission.
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTORINDEPENDENCE
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 Securities and Exchange Commission within 120 days after December 31, 2021 or as such period may be extended by action of the Securities and Exchange Commission.
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES
The information required by this item is incorporated herein by reference to the section “Principal Accounting Fees and Services” in our definitive proxy statement which will be filed with the Securities and Exchange Commission within 120 days after December 31, 2021 or as such period may be extended by action of the Securities and Exchange Commission.
PART IV
ITEMItem 15. EXHIBITS AND CONSOLIDATED FINANCIAL STATEMENTS
The following documents are filed as part of this Annual Report on Form 10-K:
(a)(1)Exhibit and (a)(2) Consolidated Financial Statements
For a list of Consolidated Financial Statements, see “Index to Consolidated Financial Statements” incorporated herein by reference.
(a)(3) ExhibitsStatement Schedules
A list of exhibits to this Annual Report on Form 10-K is set forth below:
Exhibit No.Description | | | | | |
| Articles of Incorporation, as amended (Incorporated by reference to Exhibit 3.1 of the 10-QSB filed and dated November 10, 2004). |
| Bylaws, as amended (Incorporated by reference to Exhibit 3.11 of the Registrant's Current Report on Form 8-K filed with the Securities and Exchange Commission on June 21, 2016.) |
| Description of Securities (Incorporated by reference to the Registrant's Registration Statement on From 8-A, filed with the SEC on October 27, 2008.) |
| Form of Senior Indenture (Incorporated by reference to Exhibit 4.1 of the Registrant's Registration Statement on From S-3 (No. 333-261091) and filed on November 16, 2021) |
| Form of Subordinated Indenture (Incorporated by reference to Exhibit 4.4 of the Registrant's Registration Statement on Form S-3 (No. 333-261091) and filed on November 16, 2021 |
| 2019 Equity Incentive Plan (Incorporated by reference to Exhibit 4.1 of the Registrant’s Current Report on Form 8-K dated June 20, 2019 and filed with the Securities and Exchange Commission on June 21, 2019.) |
| 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.) |
| Amended and restated Employment Agreement dated April 27, 2015 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 April 29, 2015.) |
| 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.) |
| Credit Agreement dated as of May 11, 2021, among the Natural Gas Services Group, Inc. and NGSG Properties, LLC, a Colorado limited liability company, the banks and other financial institutions identified therein as Lenders from time to time party thereto and Texas Capital Bank, National Association, as Administrative Agent, Swing Line Lender and L/C Issuer. |
| Pledge and Security Agreement dated as of May 11, 2021, among Natural Gas Services Group, Inc., the Loan Parties (as defined therein) and Texas Capital Bank, National Association, as Administrative Agent. |
| Note dated as of May 11, 2021, by Natural Gas Services Group, Inc. in favor of Texas Capital Bank, National Association, as Lender. |
| | | | | | | | |
| Annual Incentive Bonus Plan (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 December 18, 2012.) | |
No. | Subsidiaries of the registrant | Description |
| Consent of Moss Adams LLP |
| Certification of ChiefPrincipal Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 |
| | Certification of Principal Accounting Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 |
| Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 |
| Certification of Principal Accounting Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 |
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 |
| |
| * Filed herewith. |
ITEM 16. FORM 10-K SUMMARY
None.
SIGNATURES
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
| | | | | | | | | | | | | | |
| | NATURAL GAS SERVICES GROUP, INC. |
| | | | |
March 18, 2022 | By: | | | |
| | By: | | /s/ Stephen C. Taylor |
| | Name: | | Stephen C. Taylor |
| Date: | April 29, 2022 | Title: | | Chairman of the Board, President and Chief Executive Officer |
| | | | (Principal Executive Officer) |
POWER OF ATTORNEY
KNOW ALL PERSONS BY THESE PRESENTS, that each person whose signature appears below constitutes and appoints Stephen C. Taylor and Micah C. Foster, jointly and severally, as his/her true and lawful attorneys-in-fact and agents, with full power of substitution and resubstitution, for him/her and in his/her name, place and stead, in any and all capacities, to sign any and all amendments to this Annual Report on Form 10-K and to file the same, with all exhibits thereto, and other documents in connection therewith, with the Securities and Exchange Commission, granting unto said attorneys-in-fact and agents full power and authority to do and perform each and every act and thing requisite or necessary to be done in and about the premises hereby ratifying and confirming all that said attorneys-in-fact and agents, or his substitute or substitutes, may lawfully do or cause to be done by virtue hereof.
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following persons on behalf of the registrant and in the capacities and on the dates indicated:
| | | | | | | | | | | |
Signature | Title | Date |
/s/ Stephen C. Taylor | | Chairman of the Board of Directors, Chief Executive Officer and President (Principal Executive Officer) | March 18, 2022 |
Stephen C. Taylor |
| | | |
| Date: | April 29, 2022 | By: | | /s/ Micah C. Foster | | Vice President and Chief Financial Officer (Principal Accounting Officer) | March 18, 2022 |
| | Name: | | Micah C. Foster |
| | Title: | |
/s/ Leslie A. Beyer | | Director | March 18, 2022 |
Leslie A. BeyerChief Financial Officer |
| | | | |
/s/ Nigel J. Jenvey | | Director | March 18, 2022 |
Nigel J. Jenvey |
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/s/ David L. Bradshaw | | Director | March 18, 2022 |
David L. Bradshaw |
| | | |
/s/ John W. Chisholm | | Director | March 18, 2022 |
John W. Chisholm(Principal Financial Officer) |
INDEX TO CONSOLIDATED FINANCIAL STATEMENTS
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Report of Independent Registered Public Accounting Firm (Moss Adams, LLP; Dallas, Texas; PCAOB ID 659) | |
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Consolidated Balance Sheets as of December 31, 2021 and 2020 | |
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Consolidated Statements of Operations for the Years Ended December 31, 2021 and 2020 | |
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Consolidated Statements of Stockholders' Equity for the Years Ended December 31, 2021 and 2020 | |
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Consolidated Statements of Cash Flows for the Years Ended December 31, 2021 and 2020 | |
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Notes to Consolidated Financial Statements | |
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Report of Independent Registered Public Accounting Firm
To the Shareholders and the Board of Directors of
Natural Gas Services Group, Inc.
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of Natural Gas Services Group, Inc. and subsidiary (the “Company”) as of December 31, 2021 and 2020, and the related consolidated statements of operations, stockholders’ equity, and cash flows for each of the years then ended, and the related notes (collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present fairly, in all material respects, the consolidated financial position of the Company as of December 31, 2021 and 2020, and the consolidated results of its operations and its cash flows for the year then ended, in conformity with accounting principles generally accepted in the United States of America.
Basis for Opinion
These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on the Company’s consolidated financial statements based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United States) ("PCAOB") and are required to be independent with respect to the Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement, whether due to error or fraud. The Company is not required to have, nor were we engaged to perform, an audit of its internal control over financial reporting. As part of our audit we are required to obtain an understanding of internal control over financial reporting but not for the purpose of expressing an opinion on the effectiveness of the Company's internal control over financial reporting. Accordingly, we express no such opinion.
Our audits included performing procedures to assess the risks of material misstatement of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audit provides a reasonable basis for our opinion.
Critical Audit Matter
Critical audit matters are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that (1) relate to accounts or disclosures that are material to the financial statements and (2) involved our especially challenging, subjective, or complex judgments. We determined that there are no critical audit matters.
/s/ Moss Adams LLP
Dallas, Texas
March 18, 2022
We have served as the Company's auditor since 2020.
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NATURAL GAS SERVICES GROUP, INC. CONSOLIDATED BALANCE SHEETS (in thousands) |
| December 31, |
| | 2021 | | 2020 |
| ASSETS | | | |
| Current Assets: | | | |
| Cash and cash equivalents | $ | 22,942 | | | $ | 28,925 | |
| Trade accounts receivable, net of allowance for doubtful accounts of $1,129 and $1,161, respectively | 10,389 | | | 11,884 | |
| Inventory | 19,329 | | | 19,926 | |
| Federal income tax receivable | 11,538 | | | 11,538 | |
| Prepaid income taxes | 51 | | | 66 | |
| Prepaid expenses and other | 854 | | | 379 | |
| Total current assets | 65,103 | | | 72,718 | |
| Long-Term Inventory, net of allowance for obsolescence of $64 and $221, respectively | 1,582 | | | 1,065 | |
| Rental equipment, net of accumulated depreciation of $172,563 and $175,802, respectively | 206,985 | | | 207,585 | |
| Property and equipment, net of accumulated depreciation of $15,784 and $13,916, respectively | 20,828 | | | 21,749 | |
| Right of use assets - operating leases, net of accumulated amortization $555 and $356, respectively | 285 | | | 483 | |
| Intangibles, net of accumulated amortization of $2,134 and $2,008, respectively | 1,025 | | | 1,151 | |
| Other assets | 2,698 | | | 2,050 | |
| Total assets | $ | 298,506 | | | $ | 306,801 | |
| LIABILITIES AND STOCKHOLDERS' EQUITY | | | |
| Current Liabilities: | | | |
| Accounts payable | $ | 4,795 | | | $ | 2,373 | |
| Accrued liabilities | 14,103 | | | 6,770 | |
| Line of credit | — | | | 417 | |
| Current operating leases | 68 | | | 198 | |
| Deferred income | 1,312 | | | 1,103 | |
| Total current liabilities | 20,278 | | | 10,861 | |
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| Deferred income tax liability | 39,288 | | | 41,890 | |
| Long-term operating leases | 217 | | | 285 | |
| Other long-term liabilities | 2,813 | | | 2,221 | |
| Total liabilities | 62,596 | | | 55,257 | |
| Commitments and contingencies (Note 14) | 0 | | 0 |
| Stockholders’ Equity: | | | |
| Preferred stock, 5,000 shares authorized, no shares issued or outstanding | — | | | — | |
| Common stock, 30,000 shares authorized, par value $0.01; 13,394 and 13,296 shares issued, respectively | 134 | | | 133 | |
| Additional paid-in capital | 114,017 | | | 112,615 | |
| Retained earnings | 130,103 | | | 139,286 | |
| Treasury shares, at cost, 775 shares and 38, respectively | (8,344) | | | (490) | |
| Total stockholders' equity | 235,910 | | | 251,544 | |
| Total liabilities and stockholders' equity | $ | 298,506 | | | $ | 306,801 | |
See accompanying notes to these consolidated financial statements.
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NATURAL GAS SERVICES GROUP, INC. CONSOLIDATED STATEMENTS OF OPERATIONS (in thousands, except earnings per share) |
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| | For the Years Ended December 31, |
| | 2021 | | 2020 |
| Revenue: | | | |
| Rental income | $ | 63,624 | | | $ | 60,826 | |
| Sales | 6,882 | | | 5,657 | |
| Service and maintenance income | 1,914 | | | 1,572 | |
| Total revenue | 72,420 | | | 68,055 | |
| Operating costs and expenses: | | | |
| Cost of rentals, exclusive of depreciation stated separately below | 36,638 | | | 28,506 | |
| Cost of sales, exclusive of depreciation stated separately below | 7,829 | | | 6,211 | |
| Cost of service and maintenance, exclusive of depreciation stated separately below | 898 | | | 714 | |
| Selling, general and administrative expenses | 10,762 | | | 10,550 | |
| Depreciation and amortization | 25,397 | | | 25,198 | |
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| Inventory allowance | 208 | | | 184 | |
| Retirement of rental equipment | 3,096 | | | 291 | |
| Total operating costs and expenses | 84,828 | | | 71,654 | |
| Operating loss | (12,408) | | | (3,599) | |
| Other income (expense): | | | |
| Interest expense | (65) | | | (14) | |
| Other income | 687 | | | 629 | |
| Total other income, net | 622 | | | 615 | |
| Loss before income taxes: | (11,786) | | | (2,984) | |
| (Provision for) benefit from income taxes: | | | |
| Current | 1 | | | 15,438 | |
| Deferred | 2,602 | | | (10,646) | |
| Total income tax benefit | 2,603 | | | 4,792 | |
| Net income (loss) | $ | (9,183) | | | $ | 1,808 | |
| Earnings (loss) per share: | | | |
| Basic | $ | (0.70) | | | $ | 0.14 | |
| Diluted | $ | (0.70) | | | $ | 0.14 | |
| Weighted average shares outstanding: | | | |
| Basic | 13,100 | | | 13,224 | |
| Diluted | 13,100 | | | 13,261 | |
See accompanying notes to these consolidated financial statements.
NATURAL GAS SERVICES GROUP, INC.
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
(in thousands)
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| | Preferred Stock | | Common Stock | | Additional Paid-In Capital | | Retained Earnings | | Treasury Stock | | Total Stockholders' Equity |
| Shares | | Amount | | Shares | | Amount | | | | Shares | | Amount | |
| BALANCES, December 31, 2019 | — | | | $ | — | | | 13,178 | | | $ | 132 | | | $ | 110,573 | | | $ | 137,478 | | | 38 | | | $ | (490) | | | $ | 247,693 | |
| Compensation expense on common stock options | — | | | — | | | — | | | — | | | 19 | | | — | | | — | | | — | | | 19 | |
| Issuance of restricted stock | — | | | — | | | 118 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Compensation expense on restricted common stock | — | | | — | | | — | | | 1 | | | 2,175 | | | — | | | — | | | — | | | 2,176 | |
| Taxes paid related to net shares settlement of equity awards | — | | | — | | | — | | | — | | | (152) | | | — | | | — | | | — | | | (152) | |
| Net loss | — | | | — | | | — | | | — | | | — | | | 1,808 | | | — | | | — | | | 1,808 | |
| BALANCES, December 31, 2020 | — | | | — | | | 13,296 | | | 133 | | | 112,615 | | | 139,286 | | | 38 | | | (490) | | | 251,544 | |
| Compensation expense on common stock options | — | | | — | | | — | | | — | | | 1 | | | — | | | — | | | — | | | 1 | |
| Issuance of restricted stock | — | | | — | | | 98 | | | — | | | — | | | — | | | — | | | — | | | — | |
| Compensation expense on restricted common stock | — | | | — | | | — | | | 1 | | | 1,737 | | | — | | | — | | | — | | | 1,738 | |
| Taxes paid related to net shares settlement of equity awards | — | | | — | | | — | | | — | | | (336) | | | — | | | — | | | — | | | (336) | |
| Purchase of treasury shares | — | | | — | | | — | | | — | | | — | | | — | | | 737 | | | (7,854) | | | (7,854) | |
| Net loss | — | | | — | | | — | | | — | | | — | | | (9,183) | | | — | | | — | | | (9,183) | |
| BALANCES, December 31, 2021 | — | | | $ | — | | | 13,394 | | | $ | 134 | | | $ | 114,017 | | | $ | 130,103 | | | 775 | | | $ | (8,344) | | | $ | 235,910 | |
See accompanying notes to these consolidated financial statements.
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NATURAL GAS SERVICES GROUP, INC. CONSOLIDATED STATEMENTS OF CASH FLOWS (in thousands) |
| | For the Years Ended December 31, |
| | 2021 | | 2020 |
| CASH FLOWS FROM OPERATING ACTIVITIES: | | | |
| Net (loss) income | $ | (9,183) | | | $ | 1,808 | |
| Adjustments to reconcile net (loss) income to net cash provided by operating activities: | | | |
| Depreciation and amortization | 25,397 | | | 25,198 | |
| Amortization of debt issuance costs | 31 | | | — | |
| Deferred taxes | (2,602) | | | 10,646 | |
| Gain on disposal of assets | (182) | | | (284) | |
| Retirement of rental equipment | 3,096 | | | 291 | |
| Bad debt allowance | 65 | | | 329 | |
| Inventory allowance | 208 | | | 184 | |
| Stock-based compensation | 1,738 | | | 2,195 | |
| Gain on company owned life insurance | (298) | | | (168) | |
| Changes in operating assets and liabilities: | | | |
| Trade accounts receivables | 1,430 | | | (3,107) | |
| Inventory | (1,277) | | | 1,033 | |
| Prepaid income taxes and prepaid expenses | (460) | | | (11,346) | |
| Accounts payable and accrued liabilities | 9,756 | | | 4,880 | |
| Deferred income | 208 | | | 463 | |
| Other | 600 | | | 527 | |
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| NET CASH PROVIDED BY OPERATING ACTIVITIES | 28,527 | | | 32,649 | |
| CASH FLOWS FROM INVESTING ACTIVITIES: | | | |
| Purchase of rental equipment, property and other equipment | (25,710) | | | (15,257) | |
| Purchase of company owned life insurance | (150) | | | (296) | |
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| Proceeds from sale of property and equipment | 195 | | | 394 | |
| NET CASH USED IN INVESTING ACTIVITIES | (25,665) | | | (15,159) | |
| CASH FLOWS FROM FINANCING ACTIVITIES: | | | |
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| Proceeds of other long-term liabilities | (1) | | | (5) | |
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| Repayments of line of credit, net | (417) | | | — | |
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| Payments of debt issuance costs | (237) | | | — | |
| Purchase of treasury shares | (7,854) | | | — | |
| Taxes paid related to net share settlement of equity awards | (336) | | | (152) | |
| NET CASH USED IN FINANCING ACTIVITIES | (8,845) | | | (157) | |
| NET CHANGE IN CASH AND CASH EQUIVALENTS | (5,983) | | | 17,333 | |
| CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD | 28,925 | | | 11,592 | |
| CASH AND CASH EQUIVALENTS AT END OF PERIOD | $ | 22,942 | | | $ | 28,925 | |
| SUPPLEMENTAL DISCLOSURE OF CASH FLOW INFORMATION: | | | |
| Interest paid | $ | 30 | | | $ | 14 | |
| Income taxes paid | — | | | 105 | |
| NON-CASH TRANSACTIONS | | | |
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| | | |
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| Right of use asset acquired through an operating lease | — | | | 77 | |
See accompanying notes to these consolidated financial statements.
NATURAL GAS SERVICES GROUP INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
1. Description of Business
Natural Gas Services Group, Inc. (the "Company", “NGS”, "Natural Gas Services Group", "we" or "our") (a Colorado corporation), is a leading provider of natural gas compression equipment and services to the energy industry. The Company manufactures, fabricates, rents, sells and maintains natural gas compressors and flare systems for oil and natural gas production and plant facilities. NGS is headquartered in Midland, Texas, with fabrication facilities located in Tulsa, Oklahoma and Midland, Texas, and service facilities located in major oil and natural gas producing basins in the U.S. The Company was formed on December 17, 1998.
2. Summary of Significant Accounting Policies
Principles of Consolidation
The accompanying consolidated financial statements include the accounts of the Company, its subsidiary, NGSG Properties, LLC and the rabbi trust associated with the Company’s deferred compensation plan, see Note 10. All significant intercompany accounts and transactions for the periods presented have been eliminated in consolidation.
Use of Estimates
The preparation of our consolidated financial statements in conformity with generally accepted accounting principles in the United States of America requires our management to make estimates and assumptions that affect the amounts reported in these consolidated financial statements and accompanying notes. Actual results could differ from those estimates. Significant estimates include fixed asset lives, bad debt allowance and the allowance for inventory obsolescence. Additionally, NGS conducts a yearly review of impairment of long-lived assets. Throughout the review, determining factors are based on estimates that can significantly impact the carrying value of these assets. It is at least reasonably possible these estimates could be revised in the near term and the revisions could be material.
Cash Equivalents and Financial Instruments
For purposes of reporting cash flows, we consider all short-term investments with an original maturity of three months or less to be cash equivalents. We invest our cash primarily in deposits and money market funds with commercial banks. At times, cash balances at banks and financial institutions may exceed federally insured amounts. We believe that the risk to our cash balance is minimal because we have chosen a large regional bank with strong long-term ratings of Baa3/BBB-.
Accounts Receivable
Our trade receivables consist of customer obligations for the sale of compressors and flare systems due under normal trade terms, and operating leases for the use of our natural gas compressors. The receivables are not collateralized except as provided for under lease agreements. However, we typically require deposits of as much as 50% or use of progress payments for large custom sales contracts. We perform ongoing credit evaluations of our customers and adjust credit limits based on management's assessment of the customer's financial condition and payment history, as well as industry conditions and general economic conditions. We continuously monitor collections and payments from our customers, and maintain a provision for estimated credit losses based upon our historical experience and any specific customer collection issues that we have identified. While such credit losses have historically been within our expectations and the provisions established, we cannot guarantee that we will continue to experience the same credit loss rates that we have in the past. One customer accounted for 46% and 35% of our accounts receivable as of December 31, 2021 and 2020, respectively. A significant change in the liquidity or financial position of this customer could have a material adverse impact on the collectability of our accounts receivable and our future operating results. The allowance for doubtful accounts was $1.1 million and $1.2 million at December 31, 2021 and 2020, respectively. Management believes that the allowance is adequate; however, actual write-offs may exceed the recorded allowance.
A summary of our allowance for doubtful accounts is as follows:
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| Year Ended December 31, |
| ($ in thousands) | 2021 | | 2020 |
| Beginning balance | $ | 1,161 | | | $ | 918 | |
| Accruals | 65 | | | 329 | |
| Recoveries | 8 | | | — | |
| Write-offs | (105) | | | (86) | |
| Ending balance | $ | 1,129 | | | $ | 1,161 | |
Revenue Recognition Policy
Revenue is measured based on a consideration specified in a customer’s contract, excluding any sale incentives and taxes collected on behalf of third parties (i.e. sales and property taxes). Revenue is recognized when a customer obtains control of promised goods or services in an amount that reflects the consideration that we expect to receive for those goods or services. To recognize revenue, we (i) identify the contract(s) with a customer; (ii) identify the performance obligations in the contract; (iii) determine the transaction price; (iv) allocate the transaction price to the performance obligations in the contract; and (v) recognize revenue when, or as, we satisfy the performance obligation(s). Shipping and handling costs incurred are accounted for as fulfillment costs and are included in cost of revenues in our Consolidated Statements of Operations.
Nature of Goods and Services
The following is a description of principal activities from which the Company generates its revenue:
Rental Revenue. The Company generates revenue from renting compressors and flare systems to our customers. These contracts, which all qualify as operating leases under ASC Topic 842, Leases (ASC 842), may also include a fee for servicing the compressor or flare during the rental contract. Our rental contracts typically range from six to 24 months, with our larger horsepower compressors having contract terms of up to 60 months. Our revenue is recognized over time, with equal monthly payments over the term of the contract. After the terms of the contract have expired, a customer may renew their contract or continue renting on a monthly basis thereafter. In accordance ASC 842 – Leases, we have applied the practical expedient ASC 842-10-15-42A, which allows the Company to combine lease and non-lease components.
Sales Revenue. The Company generates revenue by the sale of custom/fabricated compressors, flare systems and parts, as well as, exchange/rebuilding customer owned compressors and sale of used rental equipment.
Custom/fabricated compressors and flare systems - The Company designs and fabricates compressors and flares based on the customer’s specifications outlined in their contract. Though the equipment being built is customized by the customer, control under these contracts does not pass to the customer until the compressor or flare package is completed and shipped, or in accordance with a bill and hold arrangements the customer accepts title and assumes the risk and rewards of ownership. We request some of our customers to make progressive payments as the product is being built; these payments are recorded as a contract liability on the Deferred Income line on the consolidated balance sheet until control has been transferred. These contracts also may include an assurance warranty clause to guarantee the product is free from defects in material and workmanship for a set duration of time; this is a standard industry practice and is not considered a performance obligation.
From time to time, upon the customer’s written request, we recognize revenue when manufacturing is complete and the equipment is ready for shipment. At the customer’s request, we will bill the customer upon completing all performance obligations, but before shipment. The customer will formally request we ship the equipment per their direction from our manufacturing facility at a later specified date and that we segregate the equipment from our finished goods, such that they are not available to fill other orders. Per the customer’s agreement change of control is passed to the customer once the equipment is complete and ready for shipment. We have operated using bill and hold agreements with certain customers for many years, with consistent satisfactory results for both the customer and us. The credit terms on these agreements are consistent with the credit terms on all other sales. All control is shouldered by the customer and there are no exceptions to the customer’s commitment to accept and pay for the manufactured equipment. Revenues recognized related to bill and hold arrangements for the years ended December 31, 2021 and 2020 was approximately $20,000 and $852,000, respectively.
Parts - Revenue is recognized after the customer obtains control of the parts. Control is passed either by the customer taking physical possession or the parts being shipped. The amount of revenue recognized is not adjusted for expected returns, as our historical part returns have been de minimis.
Exchange or rebuilding customer owned compressors - Based on the contract, the Company will either exchange a new/rebuilt compressor for the customer’s malfunctioning compressor or rebuild the customer’s compressor. Revenue is recognized after control of the replacement compressor has transferred to the customer based on the terms of the contract, i.e., by physical delivery, delivery and installment, or shipment of the compressor.
Used compressors or flares - From time to time, a customer may request to purchase a used compressor or flare out of our rental fleet. Revenue from the sale of rental equipment is recognized when the control has passed to the customer based on the terms of the contract, i.e. when the customer has taken physical possession or the equipment has been shipped.
Service and Maintenance Revenue. The Company provides routine or call-out services on customer owned equipment. Revenue is recognized after services in the contract are rendered.
Payment terms for sales revenue and service and maintenance revenue discussed above are generally 30 to 60 days although terms for specific customers can vary. Also, the transaction prices are not subject to variable consideration constraints.
Disaggregation of Revenue
The following table shows the Company's revenue disaggregated by product or service type for the years ended:
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| Year Ended December 31, |
| 2021 | | 2020 |
| (in thousands) |
| Compressors - sales | $ | 1,891 | | | $ | 2,211 | |
| Flares - sales | 365 | | | 489 | |
| Other (Parts/Rebuilds) - sales | 4,626 | | | 2,957 | |
| Service and maintenance | 1,914 | | | 1,572 | |
| Total revenue from contracts with customers | 8,796 | | | 7,229 | |
| Add: ASC 842 rental revenue | 63,624 | | | 60,826 | |
| Total revenue | $ | 72,420 | | | $ | 68,055 | |
| | | |
Contract Balances
As of December 31, 2021 and 2020, we had the following receivables and deferred income from contracts with customers:
| | | | | | | | | | | |
| December 31, |
| 2021 | | 2020 |
| (in thousands) |
| Accounts Receivable | | | |
| Accounts receivable - contracts with customers | $ | 3,354 | | | $ | 3,243 | |
| Accounts receivable - ASC 842 | 8,164 | | | 9,802 | |
| Total Accounts Receivable | 11,518 | | | 13,045 | |
| Less: Allowance for doubtful accounts | (1,129) | | | (1,161) | |
| Total Accounts Receivable, net | $ | 10,389 | | | $ | 11,884 | |
| | | |
| Deferred income | $ | 1,312 | | | $ | 1,103 | |
The Company recognized $1.1 million in revenue for the year ended December 31, 2021 that was included in deferred income at the beginning of 2021. For the period ended December 31, 2020, the Company recognized revenue of $73,000 from amounts related to sales that were included in deferred income at the beginning of 2020.
The increases (decreases) of accounts receivable and deferred income were primarily due to normal timing differences between our performance and the customers’ payments.
Transaction Price Allocated to the Remaining Performance Obligations
As of December 31, 2021, the Company did not have revenue related to unsatisfied performance obligations.
Contract Costs
The Company recognizes the incremental costs of obtaining contracts as an expense when incurred if the amortization period of the assets that the Company otherwise would have recognized is one year or less. These costs are included in selling, general and administrative expense on our Consolidated Statements of Operations.
Leases
Accounting Standards Codification ("ASC") 842 requires all leases to be reported on the balance sheet as right-of-use ("ROU") assets and lease obligations. We determine if an arrangement is a lease at inception and determine lease classification and recognize ROU assets and liabilities on the lease commencement date based on the present value of lease payments over the lease term. As the discount rate implicit in the lease is rarely readily determinable, we estimate our incremental borrowing rate using information available at the commencement date in determining the present value of the lease payments. We, as a lessee, apply the practical expedient to not separate non-lease components from lease components, therefore, accounting for each separate lease component and its associated non-lease component, as a single lease component. For each lease that 1) contains the same timing and pattern of transfer for lease and non-lease components and 2) if the lease component, if accounted for separately, would be classified as an operating lease, the Company has elected to not separate non-lease components from lease components.
Major Customers and Concentration of Credit Risk
Sales and rental income from Occidental Permian, LTD. ("Oxy") in 2021 and 2020 amounted to 40% and 30% of revenue, respectively. No other single customer accounted for more than 10% of our revenues in 2021 and 2020. Oxy's accounts receivable balances amounted to 46% and 35% of our accounts receivable as of December 31, 2021 and 2020, respectively. No other customers amounted to more than 10% of our accounts receivable as of December 31, 2021 and 2020.
Inventory
Inventory (current and long-term) is valued at the lower of cost and net realizable value. The cost of inventories is determined by the weighted average method. We regularly review inventory quantities on hand and record a provision for excess and obsolete inventory based primarily on current and anticipated customer demand and production requirements. The Company assesses anticipated customer demand based on current and upcoming capital expenditure budgets of its major customers as well as other significant companies in the industry, along with oil and natural gas price forecasts and other factors affecting the industry. In addition, our long-term inventory consists of raw materials and replacement parts that remain viable but which the Company does not expect to sell within the next year.
Rental Equipment and Property and Equipment
Rental equipment and property and equipment are recorded at cost less accumulated depreciation, except for work-in-progress on new rental equipment which is recorded at cost until it’s complete and added to the fleet. Depreciation is computed using the straight-line method over the estimated useful lives of the assets. Our rental equipment has an estimated useful life between 15 and 25 years, while our property and equipment has an estimate useful lives which range from 3 to 39 years. The majority of our property and equipment, including rental equipment, is a direct cost to generating revenue.
We assess the impairment of rental equipment and property and equipment whenever events or changes in circumstances indicate that the net recorded amount 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 asset (or asset group) is being used or its condition, including a meaningful drop in fleet utilization over the prior four quarters; 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 companies, as well as significant declines in oil and natural gas prices; legislative changes prohibiting us from leasing our units or flares; or poor general economic conditions. 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.
Sales of equipment out of the rental fleet are included with sales revenue and cost of sales, while retirements of units are shown a separate operating expense. Gains and losses resulting from sales and dispositions of other property and equipment are included with other income. Maintenance and repairs are charged to cost of rentals as incurred.
Intangibles
At December 31, 2021 and 2020, NGS had intangible assets, which relate to developed technology and a trade name. Developed technology is amortized on a straight-line basis with a useful life of 20 years, with a weighted average remaining life of approximately four years as of December 31, 2021. NGS has an intangible asset related to the trade name of SCS which was acquired in our acquisition of Screw Compression Systems in January 2005. This asset is not being amortized as it has been deemed to have an indefinite life.
Our policy is to review intangibles that are being amortized for impairment when indicators of impairment are present. In addition, it is our policy to review indefinite-lived intangible assets for impairment annually or when indicators of impairment are present. We review intangibles through an assessment of the estimated future cash flows related to such assets. In the event that assets are found to be carried at amounts in excess of estimated undiscounted future cash flows, then the assets will be adjusted for impairment to a level commensurate with a discounted cash flow analysis of the underlying assets.
Warranty
When warranted, we accrue amounts for estimated warranty claims based upon current and historical product warranty costs and any other related information known. There was no warranty reserve as of December 31, 2021 and 2020.
Income Taxes
Deferred tax assets and liabilities are recognized for the future tax consequences attributable to temporary differences between the financial statement carrying amounts of assets and liabilities and their respective tax bases, and operating losses and tax credit carry-forwards. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the years in which those temporary differences are expected to be recovered or settled. We 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 establish a valuation allowance. To the extent we establish a valuation allowance or increase this allowance in a period, we include an expense in the tax provision in the statement of income.
ASC Topic 740 prescribes a recognition threshold and measurement attribute for the financial statement recognition and measurement of a tax position taken or expected to be taken in a tax return. In order to record any financial statement benefit, we are required to determine, based on technical merits of the position, whether it is more likely than not (a likelihood of more than 50 percent) that a tax position will be sustained upon examination, including resolution of any related appeals or litigation processes. If that step is satisfied, then we must measure the tax position to determine the amount of benefit to recognize in the financial statements. The tax position is measured at the largest amount of the benefit that is greater than 50 percent likely of being realized upon ultimate settlement.
Our policy regarding income tax interest and penalties is to expense those items as other expense.
We account for uncertain tax positions in accordance with guidance in FASB ASC 740, which prescribes the minimum recognition threshold a tax position taken or expected to be taken in a tax return is required to meet before being recognized in the financial statements. We have no uncertain tax positions as of December 31, 2021.
Fair Value Measurement
Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date under current market conditions. ASC Topic 820 established a fair value hierarchy, which requires an entity to maximize the use of observable inputs when measuring fair value. These inputs are categorized as follows:
Level 1- quoted prices in an active market for identical assets or liabilities;
Level 2- quoted prices in an active market for similar assets or liabilities, inputs other than quoted prices that are observable for similar assets or liabilities, inputs derived principally from or corroborated by observable market data by correlation or other means; and
Level 3- valuation methodology with unobservable inputs that are significant to the fair value measurement.
Management believes that the fair value of our cash and cash equivalents, trade receivables, accounts payable and line of credit at December 31, 2021 and 2020 approximate their carrying values due to the short-term nature of the instruments or the use of prevailing market interest rates.
Segments and Related Information
ASC 280-10-50, “Operating Segments”, define the characteristics of an operating segment as a) being engaged in business activity from which it may earn revenue and incur expenses, b) being reviewed by the company's chief operating decision maker (CODM) for decisions about resources to be allocated and assess its performance and c) having discrete financial information. Although we indeed look at our products to analyze the nature of our revenue, other financial information, such as certain costs and expenses, net income and EBITDA are not captured or analyzed by these categories. Our CODM does not make resource allocation decisions or access the performance of the business based on these categories, but rather in the aggregate. Based on this, management believes that it operates in 1 business segment.
We are engaged in the business of designing and manufacturing compressors and flares. Our compressors and flares are sold and rented to our customers. In addition, we provide service and maintenance on compressors in our fleet and to third parties. These business activities are similar in all geographic areas. Our manufacturing process is essentially the same for the entire Company and is performed in house at our facilities in Midland, Texas and Tulsa, Oklahoma. Our customers primarily consist of entities in the business of producing natural gas. The maintenance and service of our products is consistent across the entire Company and is performed via an internal fleet of vehicles. The regulatory environment is similar in every jurisdiction in that the most impacting regulations and practices are the result of federal energy policy.
Recently Issued Accounting Pronouncements
In March 2020, the FASB issued ASU 2020-04, Reference Rate Reform, which provides temporary optional guidance to companies impacted by the transition away from the London Interbank Offered Rate ("LIBOR"). The guidance provides certain expedients and exceptions to applying GAAP in order to lessen the potential accounting burden when contracts, hedging relationships and other transactions that reference LIBOR as a benchmark rate are modified. This guidance is effective upon issuance and expires on December 31, 2022. We are currently evaluating the impact of the LIBOR transition and this ASU 2020-04 on our consolidated financial statements.
In June 2016, the FASB issued ASU 2016-13, Financial Instruments-Credit Losses (ASC Topic 326): Measurement of Credit Losses on Financial Instruments. The amendments to ASC Topic 326 require immediate recognition of estimated credit losses expected to occur over the remaining life of many financial assets, including trade receivables. For companies that qualify as smaller reporting companies, the amendments in this update are effective for interim and annual periods beginning after January 1, 2023. We are currently evaluating the impact of ASU 2016-13 on our consolidated financial statements and note disclosures.
3. Inventory
Our inventory, net of allowance for obsolescence of $64,000 and $221,000 at December 31, 2021 and 2020, respectively, consisted of the following:
| | | | | | | | | | | |
| December 31, |
| | 2021 | | 2020 |
| (in thousands) |
| Raw materials - current | $ | 17,528 | | | $ | 18,026 | |
| Work-in-process | 1,801 | | | 1,900 | |
| | | |
| Inventory - current | 19,329 | | | 19,926 | |
| Raw materials - long term (net of allowances of $64 and $221, respectively) | 1,582 | | | 1,065 | |
| Inventory - total | $ | 20,911 | | | $ | 20,991 | |
Our long-term inventory consists of raw materials that remain viable but which the Company does not expect to sell within the next year.
Inventory Allowance
We routinely review our inventory allowance balance to account for slow moving or obsolete inventory costs that may not be recoverable in the future.
A summary of our inventory allowance is as follows:
| | | | | | | | | | | |
| Year Ended December 31, |
| 2021 | | 2020 |
| (in thousands) |
| Beginning balance | $ | 221 | | | $ | 24 | |
| Accruals | 208 | | | 251 | |
| Write-offs | (365) | | | (54) | |
| Ending balance | $ | 64 | | | $ | 221 | |
4. Rental Equipment, Property and Equipment
Rental Equipment
Our rental equipment and associated accumulated depreciation as of December 31, 2021 and 2020, respectively, consisted of the following:
| | | | | | | | | | | |
| December 31, |
| 2021 | | 2020 |
| (in thousands) |
| Compressor units | $ | 374,336 | | | $ | 379,623 | |
| Work-in-progress | 5,212 | | | 3,764 | |
| Rental equipment | 379,548 | | | 383,387 | |
| Accumulated depreciation | (172,563) | | | (175,802) | |
| Rental equipment, net of accumulated depreciation | $ | 206,985 | | | $ | 207,585 | |
Our rental equipment has an estimated useful life between 15 and 25 years. Depreciation expense for rental equipment was $22.9 million and $22.7 million for the year ended December 31, 2021 and 2020, respectively. During the year ended December 31, 2021 we added 65 units to our rental fleet, 35 of which were repurchased from a significant customer who had previously purchased these units from us under a bill and hold arrangement in prior years, but had not yet placed the units in service.
Retirement of Rental Equipment
Company management routinely reviews its inventory of rental equipment for retirement or obsolescence. During 2021, management reviewed the rental fleet to determine which units were not of the type, configuration, make or model that our customers are demanding or that were not cost efficient to refurbish, maintain and/or operate. As a result of this review, we determined 263 units should be retired from our rental fleet. Accordingly, we recorded a $3.1 million loss on retirement of rental equipment during the year ended December 31, 2021.
During our review of our rental compressor units in 2020, we determined 216 units should be retired from our rental fleet. We recorded a $0.3 million loss on retirement of rental equipment.
Property and Equipment
Property and equipment consists of the following at December 31, 2021 and 2020:
| | | | | | | | | | | | | | | | | |
| | | December 31, |
| | Useful Lives (Years) | | 2021 | | 2020 |
| | | ($ in thousands) |
| Land | — | | $ | 1,680 | | | $ | 1,680 | |
| Building | 39 | | 18,977 | | | 18,977 | |
| Leasehold improvements | 39 | | 1,197 | | | 1,168 | |
| Office equipment and furniture | 5 | | 2,016 | | | 2,016 | |
| Software | 5 | | 573 | | | 573 | |
| Machinery and equipment | 7 | | 3,874 | | | 3,653 | |
| Vehicles | 3 | | 8,295 | | | 7,598 | |
| Total | | | 36,612 | | | 35,665 | |
| Less accumulated depreciation | | | (15,784) | | | (13,916) | |
| Total | | | $ | 20,828 | | | $ | 21,749 | |
Depreciation expense for property and equipment was $2.4 million and $2.3 million for the year ended December 31, 2021 and 2020, respectively.
Depreciation Expense by Product Line
The following table depicts annual depreciation expense associated with each product line as well as our corporate activities at December 31, 2021 and 2020:
| | | | | | | | | | | |
| December 31, |
| | 2021 | | 2020 |
| (in thousands) |
| Rentals | $ | 24,423 | | | $ | 24,255 | |
| Sales | 281 | | | 281 | |
| Service & Maintenance | 49 | | | 42 | |
| Corporate | 476 | | | 495 | |
| Total | $ | 25,229 | | | $ | 25,073 | |
5. Rental Activity
We rent natural gas compressor packages to entities in the petroleum industry. These rental arrangements are classified as operating leases and generally have original terms of six months to sixty months and continue on a month-to-month basis thereafter.
Future minimum rent payments for arrangements not on a month-to-month basis at December 31, 2021 are as follows: | | | | | | | | |
| Years Ending December 31, | | (in thousands) |
| 2022 | | $29,583 |
| 2023 | | 18,684 |
| 2024 | | 18,277 |
| 2025 | | 8,739 |
| 2026 | | 2,614 |
| Thereafter | | 462 |
| Total | | $78,359 |
6. Leases
The Company determines if an arrangement is a lease at inception by assessing whether it conveys the right to control the use of an identified asset for a period of time in exchange for consideration. The Company’s leases are primarily related to property leases for its field offices. The Company's leases have remaining lease terms of one to eight years. Renewal and termination options are included in the lease term when it is reasonably certain that the Company will exercise the option.
The Company's lease agreements do not contain any contingent rental payments, material residual guarantees or material restrictive covenants.
Right of use assets and lease liabilities are recognized at the lease commencement date based on the present value of lease payments over the lease term. As substantially all of the Company's leases do not provide an implicit rate, the Company uses its incremental borrowing rate, which is based on a fully collateralized loan over the lease term, to determine the present value of lease payments. The Company has no finance leases. The following table reflects the amounts related to leases that are recorded on our consolidated balance sheets as of December 31, 2021 and 2020:
| | | | | | | | | | | | | | |
| Classification on Consolidated | December 31, |
| Balance Sheets | 2021 | | 2020 |
| | ($ in thousands) |
| Operating lease assets | Right of use assets-operating leases | $ | 285 | | | $ | 483 | |
| | | | |
| Current lease liabilities | Current operating leases | $ | 68 | | | $ | 198 | |
| Noncurrent lease liabilities | Long-term operating leases | 217 | | | 285 | |
| Total lease liabilities | | $ | 285 | | | $ | 483 | |
| | | | |
| Weighted average remaining lease term in years | | 6.6 | | 1.5 |
| Implicit Rate | | 3.4 | % | | 3.2 | % |
Operating lease costs are recognized on a straight-line basis over the lease term. Total operating lease costs for the year ended December 31, 2021 was approximately $556,000.
| | | | | | | | | | | |
| December 31, |
| 2021 | | 2020 |
| (in thousands) |
| Cash paid for amounts included in the measurement of lease liabilities | | | |
Operating lease cost (1) (2) | $ | 556 | | | $ | 550 | |
(1) Lease costs are classified on the Consolidated Statements of Operations in cost of sales, cost of compressors and selling, general and administrative expenses.
(2) Includes costs of $346,000 for leases with terms of 12 months or less and $210,000 for leases with terms greater than 12 months for the year ended December 31, 2021. Includes costs of $333,000 for leases with terms of 12 months or less and $217,000 for leases with terms greater than 12 months for the year ended December 31, 2020.
The following table shows the future maturities of lease liabilities:
| | | | | | | | |
| Years Ending December 31, | | Lease Liabilities |
| | (in thousands) |
| 2022 | | $ | 77 | |
| 2023 | | 38 | |
| 2024 | | 38 | |
| 2025 | | 38 | |
| 2026 | | 38 | |
| Thereafter | | 92 | |
| Total lease payments | | 321 | |
| Less: Imputed interest | | (36) | |
| Total | | $ | 285 | |
Rent expense under such leases was $210,000 and $217,000 for the years ended December 31, 2021 and 2020, respectively.
7. Intangibles
At December 31, 2021 and 2020, the Company had intangible assets, which relate to developed technology and a trade name. Amortization expense recognized in each of the years ending December 31, 2021 and 2020 was $125,000. Estimated amortization expense for the years 2022-2024 is approximately $125,000 per year. The Company has an intangible asset with a gross carrying value of $654,000 at December 31, 2021 related to the trade name of SCS which was acquired in our acquisition of Screw Compression Systems in January 2005. This asset is not being amortized as it has been deemed to have an indefinite life.
The following table represents the identified intangible assets by major asset class (in thousands):
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
| | | | | December 31, 2021 | | December 31, 2020 |
| | Useful Life (years) | | Gross Carrying Value | | Accumulated Amortization | | Net Book Value | | Gross Carrying Value | | Accumulated Amortization | | Net Book Value |
| | | | | | | | | | | | | | |
| | | | | | | | | | | | | | |
| | | | | | | | | | | | | | |
| Developed Technology | | 20 | | $ | 2,505 | | | $ | 2,134 | | | $ | 371 | | | $ | 2,505 | | | $ | 2,008 | | | $ | 497 | |
| Trade Name | | Indefinite | | 654 | | | — | | | 654 | | | 654 | | | — | | | 654 | |
| Total | | | | $ | 3,159 | | | $ | 2,134 | | | $ | 1,025 | | | $ | 3,159 | | | $ | 2,008 | | | $ | 1,151 | |
Our policy is to review intangibles that are being amortized for impairment when indicators of impairment are present. In addition, it is our policy to review indefinite-lived intangible assets for impairment annually or when indicators of impairment are present. We review intangibles through an assessment of the estimated future cash flows related to such assets. In the event that assets are found to be carried at amounts in excess of estimated undiscounted future cash flows, then the assets will be adjusted for impairment to a level commensurate with a discounted cash flow analysis of the underlying assets. Based upon our analysis, we experienced no impairment of intangible assets during the years ended December 31, 2021 or 2020.
8. Credit Facility
Previous Credit Agreement
We had a senior secured revolving credit agreement (the "Previous Credit Agreement") with JP Morgan Chase Bank, N.A (the "Lender") that matured on March 31, 2021. Prior to maturation, the outstanding balance of $417,000 was repaid. The Previous Credit Agreement had an aggregate commitment of $30 million, subject to collateral availability.
New Credit Agreement
On May 11, 2021, we entered into a five year senior secured revolving credit agreement ("New Credit Agreement") with Texas Capital Bank, National Association (the "Lender") with an initial commitment of $20 million and an accordion feature that would increase the maximum commitment to $30 million, subject to collateral availability. We also have a right to request from the Lender, on an uncommitted basis, an increase of up to $30 million on the aggregate commitment; provided, however, the aggregate commitment amount is not permitted to exceed $50 million. The maturity date of the New Credit Agreement is May 11, 2026. The obligations under the New Credit Agreement are secured by a first priority lien on a variety of our assets, including inventory and accounts receivable as well as a variable number of our leased compressor equipment.
Borrowing Base. At any time before the maturity of the New Credit Agreement, we may draw, repay and re-borrow amounts available under the borrowing base up to the maximum aggregate availability discussed above. Generally, the borrowing base equals the sum of (a) 90% of eligible accounts receivable owed to the Company by investment grade debtors, plus (b) 85% of the eligible accounts receivable owing by non-investment grade debtors, plus (c) 50% of the eligible inventory, valued at the lower of cost or market value at such time, subject to a cap of this component not to exceed $2 million, plus (d) the lesser of (i) 95% of the net book value of the compressors that the Lender has determined are eligible for the extension of credit, valued at the lower of cost or market value with depreciation not to exceed 25 years, at such time and (ii) 80% of the net liquidation value percentage of the net book value of the eligible compressors that the Lender has determined are eligible for the extension of credit, valued at the lower of cost or market value with depreciation not to exceed 25 years, at such time, plus (e) 80% of the value at cost (excluding any costs for capitalized interest or other non-cash capitalized costs) of the eligible new compressor fleet, minus (f) any required availability reserves determined by the Lender in its sole discretion. The Lender may adjust the borrowing base components if material deviations in the collateral are discovered in future audits of the collateral. As of December 31, 2021, our allowable borrowing base was $20.0 million.
Interest and Fees. Under the terms of the New Credit Agreement, we have the option of selecting the applicable variable rate for each revolving loan, or portion thereof, of either (a) the Base Rate (as defined below) plus the Applicable Margin, or (b) in the case of a Eurodollar Rate Loan, the Adjusted Eurodollar Rate plus the Applicable Margin. "Base Rate" means, for any day, a rate of interest per annum equal to the highest of (a) the prime rate for such day; (b) the sum of the federal funds rate for such day plus 0.50%; and (c) the Adjusted Eurodollar Rate for such day plus 1.00%. The Applicable Margin is determined based upon the leverage ratio as set forth in the most recent compliance certificate received by the Lender for each fiscal quarter from time to time pursuant to the New Credit Agreement. Depending on the leverage ratio, the Applicable Margin can be 0.25% to 0.75% for Base Rate Loans (as defined in the New Credit Agreement) and 1.25% to 1.75% for Eurodollar Rate Loans and for requested letters of credit. In addition, we are required to pay a monthly commitment fee on the daily average unused amount of the commitment while the New Credit Agreement is in effect at an annual rate equal to 0.25% of the unused commitment amount. Accrued interest is payable monthly on outstanding principal amounts and unused commitment fee, provided that accrued interest on Eurodollar Rate Loans is payable at the end of each interest period, but in no event less frequently than quarterly.
Covenants. The New Credit Agreement contains customary representations and warranties, as well as covenants which, among other things, condition or limit our ability to incur additional indebtedness and liens; enter into transactions with affiliates; make acquisitions in excess of certain amounts; pay dividends; redeem or repurchase capital stock or senior notes; make investments or loans; make negative pledges; consolidate, merge or effect asset sales; or change the nature of our business. In addition, we also have certain financial covenants that are applicable during certain trigger periods specified in the Credit Agreement and require us during such trigger periods to maintain a leverage ratio less than or equal to 3.00 to 1.00 as of the last day of each fiscal quarter and a fixed charge coverage ratio greater than or equal to 1.00 to 1.00 as of the last day of each fiscal quarter.
Events of Default and Acceleration. The New Credit Agreement contains customary events of default for credit facilities of this size and type, and includes, without limitation, payment defaults; defaults in performance of covenants or other agreements contained in the Credit Agreement and the other transaction documents; inaccuracies in representations and warranties; certain defaults, termination events or similar events; certain defaults with respect to any other Company indebtedness in excess of $1.0 million; certain bankruptcy or insolvency events; the rendering of certain judgments in excess of $1.0 million; certain ERISA events; certain change in control events and the defectiveness of any liens under the secured revolving credit agreement. Obligations outstanding under the Credit Agreement may be accelerated upon the occurrence of an event of default.
As of December 31, 2021, we were in compliance with all financial covenants in our New Credit Agreement. At December 31, 2021, we had no amounts outstanding under the New Credit Agreement.
9. Income Taxes
The (provision for) benefit from income taxes for the years ended December 31, 2021 and 2020, consists of the following (in thousands):
| | | | | | | | | | | |
| | 2021 | | 2020 |
| Current benefit: | | | |
| Federal benefit | $ | — | | | $ | 15,587 | |
| State (expense) benefit | 1 | | | (149) | |
| Total current benefit | 1 | | | 15,438 | |
| Deferred benefit: | | | |
| Federal benefit (expense) | 1,991 | | | (10,234) | |
| State benefit (expense) | 611 | | | (412) | |
| Total deferred benefit (expense) | 2,602 | | | (10,646) | |
| Total benefit | $ | 2,603 | | | $ | 4,792 | |
The effective tax rate for the years ended December 31, 2021 and 2020, differs from the statutory rate as follows:
| | | | | | | | | | | |
| | 2021 | | 2020 |
| Statutory rate | 21.0 | % | | 21.0 | % |
| State and local taxes | 5.2 | % | | (17) | % |
| | | |
| | | |
| | | |
| Stock based compensation | (0.7) | % | | (13.1) | % |
| Nondeductible compensation | (3.6) | % | | (11.6) | % |
| Effect of CARES Act | — | % | | 180.3 | % |
| | | |
| Other | 0.2 | % | | 0.5 | % |
| Effective rate | 22.1 | % | | 160.1 | % |
| | | |
| Effective rate | 22.1 | % | | 160.1 | % |
On March 27, 2020, the Coronavirus Aid, Relief, and Economic Security Act ("CARES Act") was enacted in response to the economic impact caused by the COVID-19 pandemic. The CARES Act, among other things, permits federal income tax net operating loss ("NOL") carryovers and carrybacks to offset 100% of taxable income for taxable years beginning before 2021. In addition, the CARES Act allows NOLs incurred in 2018, 2019, and 2020 to be carried back to each of the five preceding taxable years to generate a refund of previously paid federal income taxes.The Company generated significant NOLs during 2018 and 2019 and filed carryback claims for these losses to the preceding five years.Accordingly, as of March 31, 2020, the Company recorded a federal income tax receivable of $15.0 million and an increase to its deferred tax liability of $10.1 million on its condensed balance sheet.During the third quarter of 2020, the Company received refunds corresponding to the 2018 NOL carryback, leaving a balance in the federal income tax receivable of $11.5 million at December 31, 2021.
The income tax effects of temporary differences that give rise to significant portions of deferred income tax assets and (liabilities) as of December 31, 2021 and 2020, are as follows (in thousands):
| | | | | | | | | | | |
| | 2021 | | 2020 |
| Deferred income tax assets: | | | |
| Net operating loss | $ | 5,355 | | | $ | 3,361 | |
| Research and development credits | 1,363 | | | 1,363 | |
| Stock compensation | 114 | | | 175 | |
| Deferred compensation | 632 | | | 705 | |
| Other | 515 | | | 398 | |
| Total deferred income tax assets | 7,979 | | | 6,002 | |
| Deferred income tax liabilities: | | | |
| Property and equipment | (47,044) | | | (47,626) | |
| Goodwill and other intangible assets | (223) | | | (266) | |
| Total deferred income tax liabilities | (47,267) | | | (47,892) | |
| Net deferred income tax liabilities | $ | (39,288) | | | $ | (41,890) | |
As of December 31, 2021, the Company had NOL carryforwards for federal income tax purposes of $20.8 million, which may be carried forward indefinitely and can offset up to 80% of future taxable income in any given year.Future changes in ownership, as defined by Section 382 of the Internal Revenue Code ("IR"), could limit the amount of NOL carryforwards used in any one year.In general, under Section 382 and 383 of the IRC, a corporation that undergoes an “ownership change” is subject to limitations on its ability to utilize its pre-change NOLs and certain tax credits, to offset future taxable income and tax. In general, an ownership change occurs if the aggregate stock ownership of certain stockholders changes by more than 50 percentage points over such stockholders’ lowest percentage of ownership during the testing period (generally three years).
We account for uncertain tax positions in accordance with guidance in FASB ASC 740, which prescribes the minimum recognition threshold a tax position taken or expected to be taken in a tax return is required to meet before being recognized in the financial statements. The Company assessed whether it had any uncertain tax positions related to open tax years and concluded there were none. Accordingly, no reserve for uncertain tax positions has been recorded as of December 31, 2021 and 2020.
Our policy regarding income tax interest and penalties is to expense those items as incurred. During the years ended December 31, 2021 and 2020, there were no significant income tax interest or penalty items in the statement of operations.
We file income tax returns in the U.S. federal jurisdiction and various state jurisdictions. With few exceptions, we are no longer subject to U.S. federal or state income tax examination by tax authorities for years before 2015.
10. Deferred Compensation Plans
Effective January 1, 2016, the Company established a non-qualified deferred compensation plan for executive officers, directors and certain eligible employees. The assets of the deferred compensation plan are held in a rabbi trust and are subject to additional risk of loss in the event of bankruptcy or insolvency of the Company. The plan allows for deferral up to 90% of a participant’s base salary, bonus, commissions, director fees and restricted stock awards. A Company owned life insurance policy held in a rabbi trust is utilized as a source of funding for the plan. The cash surrender value of the life insurance policy is $2.5 million and $2.0 million as of December 31, 2021 and 2020, respectively, with a gain related to the policy of $298,000 and $168,000 reported in other income in our consolidated statement of operations for the year ended December 31, 2021 and 2020, respectively.
For deferrals of base salary, bonus, commissions and director fees, settlement payments are made to participants in cash, either in a lump sum or in periodic installments. The deferred obligation to pay the deferred compensation and the deferred director fees is adjusted to reflect the positive or negative performance of investment measurement options selected by each participant and was $2.8 million and $2.2 million as of December 31, 2021 and 2020, respectively. The deferred obligation is included in other long-term liabilities in the consolidated balance sheets.
For deferrals of restricted stock units, the plan does not allow for diversification, therefore, distributions are paid in shares of our common stock and the obligation is carried at grant value. As of December 31, 2021 and 2020, respectively, we
have 17,248 and 45,998 unvested restricted stock units being deferred. As of December 31, 2021 and 2020, respectively we have released and issued 174,452 and 145,702 shares to the deferred compensation plan with a value of $2.5 million and $2.2 million, respectively.
11. Stockholders' Equity
Preferred Stock
We have a total of 5.0 million authorized preferred shares which may be issued in series with rights and preferences as designated by the Board of Directors. As of December 31, 2021 and 2020, there were no issued or outstanding preferred shares.
12. Stock-Based and Other Long-Term Incentive Compensation
Restricted Stock
On June 20, 2019, at our annual meeting of shareholders, our shareholders approved an Equity Incentive Plan for restricted shares/units, stock options and other equity awards. The Equity Incentive Plan allows issuance up to 500,000 share of common stock. As of December 31, 2021, we had 276,319 shares outstanding under the Equity Incentive Plan that will vest over the next three years. As of December 31, 2021, 47,135 shares were still available for issuance under the Equity Incentive Plan.
On March 18, 2021, the Compensation Committee awarded 129,212 shares of restricted common stock to 2 executive officers that vest ratably over three years, beginning on March 18, 2022. On June 17, 2021, the Compensation Committee awarded 5,000 shares of restricted common stock to an executive officer that vest ratably over three years beginning on June 17, 2022. In addition, on March 18, 2021, 5,612 shares of restricted common stock were awarded to each of our 3 independent Board members. Lastly, on April 1, 2021, 5,291 shares of restricted common stock were awarded to a newly appointed independent Board member. The restricted stock issued to our directors vests in one year from the date of grant.
Compensation expense related to the restricted shares was approximately $1.7 million and $2.2 million for the years ended December 31, 2021 and 2020, respectively. As of December 31, 2021, there was a total of approximately $1.4 million of unrecognized compensation expense related to the unvested portion of these restricted shares/units. This expense is expected to be recognized over the next three years.
A summary of all restricted stock activity as of December 31, 2020 and 2021 and changes during the years then ended are presented below. | | | | | | | | | | | | | | | | | | | | | | | |
| | Number
of
Shares | | Grant Date Fair Value | | Weighted
Average
Remaining
Contractual Life (years) | | Aggregate Intrinsic Value (in thousands) |
| Outstanding, December 31, 2019 | 279,766 | | | $ | 20.15 | | | 8.77 | | $ | 3,430 | |
| Granted | 123,185 | | | $ | 5.68 | | | — | | | $ | 700 | |
| Vested | (144,850) | | | $ | 20.82 | | | — | | | $ | 946 | |
| Canceled/Forfeited | — | | | — | | | — | | | — | |
| Outstanding, December 31, 2020 | 258,101 | | | $ | 12.87 | | | 8.61 | | $ | 2,447 | |
| Granted | 156,339 | | | $ | 8.99 | | | — | | | $ | 1,406 | |
| Vested | (134,788) | | | $ | 14.94 | | | — | | | $ | 1,258 | |
| Canceled/Forfeited | (3333) | | | $ | 12.26 | | | — | | | $ | 31 | |
| Outstanding, December 31, 2021 | 276,319 | | | $ | 9.67 | | | 1.77 | | $ | 2,893 | |
Other Long-Term Incentive Compensation
On April 28, 2020, the Compensation Committee issued a long-term incentive award of $1.1 million to an executive officer that vests in equal, annual tranches over three years. At the time of vesting, each tranche will be payable in cash or common stock at the discretion of the Compensation Committee. On March 18, 2020, the Compensation Committee issued a long-term incentive award of $1.0 million to an executive officer that vests in equal, annual tranches over three years. In
addition, on April 28, 2020, we issued a $50,000 award to each of our 4 independent members of our Board of Directors as partial payment for their services in 2020. These awards vest one year from the date of grant and are payable in cash upon vesting. On March 18, 2021, we issued a $50,000 award to each of our 3 independent Board members. On April 1, 2021, we issued a $50,000 award to a newly appointed independent Board member. These awards vest one year from the date of grant and are payable in cash upon vesting. The Company accounts for these other long-term incentive awards as liabilities under accrued liabilities on our condensed consolidated balance sheet. The vesting of these awards is subject to acceleration upon certain events, such as (i) death or disability of the recipient, (ii) certain circumstances in connection with a change of control of the Company, (iii) for executive officers, termination without cause (as defined in the agreement), and (iv) for executive officers, resignation for good reason (as defined). Total compensation expense related to these other long-term incentive awards was approximately $0.8 million for the year ended December 31, 2021. As of December 31, 2021 there was a total of $1.2 million of unrecognized compensation expense related to these other long-term incentive awards which is expected to be recognized over the next three years.
Stock Option Plan
Our Stock Option Plan, which is stockholder approved, permits the granting of stock options to its employees for up to 1.0 million shares of common stock. We believe that such awards align the interests of our employees with our stockholders. Option awards are generally granted with an exercise price equal to the market price of our stock at the date of grant; those option awards generally vest in equal increments over three years of continuous service and have ten-year contractual terms. Certain option and share awards provide for accelerated vesting if there is a change in control of the Company (as defined in the Stock Option Plan). The last date that grants can be made under the Stock Option Plan is February 28, 2026. As of December 31, 2021, 345,003 shares were still available to be granted under the Stock Option Plan.
The fair value of each option award is estimated on the date of grant using the Black-Scholes option valuation model that uses the assumptions noted in the following table. The risk-free rate for periods within the contractual life of the option is based on the U.S. Treasury yield curve in effect at the time of grant. The expected life of options granted is based on the vesting period and historical exercise and post-vesting employment termination behavior for similar grants. We use historical data to estimate option exercise and employee termination within the valuation model; separate groups of employees that have similar historical exercise behavior are considered separately for valuation purposes.
| | | | | | | | | | | |
Weighted average Black -Scholes fair value assumption during the year ended December 31, are as follows: | | 2021 | | |
Risk free rate | | | 1.45 | % | | | | |
Expected life | | | 6.86 | | | | |
Expected volatility | | | 46.8 | % | | | | |
Expected dividend yield | | | — | % | | | | |
During the year ended December 31, 2021, 55,500 stock option grants were made.
A summary of all option activity as of December 31, 2020 and 2021 and changes during the years then ended are presented below:
| | | | | | | | | | | | | | | | | | | | | | | |
| | Number
of
Shares | | Weighted Average
Exercise Price | | Weighted
Average
Remaining
Contractual Life (years) | | Aggregate Intrinsic Value |
| | | | | | | (in thousands) |
| Outstanding, December 31, 2019 | 208,334 | | | $ | 23.67 | | | 3.66 | | $ | — | |
| Granted | 5,000 | | | $ | 4.91 | | | — | | | — | |
| Exercised | — | | | — | | | — | | | — | |
| Canceled/Forfeited | (12,000) | | | $ | 20.20 | | | — | | | $ | 24 | |
| Expired | (40,000) | | | $ | 19.11 | | | — | | | — | |
| Outstanding, December 31, 2020 | 161,334 | | | $ | 24.48 | | | 3.48 | | — | |
| Granted | 55,500 | | | $ | 10.58 | | | — | | | — | |
| Exercised | — | | | — | | | — | | | — | |
| Canceled/Forfeited | — | | | — | | | — | | | — | |
| Expired | (16,000) | | | $ | 17.81 | | | — | | | — | |
| Outstanding, December 31, 2021 | 200,834 | | | $ | 21.17 | | | 4.83 | | $ | — | |
| Exercisable, December 31, 2021 | 145,334 | | | $ | 25.21 | | | 2.86 | | $ | — | |
The weighted average grant date fair value of options granted during 2021 was $5.15 per option. We had 0 grants in 2020. There were no option exercises in either 2021 or 2020.
The following table summarizes information about our stock options outstanding at December 31, 2021:
| | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | | |
Range of Exercise Prices | | Options Outstanding | | Options Exercisable |
| Shares | | Weighted Average Remaining Contractual Life (years) | | Weighted Average Exercise Price | | Shares | | Weighted Average Exercise Price |
| | | | | | | | | | |
| $0.01-$18.00 | | 64,000 | | | 8.68 | | $ | 11.15 | | | 8,500 | | | $ | 14.89 | |
| $18.01-$22.00 | | 20,500 | | | 1.22 | | 18.75 | | | 20,500 | | | $ | 18.75 | |
| $22.01-$26.00 | | 42,167 | | | 3.28 | | 22.90 | | | 42,167 | | | $ | 22.90 | |
| $26.01-$30.00 | | 30,000 | | | 5.13 | | 28.15 | | | 30,000 | | | $ | 28.15 | |
| $30.01-$34.00 | | 44,167 | | | 2.22 | | 30.41 | | | 44,167 | | | $ | 30.41 | |
| | 200,834 | | | 4.83 | | $ | 21.17 | | | 145,334 | | | $ | 25.21 | |
The summary of the status of our unvested stock options as of December 31, 2021 and changes during the year then ended is presented below. | | | | | | | | | | | |
Unvested stock options: | Shares | | Weighted Average Grant Date Fair Value |
| Unvested at December 31, 2020 | — | | | $ | — | |
| Granted | 55,500 | | | $ | 10.58 | |
| Vested | — | | | — | |
| Canceled/Forfeited | — | | | — | |
| Unvested at December 31, 2021 | 55,500 | | | $ | 10.58 | |
We recognized stock compensation expense from stock options vesting of $728 and $19,366 for the years ended
December 31, 2021 and 2020, respectively. As of December 31, 2021, there was $247,000 of unamortized compensation cost related to unvested stock options.
13. (Loss) Earnings per Share
Basic (loss) earnings per common share is computed using the weighted average number of common shares outstanding during the period. Diluted (loss) earnings per common share is computed using the weighted average number of common stock and common stock equivalent shares outstanding during the period.
The following table sets forth the computation of basic and diluted (loss) earnings per share (in thousands, except per share amounts):
| | | | | | | | | | | |
| | Year Ended December 31, |
| | 2021 | | 2020 |
| Numerator: | | | |
| Net (loss) income | $ | (9,183) | | | $ | 1,808 | |
| Denominator for basic net (loss) income per common share: | | | |
| Weighted average common shares outstanding | 13,100 | | | 13,224 | |
| Denominator for diluted net (loss) income per share: | | | |
| Weighted average common shares outstanding | 13,100 | | | 13,224 | |
| Dilutive effect of stock options and restricted shares | — | | | 37 | |
| Diluted weighted average shares | 13,100 | | | 13,261 | |
| (Loss) earnings per common share: | | | |
| Basic | $ | (0.70) | | | $ | 0.14 | |
| Diluted | $ | (0.70) | | | $ | 0.14 | |
In the year ended ended December 31, 2021, 276,319 restricted stock/units and 200,834 stock options were not included in the computation of dilutive income per share, due to their anti-dilutive effect. In the year ended ended December 31, 2020, 221,061 restricted stock/units and 161,334 stock options were not included in the computation of diluted loss per share due to their antidilutive effect.
14. Commitments and Contingencies
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 other threatened litigation.
15. Subsequent Events
None.