UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON D.C. 20549
FORM 10-K
(Mark One)
☒ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
FOR THE FISCAL YEAR ENDED DECEMBER 31, 2023
OR
☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 FOR THE TRANSITION PERIOD FROM
TO .
COMMISSION FILE NUMBER 001-35195
CSI Compressco LP
(EXACT NAME OF THE REGISTRANT AS SPECIFIED IN ITS CHARTER)
Delaware
(State or Other Jurisdiction of Incorporation or Organization)
94-3450907
(I.R.S. Employer Identification No.)
1735 Hughes Landing Boulevard, Suite 200
(Address of Principal Executive Offices)
The Woodlands,
Texas
77380
(ZIP CODE)
(832) 365-2257
(Registrant’s Telephone Number, Including Area Code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
COMMON UNITS REPRESENTING LIMITED
PARTNERSHIP INTERESTS
Trading Symbol(s)
Name of each exchange on which registered
CCLP
NASDAQ
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 Act. Yes ☐ No ☒
Indicate by check mark whether the registrant: (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12
months (or for such shorter period that the registrant was required to file such reports); and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of
this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company.
See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer
Non-accelerated filer
☐
☐
Accelerated filer
Smaller reporting company
Emerging growth company
☒
☒
☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial
accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial reporting
under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.S. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. Yes ☐ No ☒
If securities are registered pursuant to Section 12(b) of the Act, indicate by check mark whether the financial statements of the registrant included in the filing reflect the correction of
an error to previously issued financial statements. Yes ☐ No ☒
Indicate by check mark whether any of those error corrections are restatements that required a recovery analysis of incentive-based compensation received by any of the registrant’s
executive officers during the relevant recovery period pursuant to §240.10D-1(b). Yes ☐ No ☒
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes ☐ No ☒
The aggregate market value of common stock held by non-affiliates of the Registrant was $94,545,412 as of June 30, 2023. As of February 28, 2024, there were 142,496,840
Common Units outstanding.
DOCUMENTS INCORPORATED BY REFERENCE- NONE
Item 1.
Item 1A.
Item 1B.
Item 1C.
Item 2.
Item 3.
Item 4.
Item 5.
Item 6.
Item 7.
Item 7A.
Item 8.
Item 9.
Item 9A.
Item 9B.
Item 9C.
Item 10.
Item 11.
Item 12.
Item 13.
Item 14.
Item 15.
Item 16.
Business
Risk Factors
Unresolved Staff Comments
Cybersecurity
Properties
Legal Proceedings
Mine Safety Disclosures
TABLE OF CONTENTS
Part I
Part II
Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Purchases of Equity
Securities
[Reserved].
Management’s Discussion and Analysis of Financial Condition and Results of Operations
Quantitative and Qualitative Disclosures about Market Risk
Financial Statements and Supplementary Data
Changes in and Disagreements with Accountants on Accounting and Financial Disclosure
Controls and Procedures
Other Information
Disclosure Regarding Foreign Jurisdictions that Prevent Inspections
Part III
Directors, Executive Officers, and Corporate Governance
Executive Compensation
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters
Certain Relationships and Related Transactions, and Director Independence
Principal Accounting Fees and Services
Exhibits and Financial Statement Schedules
Form 10-K Summary
Part IV
(i)
1
8
32
33
34
34
34
35
36
36
47
47
47
47
50
50
50
54
58
60
61
62
66
Forward-Looking Statements
This Annual Report on Form 10-K (this “Annual Report”) contains “forward-looking statements” and information based on our beliefs and those of our
general partner. Forward-looking statements in this Annual Report are identifiable by the use of the following words, the negative of such words, and other similar
words: “anticipates”, “assumes”, “believes”, “could”, “estimates”, “expects”, “forecasts”, “goal”, “intends”, “may”, “might”, “plans”, “predicts”, “projects”, “seeks”,
“should, “targets”, “will” and “would”.
Such forward-looking statements reflect our current views with respect to future events and financial performance and are based on assumptions that we believe
to be reasonable but such forward-looking statements are subject to numerous risks, and uncertainties, including, but not limited to:
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
economic and operating conditions that are outside of our control, including the trading price of our common units, and the supply, demand, and prices
of oil and natural gas;
the availability of adequate sources of capital to us, including changes to interest rates;
our existing debt levels and our ability to obtain additional financing;
our ability to continue to make cash distributions, or increase cash distributions from current levels, after the establishment of reserves, payment of
debt service, and other contractual obligations;
the restrictions on our business that are imposed under our long-term debt agreements;
our dependence upon a limited number of customers and the activity levels of our customers;
the levels of competition we encounter;
our ability to renew our contracts with customers, which are generally short-term contracts;
the availability of raw materials and labor at reasonable prices;
risks related to acquisitions and our growth strategy;
risks related to our potential merger with Kodiak, announced in December 2023;
fluctuations in the price for shares of Kodiak Common Stock;
the legal, financial, accounting, filing, printing and other costs related to the merger with Kodiak;
the risk of any litigation related to the merger with Kodiak;
the credit and risk profile of Spartan;
information technology risks including the risk from cyberattacks and cybersecurity breaches;
acts of terrorism, war or political or civil unrest in the United States or elsewhere, including the war between Russia and Ukraine, the conflict between
Israel and Hamas and continued hostilities in the Middle East;
operating hazards, natural disasters, weather-related impacts, casualty losses and other matters beyond our control;
the effects of existing and future laws and governmental regulations;
global or national health concerns, including the outbreak of pandemics or epidemics such as the COVID-19 pandemic, including operational
challenges, workforce challenges, and supply chain disruptions;
the effect and results of litigation, regulatory matters, settlements, audits, assessments, and contingencies; and
other risks and uncertainties under “Item 1A. Risk Factors” in this Annual Report and as included in our other filings with the U.S. Securities and
Exchange Commission (“SEC”), which are available free of charge on the SEC website at www.sec.gov.
The risks and uncertainties referred to above are generally beyond our ability to control and we cannot predict all the risks and uncertainties that could
cause our actual results to differ from those indicated by the forward-looking statements. If any of these risks or uncertainties materialize, or if any of the underlying
assumptions prove incorrect, actual results may vary from those indicated by the forward-looking statements, and such variances may be material.
All subsequent written and oral forward-looking statements made by or attributable to us or to persons acting on our behalf are expressly qualified in their
entirety by reference to these risks and uncertainties. You should not place undue reliance on forward-looking statements. Each forward-looking statement speaks
only as of the date of the particular statement, and we undertake no obligation to update or revise any forward-looking statements we may make, except as may be
required by law.
Summary Risk Factors
Our business is subject to varying degrees of risk and uncertainty. Investors should consider the risks and uncertainties summarized below, as well as the
risks and uncertainties discussed in Part I, Item 1A, “Risk Factors” of this Annual Report. Additional risks not presently known to us or that we currently deem
immaterial may also affect us. If any of these risks occur, our business, financial condition or results of operations could be materially and adversely affected.
(ii)
Our business is subject to the following principal risks and uncertainties:
•
•
•
•
•
•
Fluctuations in the market price for shares of Kodiak Common Stock makes it difficult for holders of our common units to be sure of the value of Kodiak
Common Stock that they will receive in the Mergers with Kodiak.
The Mergers with Kodiak are subject to various closing conditions, and delays in completing the Mergers could reduce or eliminate the benefits expected
from the Mergers.
The Merger Agreement and the support agreements entered into in connection therewith impose material restrictions on our ability to pursue strategic
alternatives to the Mergers.
Failure to complete the Mergers could negatively impact the price of our common units and our future business and financial results.
Reduced demand for or production levels of oil and gas adversely affect the demand for and prices we charge for our services, which could cause our
revenue and cash available for distribution to our unitholders to decrease.
Our results of operations, cash flows and financial condition were adversely impacted by the COVID-19 pandemic, and could in the future be impacted
by a similar pandemic or public health event.
Our substantial leverage.
•
• We may be unable to repurchase or refinance our senior secured notes in the event of a change of control as required by their respective indentures.
The loss of any of our most significant customers would result in a decline in our revenue and cash available to pay distributions to our common
•
unitholders.
Our ability to manage and grow our business effectively and provide quality services to our customers may be adversely affected if our general partner
loses its management or we are unable to retain trained personnel.
Pressure from competitors may result in price reductions and periods of reduced demand for our products.
Our operations in non-U.S. markets expose us to legal, political and economic risks that could have a material impact on our business.
Regulatory initiatives related to hydraulic fracturing could result in operating restrictions or delays in the completion of oil and gas wells that may reduce
demand for our services.
•
•
•
•
•
•
•
•
•
•
•
A cyberattack or other failure or security breach of our information technology infrastructure, or the theft, loss or misuse of personal data, could adversely
affect our business and operations.
Armed conflict, war, and acts of terrorism could disrupt global supply lines and transportation of oil and gas and result in reduced production of oil and gas
in the United States, which could adversely affect our business and operations.
The market price of our common units has been and may continue to be volatile.
Spartan has conflicts of interest, which may permit it to favor its own interests to our unitholders’ detriment.
Our partnership agreement limits our general partner’s fiduciary duties to our common unitholders and restricts the remedies available to our common
unitholders for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty.
Our common unitholders have limited voting rights and are not entitled to elect our general partner or its directors.
•
• We are exempt from certain corporate governance requirements that provide additional protection to stockholders of other public companies.
•
Our tax treatment depends on our status as a partnership for federal income tax purposes. Our cash available for distribution to unitholders may be
substantially reduced if we become subject to entity-level taxation as a result of the Internal Revenue Service (“IRS”) treating us as a corporation or
legislative, judicial or administrative changes, and may also be reduced by any audit adjustments if imposed directly on the Partnership.
Even if unitholders do not receive any cash distributions from us, unitholders will be required to pay taxes on their share of our taxable income. A
unitholder’s share of our taxable income may be increased as a result of the IRS successfully contesting any of the federal income tax positions we take.
Tax-exempt entities and non-U.S. unitholders face unique tax issues from owning our common units that may result in adverse tax consequences to
them.
Certain Defined Terms
Unless the context requires otherwise, when we refer to “we,” “us,” “our,” “Registrant” and “the Partnership,” we are describing CSI Compressco LP and its
wholly owned subsidiaries on a consolidated basis. References to “CSI Compressco GP” or “our general partner” refer to our general partner, CSI Compressco GP
LLC (f/k/a CSI Compressco GP Inc.). References to “TETRA” refer to TETRA Technologies, Inc., the former owner of our general partner, and TETRA’s controlled
subsidiaries. References to “Spartan” refer to Spartan Energy Partners LP. References to the “Initial Public Offering” refer to the Partnership’s initial public offering of
common units representing limited partner interests in the Partnership (“common units”) completed on June 20, 2011 pursuant to a Registration Statement on Form
S-1, as amended (File No. 333-155260), initially filed on November 10, 2008 by the Partnership with the SEC pursuant to the Securities Act of 1933, as amended
(the “Securities Act”), including a prospectus regarding the Initial Public Offering filed with the SEC on June 16, 2011 pursuant to Rule 424(b).
(iii)
Item 1. Business.
PART I
The financial statements presented in this Annual Report are the consolidated financial statements of CSI Compressco LP, a Delaware
limited partnership and its subsidiaries.
We were formed in October 2008. Our headquarters are located at 1735 Hughes Landing Boulevard, Suite 200, The Woodlands, Texas,
77380. Our phone number is (832) 365-2257 and our website is www.csicompressco.com. Our common units are traded on the NASDAQ Exchange
(“NASDAQ”) under the symbol “CCLP.”
Our Corporate Governance Guidelines, Code of Conduct, Financial Code of Ethics, Policy on Trading in Partnership Securities and Audit
Committee Charter, as well as our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K, and all
amendments to those reports are all available, free of charge, on our website at www.csicompressco.com as soon as practicable after we file the
reports with the SEC. Information contained on or connected to our website is not, and shall not be deemed to be, a part of this Annual Report on
Form 10-K or incorporated into any other filings with the SEC. The documents referenced above are available in print at no cost to any unitholder
who requests them from our Corporate Secretary.
About CSI Compressco LP
We are a provider of contract services related to the exploration and production of oil and natural gas, including natural gas compression
services and treating services. Natural gas compression is used for oil and natural gas production, gathering, artificial lift, transmission, processing,
and storage. Treating services include removal of contaminants from a natural gas stream and cooling to reduce the temperature of produced gas
and liquids. We also sell used standard compressor packages and provide aftermarket services and compressor package parts and components
manufactured by third-party suppliers. We provide contract compression and treating services and compressor parts and component sales to a
broad base of natural gas and oil exploration and production, midstream, transmission, and storage companies operating throughout many of the
onshore producing regions of the United States, as well as in a number of international locations, including the countries of Mexico, Canada,
Argentina and Chile.
We are one of the largest service providers of natural gas compression services in the United States, using our fleet of compressor
packages that employ a full spectrum of low-, medium-, and high-horsepower engines. Low-horsepower compressor packages enhance production
for dry gas wells and liquids-loaded gas wells by deliquefying the wells, lowering wellhead pressure, and increasing gas velocity. These packages
are also used in connection with oil and liquids production and in vapor recovery and casing gas system applications. Low- to medium-horsepower
compressor packages are typically selected for wellhead and natural gas gathering systems, artificial lift systems, and other applications primarily in
connection with natural gas and oil production. Our high-horsepower compressor package offerings are typically deployed in natural gas production,
natural gas gathering, centralized gas lift, centralized compression facilities, and midstream applications.
Our aftermarket business provides a wide range of services and compressor package parts and components manufactured by third-party
suppliers to support the needs of customers who own compression equipment. These services include operations, maintenance, overhaul, and
reconfiguration services and may be provided under turnkey engineering, procurement and construction contracts. Our aftermarket services are
provided by our factory- and internally-trained technicians in most of the major oil and natural gas producing basins in the United States and Mexico.
Our long-term growth strategy includes expanding our existing businesses through organic growth and accretive acquisitions, both in the
U.S. and internationally.
Our operations are organized into a single business segment. See Note 13 - “Segments” in the Notes to Consolidated Financial Statements
in this Annual Report for further information. For financial information regarding our revenues and total assets, see Note 14 - “Geographic
Information” contained in the Notes to Consolidated Financial Statements in this Annual Report.
1
Proposed Merger with Kodiak
On December 19, 2023, we entered into an Agreement and Plan of Merger (the “Merger Agreement”), by and among the Partnership,
Kodiak Gas Services, Inc., a Delaware corporation (“Kodiak”), Kodiak Gas Services, LLC, a Delaware limited liability company and indirect, wholly
owned subsidiary of Kodiak (“Kodiak Services”), Kick Stock Merger Sub, LLC, a Delaware limited liability company and indirect, wholly owned
subsidiary of Kodiak, Kick GP Merger Sub, LLC, a Delaware limited liability company and direct, wholly owned subsidiary of Kodiak Services, and
Kick LP Merger Sub, LLC, a Delaware limited liability company and direct, wholly owned subsidiary of Kodiak Services, pursuant to which Kodiak
will acquire the Partnership through a series of mergers (the “Mergers”). Under the terms of the Merger Agreement, (i) our common unitholders
(excluding certain holders described in clause (ii)) will receive 0.086 (the “Exchange Ratio”) shares of common stock, par value $0.01 per share, of
Kodiak (“Kodiak Common Stock”) in exchange for each common unit, (ii) our common unitholders that meet certain specified conditions may elect
to receive as consideration for each common unit, in lieu of a number of shares of Kodiak Common Stock equal to the Exchange Ratio, a number of
units (“OpCo Units”) in Kodiak Services, equal to the Exchange Ratio and an equal number of shares of Series A Preferred Stock of Kodiak (“Series
A Preferred Stock”), and (iii) the owner of our general partner will receive, in consideration for the notional units representing the general partner
interest in the Partnership, a number of OpCo Units and shares of Series A Preferred Stock equal to the Exchange Ratio for each such notional unit.
Each OpCo Unit will be redeemable for one share of Kodiak Common Stock (together with the cancellation of one share of Series A Preferred
Stock) pursuant to the terms of the Sixth Amended and Restated Limited Liability Company Agreement of Kodiak Services. On February 21, 2024,
upon the delivery of written consents approving the Mergers by each of the Supporting Unitholders (as defined below), we received the requisite
unitholder approval to consummate the Mergers. See “Item 1A. Risk Factors,” for additional discussion of risks related to the Mergers.
Products and Services
We are a provider of contract services including natural gas compression services and treating services. Natural gas compression is a
mechanical process in which the pressure of a given volume of natural gas is increased to a higher pressure. It is essential to the production and
movement of natural gas. Compression is typically required numerous times in the natural gas production and sales cycle, including (i) at the
wellheads, (ii) throughout gathering and distribution systems, (iii) into and out of processing and storage facilities, and (iv) in natural gas pipelines.
Compression is also utilized for gas lift, an artificial lift technique for producing oil that has insufficient reservoir pressure. Natural gas treating
encompasses several processes used to remove contaminants and improve the marketability of gas. We also provide aftermarket compression
services and compressor package parts and components manufactured by third-party suppliers.
Contract Services
We use our fleet of compressor packages to provide a variety of compression services to our customers to meet their specific requirements. Our
fleet includes approximately 4,300 compressor packages that provide approximately 1.2 million in aggregate horsepower, employing a wide
spectrum of low-, medium-, and high-horsepower engines. The horsepower of our natural gas compressor package fleet as of December 31, 2023
is summarized in the following table:
Range of Horsepower Per Package
Number of Packages
Aggregate Horsepower
Low-horsepower (0-100)
Medium-horsepower (101-1,000)
High-horsepower (1,001 and over)
Total
2,466
1,398
460
4,324
116,701
400,271
658,945
1,175,917
% of Aggregate
Horsepower
10 %
34 %
56 %
100 %
®
Low-Horsepower (0-100 Horsepower) Compression Services. Our natural gas-powered, low-horsepower compressor packages include our
GasJack compressor packages that are relatively compact and easy to transport to our customer’s well site. We utilize our electric powered, low-
horsepower VJack™ compressor packages to provide production enhancement services on wells where electric power is available. Our low-
horsepower packages allow us to perform wellhead compression, fluids separation, and optional gas metering services all from one skid, thereby
providing services that otherwise would generally require the use of multiple, more costly pieces of equipment. We utilize our low-horsepower
compressor packages to provide production enhancement for dry gas wells and liquid-loaded gas wells and backside auto injection systems
(“BAIS”). BAIS monitors tubing pressure to redirect gas flow into the casing annulus as needed to help gas wells unload liquids that hinder
production. We also
2
utilize our low-horsepower compressor packages to collect hydrocarbon vapors that are a by-product of oil production and storage (“vapor
recovery”) and to reduce casing pressure of pumping oil wells to enhance oil production (“casing gas systems”).
Medium-horsepower (101-1,000 Horsepower) Compression Services. Our medium-horsepower compressor packages are primarily utilized to
move natural gas from the wellhead through the field gathering system by boosting the pressure of the natural gas flowing through the system.
Additionally, these compressor packages are used to reinject natural gas into producing vertical and horizontal oil wells that have insufficient
reservoir pressure, to help lift liquids to the surface (“gas lift operations”). Typically, these applications require medium-horsepower compressor
packages located at or near the wellhead. These compressor packages are also used to increase the efficiency of low-capacity natural gas fields by
providing a central compression point from which the natural gas can be further processed and transported. These compressor packages feature
primarily two- and three-stage compressors powered by natural gas engines ranging from 101 to 1,000 horsepower and equipped with interstage
cooling.
High-Horsepower (Over 1,000 Horsepower) Compression Services. Our high-horsepower compressor packages are primarily utilized in
midstream applications including natural gas gathering, gas lift, and centralized compression facilities. They boost the pressure of natural gas
flowing from individual wells or a group of wells into a gathering pipeline that leads to various types of processing facilities. A significant number of
these compressor packages in midstream applications also serve the dual purpose of gas lift operations by injecting a percentage of the
compressed natural gas into producing oil wells. Our high-horsepower compressor packages are also used for traditional midstream applications in
gas gathering and processing facilities. These compressor packages feature primarily two- and three-stage compressors powered by natural gas
engines.
Gas Treating. We provide a variety of natural gas treating services for natural gas producers and midstream companies, such as providing
equipment for lease or sale, equipment installation services and the operation of equipment which Spartan Treating refers to as contract services.
Spartan Treating’s two primary gas treating services provided for customers are the removal of contaminants from the customer’s gas stream and
natural gas cooling to reduce the gas temperature. Spartan Treating maintains a fleet of amine plants ranging in size used to treat varying customer
gas flow volumes by removing hydrogen sulfide and carbon dioxide to meet required pipeline specifications. Additionally, Spartan Treating’s
equipment fleet includes natural gas cooling units used to reduce the temperature of natural gas so that it can be further treated, processed or
compressed.
Other Related Services. In Mexico, we provide well monitoring and sand separation services in connection with our compression services. Well
monitoring services include a variety of services that monitor and optimize production from oil and gas wells. We utilize automated sand separators,
which are high-pressure vessels with automated valve operation functions, at the well to remove solids that would otherwise cause abrasive wear
damage to compression and other equipment that is installed downstream and inhibit production from the well.
Contract Services Contract Terms. Our contract services are primarily performed under service contracts using our low-, medium-, and high-
horsepower compressor packages and our treating assets. A significant portion of these compression services are provided under services
contracts that our outside legal counsel has concluded generate qualifying income. Under these services contracts, we are responsible for providing
our services in accordance with the particular specifications of a job. As owner and operator, we are responsible for operating and maintaining the
equipment we utilize to provide our services. Our low horsepower compression service contracts typically have an initial term of one month and,
unless terminated by us or our customers with 30-days’ notice, continue on a month-to-month basis thereafter. Our medium- and high- horsepower
compression service and treating contracts typically have an initial term of twelve months, but range from six months to thirty-six months. After the
initial terms on our medium- and high-horsepower compression service and treating contracts, customers typically continue on a month-to-month
basis or renew for additional extensions. We charge our customers a fixed monthly fee for the services provided under the services contracts. Aside
from factors beyond our control, if the level of services we provide falls below certain contractually specified percentages, our customers are
generally entitled to request limited credits against our service fees. To date, these credits have been insignificant as a percentage of revenue.
We generally own the equipment we use to provide services to our customers, and we bear the risk of loss to this equipment to the extent not
caused by (i) a breach of certain obligations of the customer, primarily involving the service site and the fuel gas being supplied to us, or (ii) an
uncontrolled well condition. Utilizing our proprietary,
3
telemetry-based reporting system, we remotely monitor, in real time, whether our services are being continuously provided at our U.S. customer well
sites.
As owner of the equipment, we are obligated to pay ad valorem taxes levied on the equipment and related insurance expenses, and we typically
do not seek reimbursement for such taxes and expenses from our service agreement customers.
Aftermarket Services
Through our aftermarket operations, we provide a wide range of services to support the needs of customers who own compression equipment.
The services provided are primarily operation, maintenance, overhaul and reconfiguration services, which may be provided under turnkey contracts.
We also sell engine parts, compressor package parts and other parts manufactured by third parties that are utilized in natural gas compressor
packages. We have factory- and internally-trained technicians in most of the major oil and natural gas producing basins in the United States to
perform these services.
Market Overview and Competition
Oil and natural gas commodity prices gained strength through the first half of 2022 before remaining relatively stable with a slight decline during
the remainder of 2022 and during 2023. While there has been a decline in commodity prices, they remain at strong levels. Accordingly, we did not
have a negative impact in the demand for our contract services, aftermarket services and equipment rentals during 2023. Revenue from contract
services increased each quarter in 2023. We secured orders from key customers for high-horsepower and electric compressors that started
generating revenues in the fourth quarter of 2023 and continue to be deployed throughout 2024. The strengthening market environment has
increased competition for field and corporate employees. Supply chain issues, increased commodity prices, and inflationary pressures have
increased costs and impacted availability of our parts and supplies. External factors including Russia’s invasion of Ukraine, recent events in the
Middle East, inflationary pressures, and related policy, such as Federal Reserve interest rate increases, could adversely affect our results of
operations, impair our ability to raise capital, or otherwise adversely impact our ability to realize certain business strategies. We continue to monitor
these risks and take the necessary actions to mitigate them. We have and will continue to evaluate the sale of non-core assets, including our low-
horsepower compression fleet, but we can provide no assurance that we will consummate a future sale of our low-horsepower compression fleet.
Customers
We provide services to a broad base of natural gas and oil exploration and production, midstream, pipeline transmission, and storage companies
operating throughout many of the onshore producing regions of the United States. We also have operations in Canada, Mexico, Argentina and
Chile. While most of our services in the U.S. are performed throughout Texas (with a concentration in the Permian Basin), the Haynesville shale, the
San Juan Basin, the Rocky Mountain region, and the Mid-Continent region, we also have a presence in the Marcellus / Utica and other producing
regions. We continue to evaluate opportunities to further expand our operations into other regions in the U.S. and elsewhere in the world.
Following the expiration of the primary term, the parties may elect to renew or extend the term, or our service contracts typically will
continue month to month until terminated upon thirty days’ notice. Our low-horsepower compression fleet is generally deployed on short-term
contracts while our medium-horsepower is generally deployed on 12 month terms or greater and high-horsepower fleet is generally deployed with
an initial term of 24 months or greater. Although we enter into short-term contracts on our lower horsepower units, the average duration a typical
unit stays deployed with the same customer is greater than 30 months. Our significant customers for the year ended December 31, 2023 include
various major integrated oil companies, public and private independent exploration and production companies and midstream companies, one of
which individually accounted for more than 10% of our consolidated revenues for the year ended December 31, 2023. The loss of any of our major
customers could have a material adverse effect on our business, results of operations, financial condition, and our ability to make cash distributions
to our unitholders.
Competition
The natural gas compression services business is highly competitive. We experience competition from companies that may be able to more
quickly adapt to changes within our industry and changes in economic conditions as a whole, more readily take advantage of available opportunities
and technologies, and adopt more
4
aggressive pricing policies. Primary competition for our low-horsepower compression services business comes from smaller local and regional
companies that utilize packages consisting of a screw or reciprocating compressor with a separate engine driver. These local and regional
competitors tend to compete on the basis of price and availability, as opposed to our focus of adding value to the customer. Competition for our
medium- and high-horsepower compression services business comes primarily from large companies that may have greater financial resources
than we do. Such competitors include Archrock Compression Services, Kodiak Gas Services, USA Compression Partners and Natural Gas
Compression Systems, Inc. Competitors for natural gas treating contract services include USA Compression Partners and Kinder Morgan.
Many of our competitors compete on the basis of price. We believe our pricing has proven to be competitive because of the significant increase in
value that results from use of our services, our customer service, trained field personnel, and the quality of the compressor packages we use to
provide our services.
Other Business Matters
Marketing
We use various marketing strategies to promote our services and compressor package products. Our account managers work to build close
working relationships with our existing and potential future customers, educating them about our services and products by scheduling personal
visits, hosting and attending workshops, tradeshows and conferences, and participating in industry organizations. We sponsor and make
presentations at industry events that are targeted to production managers, compression specialists and other decision makers. Our marketing
representatives also use these marketing opportunities to promote our value-added service initiatives, such as the use of our proprietary telemetry-
based system, our wellsite optimization program and our fleet reliability center.
Human Capital Management
We collaborate as a team to execute for each other, our customers, and our unitholders. On December 31, 2023, we employed
approximately 719 people worldwide. Our employees in the U.S. and Canada are not subject to collective bargaining agreements. Our employees in
Argentina and Mexico are subject to collective bargaining agreements. We believe that the various employers of these employees have good
relations with these employees and we have not experienced work stoppages in the past.
Career Development
Our executive team evaluates executive development and succession planning to prepare us for future success. The succession planning
process covers all senior management positions and certain other key positions. This review of executive talent determines readiness to take on
additional leadership roles and identifies developmental opportunities needed to prepare our executives for greater responsibilities. Our short and
long-term business strategy is considered when evaluating candidates and their skills.
Compensation and Benefits
Our compensation programs are designed to incentivize performance, maximize returns, and build unitholder value. We work with
consultants to benchmark our compensation and benefits programs to help us offer competitive compensation packages to attract and retain high-
performing talent. We also offer competitive benefits to attract and retain exceptional talent.
Safety
Recognizing that safety, service quality, and environmental protection are conditions of employment, all employees and contractors are
responsible for their safety, the safety of those around them, the quality of their work, and protection of the environment. As part of our safety-
focused culture, it is customary that each meeting starts with an employee-led safety moment.
To ensure our work remains safe and of the highest quality, we have a comprehensive Health, Safety, Environment, and Quality (HSEQ)
Management System and program designed to improve the capacity of the organization by controlling worksite risks, developing proper work
practices and procedures, and empowering
5
employees with stop-work authority if they observe unsafe conditions, omissions, errors, or actions that could result in safety or environmental
incidents, or product and service quality issues. If an incident takes place, we investigate all serious occurrences to root causes and implement
corrective actions to ensure we expand our capacity to operate safely.
Driving is one of the highest exposure activities that we undertake in our day-to-day operations. We maintain a fleet of Department of
Transportation (DOT) and non-DOT vehicles and provide positive, real-time behavior feedback to our drivers via real-time monitors. Coupled with
vehicle selection guidelines and driver training, we have a comprehensive approach to reducing our driving exposure and incidents.
Proprietary Technology and Trademarks
It is our practice to enter into confidentiality agreements with employees, consultants, and third parties to whom we disclose our confidential and
proprietary information. There can be no assurance, however, that these measures will prevent the unauthorized disclosure or use of our trade
secrets and expertise or that others may not independently develop similar trade secrets or expertise. Our management believes, however, that it
would require a substantial period of time and substantial resources to independently develop similar know-how or technology.
We sell various services and products under a variety of trademarks and service marks, some of which are registered in the United States.
Health, Safety, and Environmental Affairs Regulations
Our service and sales operations are subject to stringent and complex U.S. and foreign health, safety, and environmental laws and regulations,
and, although we are committed to conducting all of our operations under the highest standards of safety and respect for the environment, risks of
substantial costs and liabilities pursuant to laws and regulations are inherent in certain of our operations. Because of these risks, there can be no
assurance that significant costs and liabilities will not be incurred now or in the future. Changes in health, safety, and environmental laws and
regulations could subject us to more rigorous standards and could affect demand for our customer’s product which in turn would impact demand for
our products. We cannot predict the extent to which our operations may be affected by any changes to existing laws, regulations, and enforcement
policies, new interpretations of existing laws, regulations, and policies, or any new laws, regulations, or policies promulgated in the future.
We are subject to numerous federal, state, and local laws and regulations governing the discharge of materials into the environment or otherwise
relating to protection of human health and the environment. The primary environmental laws that impact our operations in the U.S. include:
•
•
•
•
the Clean Air Act (“CAA”) and comparable state laws and regulations thereunder, which regulate air emissions;
the Federal Water Pollution Control Act of 1972 (the “Clean Water Act”) and comparable state laws, and regulations thereunder, which
regulate the discharge of pollutants into regulated waters, including industrial wastewater discharges and storm water runoff;
the Resource Conservation and Recovery Act (“RCRA”) and comparable state laws and regulations thereunder, which regulate the
management and disposal of solid and hazardous waste; and
the federal Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA” or “Superfund”) and comparable
state laws, and regulations thereunder, which impose liability for the cleanup of releases of hazardous substances in the environment.
Our operations in the U.S. are also subject to regulation under the Occupational Safety and Health Act (“OSHA”) and comparable state laws, and
regulations thereunder, which regulate the protection of the health and safety of workers.
The CAA and implementing regulations, and comparable state laws and regulations, regulate emissions of air pollutants from various industrial
sources and impose various monitoring and reporting requirements, including requirements related to emissions from certain stationary engines,
including our compressor packages. These laws and regulations impose limits on the levels of various substances that may be emitted into the
atmosphere from our compressor packages and require us to meet stringent air emission standards and install new emission control equipment on
all of our engines built after July 1, 2008. In addition, regulations under the National Emission
6
Standards for Hazardous Air Pollutants (“NESHAP”) provisions of the CAA require control of hazardous air pollutants from new and existing
stationary reciprocal internal combustion engines. Our equipment is also subject to prescribed maintenance practices and catalyst installation may
also be required. Furthermore, in June 2016, the Environmental Protection Agency (“EPA”) finalized rules that establish new air emission controls
under the EPA’s New Source Performance Standards (“NSPS”) and NESHAP for natural gas and natural gas liquids production, processing and
transportation activities. These rules establish specific requirements associated with volatile organic compounds and methane emissions from
compressor packages and controllers at natural gas gathering and boosting stations. In December 2023, the EPA finalized more stringent methane
rules for new, modified, and reconstructed facilities, known as OOOOb, as well as standards for existing sources, known as OOOOc. Under the final
rules, states have two years to prepare and submit their plans to impose methane emissions controls on existing sources. The presumptive
standards established under the final rule are generally the same for both new and existing sources and include enhanced leak detection survey
requirements using optical gas imaging and other advanced monitoring to encourage the deployment of innovative technologies to detect and
reduce methane emissions, reduction of emissions by 95% through capture and control systems, zero-emission requirements for certain devices,
and the establishment of a “super emitter” response program that would allow third parties to make reports to EPA of large methane emission
events, triggering certain investigation and repair requirements. Fines and penalties for violations of these rules can be substantial. It is likely,
however, that the final rule and its requirements will be subject to legal challenges. Moreover, compliance with the new rules may affect the amount
owed under the Inflation Reduction Act (“IRA 2022”), signed into law in August 2022, which imposes the first ever federal methane fee on excess
methane emissions from sources required to report their GHG emissions to the EPA. The methane emissions charge imposes a fee on excess
methane emissions from certain oil facilities starting at $900 per metric ton of leaked methane in 2024 and rising to $1,200 in 2025 and $1,500 in
2026 and thereafter. The requirements of the EPA’s final methane rules and the IRA 2022’s methane emissions fee could accelerate the transition
away from fossil fuels, which could in turn reduce the demand for our services.
The EPA has determined that greenhouse gases (“GHGs”) present an endangerment to public health and the environment because, according to
the EPA, they contribute to global warming and climate change. As a result, the EPA has begun to regulate certain sources of GHGs, including air
emissions associated with oil and gas production particularly as they relate to the hydraulic fracturing of natural gas wells. In addition, the EPA has
issued regulations requiring the reporting of GHG emissions from certain sources including onshore and offshore oil and natural gas production
facilities and onshore oil and gas processing, transmission, storage, and distribution facilities. Reporting of GHG emissions from such facilities is
required on an annual basis. President Biden has issued executive orders that commit to substantial action on climate change and the reduction of
GHG emissions, calling for, among other things, the increased use of zero-emissions vehicles by the federal government, the elimination of
subsidies provided to the fossil fuel industry, and an increased emphasis on climate-related risk across government agencies and economic sectors.
Further, Congress has considered, and almost one-half of the states have adopted, legislation that seeks to control or reduce emissions of GHGs
from a wide range of sources.
The Clean Water Act and implementing regulations, and comparable state laws and regulations, prohibit the discharge of pollutants into regulated
waters without a permit and establish limits on the levels of pollutants contained in these discharges. In addition, the Clean Water Act and other
comparable laws and regulations regulate storm water discharges associated with industrial activities depending on a facility’s primary standard
industrial classification.
RCRA and implementing regulations, and comparable state laws and regulations, address the management and disposal of solid and hazardous
waste. These laws and regulations govern the generation, storage, treatment, transfer, and disposal of wastes including, but not limited to, used oil,
antifreeze, filters, sludges, paint, solvents and sandblast materials. The EPA and various state agencies have limited the approved methods of
disposal for these types of wastes.
CERCLA and comparable state laws and regulations impose strict, joint, and several liabilities without regard to fault or the legality of the original
conduct on certain classes of persons that contributed to the release of a hazardous substance into the environment. These persons include the
owner or operator of a disposal site where a hazardous substance release occurred and any company that transported, disposed of, or arranged for
the transport or disposal of such hazardous substances released at a site. Under CERCLA, such persons may be liable for the costs of remediating
the hazardous substances that have been released into the environment, for damages to natural resources and for the costs of certain health
studies.
7
Although we believe that we have properly disposed of all historical waste streams and that we have no outstanding liability regarding any past
waste handling or spill activities, there is always the possibility that future spills and releases of petroleum hydrocarbons, wastes, or other regulated
substances into the environment could cause us to become subject to remediation costs and liabilities under CERCLA, RCRA, or other
environmental laws. The costs and liabilities associated with the future imposition of remedial obligations could have the potential for a material
adverse effect on our operations or financial position.
We are also subject to the requirements of OSHA and comparable state statutes. These laws and 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.
While we do not believe that compliance with existing requirements under applicable U.S. environmental laws and regulations will have a
material adverse effect on our business and results of operations, we cannot guarantee that we will not incur substantial costs now or in the future
with respect to compliance with or liability under such laws and regulations.
Our operations outside the U.S. are subject to foreign governmental laws and regulations relating to health, safety, and the environment and
other regulated activities. While we do not believe that compliance with existing foreign environmental laws and regulations will have a material
adverse effect on our business and results of operations, we cannot guarantee that we will not incur substantial costs now or in the future with
respect to compliance with or liability under such foreign laws and regulations.
Related Party Agreements
In connection with the Contribution Agreement, the Partnership entered into a Management Services Agreement, dated November 10,
2021, by and among the Partnership, our general partner, Spartan, Spartan Energy Partners GP LLC, the general partner of Spartan (“Spartan
GP”), and Spartan Operating Company LLC (the “Management Services Agreement”). Under the terms of the Management Services Agreement,
our general partner, Spartan Operating Company LLC (“Spartan Operating”) and Spartan GP will provide certain services reasonably necessary for
the operation of the businesses of the Partnership and its subsidiaries, Spartan, Spartan GP and Spartan Treating, including certain corporate and
general and administrative services. Pursuant to the Management Services Agreement, our general partner and Spartan GP will allocate any costs
and expenses incurred on a reasonable basis, and the parties will reimburse such other parties for costs and expenses allocated to them.
For a more comprehensive discussion on agreements we have entered into with related parties, please see “Item 13 - Certain Relationships and
Related Transactions, and Director Independence.”
Item 1A. Risk Factors.
Certain Risks Related to Potential Mergers with Kodiak
Because the market price for shares of Kodiak Common Stock will fluctuate prior to the consummation of the Mergers, holders of our common units
cannot be sure of the market value of shares of Kodiak Common Stock (or OpCo Units and shares of Series A Preferred Stock) that they will
receive in the Mergers.
At the time the Mergers are completed, holders of our common units will receive 0.086 shares of Kodiak Common Stock, with cash paid in
lieu of the issuance of fractional shares, if any (or, in the case of the Electing Unitholders, 0.086 OpCo Units, with cash paid in lieu of the issuance of
fractional units, if any, and an equal number of shares of Series A Preferred Stock, which together will be redeemable, subject to certain limitations,
for shares of Kodiak Common Stock) for each Partnership Common Unit they own as of immediately prior to the Mergers. At the time that
Partnership Common Unitholders return their written consents regarding the approval of the Merger Agreement, holders of our common units will
not know the actual market value of the shares of Kodiak Common Stock (or OpCo Units and shares of Series A Preferred Stock) that they will
receive when the Mergers are completed. The actual market value of the shares of Kodiak Common Stock (or OpCo Units and shares of Series A
Preferred Stock), when received by holders of our common units, will depend on the market value of the shares of Kodiak Common Stock on that
date. This market value may be less than the value of the shares of Kodiak Common Stock on the date of the Merger Agreement and on the date
that holders of our common units return their written
8
consents regarding the approval of the Merger Agreement. These fluctuations in the market value of shares of Kodiak Common Stock may be
caused by a variety of factors, including general market and economic conditions, changes in Kodiak’s businesses, operations and prospects and
regulatory considerations. Such factors are difficult to predict and, in many cases, may be beyond the Partnership’s and Kodiak’s control. Neither
the Partnership nor Kodiak is permitted to terminate the Merger Agreement as a result, in and of itself, of any increase or decrease in the market
price of our common units or Kodiak Common Stock.
The Mergers are subject to various closing conditions, and any delay in completing the Mergers may reduce or eliminate the benefits expected and
delay the payment of the consideration for the Mergers to holders of our common units.
The Mergers are subject to the satisfaction of a number of other conditions beyond the parties’ control that may prevent, delay or otherwise
materially adversely affect the completion of the Mergers. These conditions include, among other things, the expiration or termination of any
applicable waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended. Kodiak and the Partnership cannot predict
with certainty whether and when any of these conditions will be satisfied. Any delay in completing the Mergers could cause the combined company
not to realize, or delay the realization, of some or all of the benefits that the companies expect to achieve from the Mergers. In such context, the
date on which our unitholders will receive the merger consideration is also uncertain.
Partnership Common Unitholders will have a reduced ownership and voting interest after the Mergers.
When the Mergers occur, each of our unitholders will become a stockholder of Kodiak (and those who receive OpCo Units (and
corresponding shares of Series A Preferred Stock) will become unitholders of Kodiak Services and ultimately may become common stockholders of
Kodiak upon the redemption of their OpCo Units (and cancellation of corresponding shares of Series A Preferred Stock)) with a percentage
ownership of the combined company that is much smaller than such unitholder’s percentage ownership of the Partnership. Based on the number of
shares of Kodiak Common Stock and Partnership Common Units outstanding as set forth in their respective Quarterly Reports for the quarter ended
September 30, 2023, our unitholders will own approximately 14% of the outstanding shares of Kodiak Common Stock and OpCo Units after the
Mergers, on a fully diluted basis.
The merger agreement and the support agreements entered into with certain members of management and large unitholders limit the Partnership’s
ability to pursue alternatives to the Mergers.
The merger agreement contains provisions that make it more difficult for the Partnership to sell its business to a party other than Kodiak.
These provisions include the general prohibition on the Partnership soliciting any proposal or offer for a competing transaction from a third party,
and the requirement that the Partnership pay Kodiak a breakup fee of $15 million if the merger agreement is terminated in specified circumstances.
In addition, our NEOs (as defined below) and certain large unitholders (collectively, the “Supporting Unitholders”) entered into support agreements
which obligated them to deliver their written consent to each of the matters for which we are soliciting consents of our unitholders after the
registration statement became effective under the Securities Act. After the registration statement was declared effective by the SEC on February 20,
2024, each of the Supporting Unitholders delivered their written consent on February 21, 2024 approving the matters for which we are soliciting
consent of our unitholders. The delivery of the written consents by the Supporting Unitholders is sufficient to approve the merger agreement. The
foregoing may discourage a third party that might have an interest in acquiring all or a significant part of the Partnership from considering or
proposing an acquisition, even if that party were prepared to pay consideration with a higher per unit value than the current proposed merger
consideration.
The pendency of the Mergers could materially adversely affect the future business and operations of the Partnership or result in a loss of the
Partnership’s employees.
In connection with the pending Mergers, it is possible that some customers, suppliers and other persons with whom we have a business
relationship may delay or defer certain business decisions or might decide to seek to terminate, change or renegotiate their relationship with us as a
result of the Mergers, which could negatively impact our revenues, earnings and cash flows, as well as the market price of our common units,
regardless of whether the Mergers are completed. Similarly, current and prospective employees may experience uncertainty
9
about their future roles with Kodiak and the Partnership following completion of the Mergers, which may materially adversely affect our ability to
attract and retain key employees.
We will incur substantial transaction-related costs in connection with the Mergers, including fees paid to legal, financial and accounting advisors,
filing fees and printing costs.
We have incurred and expect to incur a number of non-recurring costs associated with the Mergers. These costs include financial advisory,
legal, accounting, consulting and other advisory fees, severance/employee benefit-related costs, public company filing fees and other regulatory
fees, printing costs and other related costs. Some of these costs are payable by either Kodiak or the Partnership regardless of whether or not the
Mergers are completed.
We may be subject to class action lawsuits relating to the Mergers, which could materially adversely affect our business, financial condition and
operating results.
The Partnership or our general partner, or our general partners directors and officers, may be subject to class action lawsuits relating to the
Mergers and other additional lawsuits that may be filed. Securities class action lawsuits and derivative lawsuits are often brought against public
companies that have entered into merger agreements. Even if the lawsuits are without merit, defending against these claims can result in
substantial costs and divert management time and resources. An adverse judgment could result in monetary damages, which could have a negative
impact on our liquidity and financial condition. Additionally, if a plaintiff is successful in obtaining an injunction prohibiting completion of the Mergers,
then that injunction may delay or prevent the Mergers from being completed, which may adversely affect our business, financial position and results
of operation. Currently, we are unaware of any securities class action lawsuits or derivative lawsuits having been filed in connection with the
Mergers.
One of the conditions to consummating the Mergers is that no injunction, order or decree prohibiting or otherwise preventing or making
unlawful the consummation of the Mergers will have been issued by any court or governmental entity of competent jurisdiction in the United States.
Consequently, if any lawsuit is filed challenging the Mergers and is successful in obtaining an injunction preventing the parties to the merger
agreement from consummating the Mergers, such injunction may prevent the Mergers from being completed in the expected timeframe, or at all.
Failure to complete the Mergers could negatively affect the per unit price of our common units and our future business and financial results.
If the Mergers are not completed, our ongoing business may be adversely affected and we will be subject to several risks and
consequences, including the following:
under the merger agreement, we may be required, under certain circumstances, to pay Kodiak a breakup fee of $15 million;
•
• we will be required to pay certain costs relating to the Mergers, whether or not the Mergers are completed, such as legal, accounting,
•
financial advisor and printing fees;
under the merger agreement, we are subject to certain restrictions on the conduct of its business prior to completing the Mergers without
Kodiak’s consent, which may adversely affect our ability to execute certain of our business strategies; and
• matters relating to the Mergers may require substantial commitments of time and resources by our general partner’s management, which
could otherwise have been devoted to other opportunities that may have been beneficial to the Partnership as an independent company.
In addition, if the Mergers are not completed, we may experience negative reactions from the financial markets, including negative impacts
on the market price of our common units, and from our customers, employees, vendors, business partners and other third parties. We also could be
subject to litigation related to any failure to complete the Mergers or to enforcement proceedings commenced against us to attempt to force us to
perform our obligations under the merger agreement.
10
Certain Business Risks
Although it is not possible to identify all of the risks we encounter, we have identified the following significant risk factors that could affect our
actual results and cause actual results to differ materially from any such results that might be projected, forecasted, or estimated by us in this
Annual Report.
We depend on demand for and production of oil and natural gas, and a reduction in this demand or production could adversely affect the demand or
the prices we charge for our services, which could cause our revenue and cash available for distribution to our unitholders to decrease.
Our operations are significantly dependent upon the demand for, and production of, oil and natural gas in the various U.S. and international
markets in which we operate. Oil and natural gas production rates are volatile and may be affected by, among other factors, prices for such
commodities, market uncertainty, weather and availability of alternative energy sources.
Oil prices averaged 18% lower in 2023 compared to 2022. This was due to global markets adjusting to new trade dynamics, with crude oil from
Russia finding destinations outside the European Union (the “EU”) after the EU import ban on Russia’s crude oil and products, and global crude oil
demand falling short of expectations. These dynamics offset the impacts from OPEC crude oil production cuts in the second half of the year. West
Texas Intermediate oil prices reached a high of $93.67 per barrel in September 2023 and a low of $66.61 per barrel in March 2023. The West Texas
Intermediate price averaged $77.58 per barrel during 2023. Over this same period, U.S. natural gas prices averaged 61% lower in 2023 compared
to 2022. Record-high natural gas production, flat consumption and rising natural gas inventories contributed to these lower prices. Warmer-than-
average temperatures in January and February 2023 led to the lowest U.S. natural gas consumption for these months in seven years. The Henry
Hub price ranged from a high of $3.78 per million British thermal units ("MMBtu") in January 2023 to a low of $1.74 per MMBtu in June 2023. The
Henry Hub price averaged $2.53 per MMBtu during 2023. As of February 26, 2024, the price of West Texas Intermediate oil was $78.53 per barrel
and the Henry Hub price for natural gas was $1.65 per MMBtu. If oil and natural gas prices decline significantly, there could be a material adverse
effect on our business, consolidated results of operations, and consolidated financial condition.
Factors affecting the prices of oil and natural gas include: the levels of supply and demand for oil and natural gas, worldwide; governmental
regulations, including the policies of governments regarding the exploration for and production and development of their oil and natural gas
reserves; weather conditions, natural disasters, and health or similar issues, such as pandemics or epidemics; worldwide political, military, and
economic conditions; the ability or willingness of the Organization of Petroleum Exporting Countries ("OPEC") and non-OPEC countries, such as
Russia, to set and maintain oil production levels; the levels of oil production in the U.S. and by other non-OPEC countries; oil refining capacity and
shifts in end-customer preferences toward fuel efficiency and the use of natural gas; the cost of producing and delivering oil and natural gas; and
acceleration of the development of, and demand for, alternative energy sources.
The COVID-19 pandemic has had, or may in the future have, certain negative impacts on our business, and such impacts have had, or may in the
future have, an adverse effect on our business, our financial condition, results of operations, or liquidity.
During the first half of 2021, the COVID-19 pandemic and the resulting economic impact had a significant negative impact on the oil and gas
industry. The deterioration in demand for oil caused by the pandemic, coupled with oil oversupply had an adverse impact on the demand for our
services. Although global demand for oil and natural gas began to rebound in 2021 and has remained relatively steady throughout 2022 and 2023,
any future pandemic, and the resulting actions that may be taken by governments, various regulatory agencies, our customers and our suppliers
could have certain negative impacts on our financial condition, results of operations, and liquidity. In addition, the impact of COVID-19 in China
continues to impact the global demand for oil and gas.
11
Continuing or worsening inflationary issues and associated changes in monetary policy have resulted in and may result in additional increases in
the cost of our goods, services and labor, which in turn may cause our capital expenditures and operating costs to rise.
Inflationary pressures have resulted in and may result in additional increases to the costs of our goods, services and labor, which in turn has
caused and may cause our capital expenditures and operating costs to rise. Due to high levels of high inflation in the U.S., the U.S. Federal
Reserve and other central banks increased interest rates multiple times in 2022 and 2023, and although the U.S. Federal Reserve has indicated
that such increases have ceased going into 2024, uncertainty remains as to when or if such elevated rates may be decreased. To the extent that
rates remain high, this could have the effects of raising the cost of capital and depressing economic growth, either of which—or the combination
thereof—could negatively impact the financial and operating results of our business. To the extent elevated inflation remains, we may experience
additional cost increases for our operations, including services, labor costs and equipment if our operating activity increases.
Higher oil and natural gas prices may cause the costs of materials and services to continue to rise. We cannot predict any future trends in
the rate of inflation and a significant increase in inflation, to the extent we are unable to recover higher costs through higher prices and revenues,
would negatively impact our business, financial condition and results of operations.
We may be unable to repurchase our 7.50% First Lien Notes due 2025 and 10.000%/10.750% Second Lien Notes due 2026 in the event of
a change of control as required by their respective indentures.
Holders of our 7.50% First Lien Notes due 2025 (the “First Lien Notes”) and 10.000%/10.750% Second Lien Notes due 2026 (the “Second Lien
Notes,” collectively with First Lien Notes, “Notes”) have the right to require us to repurchase their notes at a price equal to 101% of the principal
amount, in each case, upon the occurrence of any specified change of control event.
Any change of control also would constitute a default under our Credit Agreement (as defined below) and the Spartan Credit Agreement (as
defined below). Therefore, upon the occurrence of a change of control, the lenders under each of our Credit Agreement and Spartan Credit
Agreement would have the right to accelerate the payment obligations with respect to our Credit Agreement and the Spartan Credit Agreement,
respectively, and if so accelerated, we would be required to pay all of our outstanding obligations under our Credit Agreement and the Spartan
Credit Agreement. In the event that our Credit Agreement and the Spartan Credit Agreement are not paid off or otherwise terminated
contemporaneously therewith, the consummation of the transactions under the Merger Agreement would result in a change of control under each of
the Credit Agreement and the Spartan Credit Agreement, which would constitute a default under such agreement. We may not be able to repay or
repurchase our First Lien Notes and Second Lien Notes at that time because we may not have available funds to repay the debt or pay the
repurchase price as applicable. Any requirement to repay or to offer to purchase any outstanding First Lien Notes and Second Lien Notes may
result in us having to refinance our outstanding indebtedness, which we may not be able to do. In addition, even if we were able to refinance our
outstanding indebtedness, such financing may be on terms unfavorable to us. A change of control under the indentures governing our First Lien
Notes and Second Lien Notes could have a material adverse effect on our business, results of operations, and financial condition.
Our current capital structure, along with current debt and equity market conditions, may continue to limit our ability to obtain financing to pursue
business growth opportunities.
Conditions in the markets for debt and equity securities in the energy sector have increased the difficulty of obtaining debt and equity
financing to grow our business. We expect that the stock market volatility, which started in March 2020 and continued throughout 2021, 2022 and
into 2023, may make it more difficult to obtain debt and equity financing in the near future. As of December 29, 2023, the market price for our
common units was $1.63 per common unit, down from the 2023 high of $1.97 per common unit. The closing price of our common units was $1.97
as of February 28, 2024. The issuance of new common units or debt convertible into common units in the future, could be significantly dilutive to
current common unitholders. In addition, as of December 31, 2023, we had approximately $629.5 million aggregate principal amount of debt
outstanding, including borrowings under our credit agreements, the First Lien Notes and the Second Lien Notes. Obtaining equity or debt financing
in the current market environment is particularly difficult for us, given our current levels of long-term debt.
12
During the year ended December 31, 2023, our aggregate capital expenditures totaled $57.9 million, which were primarily growth capital
expenditures to increase our compression services equipment fleet. The majority of these capital expenditures were funded from our operating
cash. As of December 31, 2023, our total cash balance was $7.0 million. We expect capital expenditures in 2024 to range from $52.0 million to
$69.0 million. These capital expenditures include approximately $20.0 million to $27.5 million of maintenance capital expenditures, approximately
$30.0 million to $37.5 million of capital expenditures primarily associated with the expansion of our contract services fleet, and $2.0 million to $4.0
million of capital expenditures related to investments in technology and facilities. We will continue to monitor such estimates going forward. We
expect that the combination of $7.0 million of cash on hand at the beginning of 2024 and operating cash flows expected to be generated during the
year will be sufficient to fund these capital expenditures without having to incur additional long-term debt and without having to access the equity
markets. While we do not expect to have to incur additional long-term debt, we may elect to enter into capital lease transactions and/or raise
additional equity. However, our ability to grow our business through capital expenditures or acquisitions beyond these sources of financing may be
significantly limited or curtailed. Without the ability to increase our compression equipment fleet or otherwise grow our operations, our ability to
continue to retain customers whose compression services needs are expanding and to increase distributions to our common unitholders in the
future may be limited.
Our long-term debt levels result in a significant amount of our operating cash flows being used to fund debt service requirements.
The aggregate carrying value of our First Lien Notes and Second Lien Notes as of December 31, 2023 are $400.1 million and $172.6 million,
respectively. In addition, we have an aggregate collective carrying value of $46.5 million outstanding on our Spartan Credit Agreement and our CSI
Credit Agreement as of December 31, 2023. The interest expense related to our long-term indebtedness reduces our cash available to fund capital
expenditures or for distribution. Our ability to service our indebtedness in the future will depend upon, among other things, our future financial and
operating performance, which will be impacted by prevailing economic conditions and financial, business, regulatory and other factors, many of
which are beyond our control. If our operating results are not sufficient to service our current or future indebtedness, we may be forced to consider
taking actions such as reducing or delaying our business activities, acquisitions, investments and/or capital expenditures, delaying any desired
increase of distributions, selling assets, restructuring or refinancing our indebtedness, or seeking additional equity capital or bankruptcy protection.
We may not be able to take any of these courses of action.
We may not have sufficient cash from operations following the establishment of cash reserves and payment of debt service and other contractual
obligations, fees and expenses, including cost reimbursements to our general partner, to enable us to increase cash distributions to our common
unitholders.
Beginning with the first quarter of 2019, our common unit distributions decreased from $0.75 per unit per year (or $0.1875 per quarter) to $0.04
per unit per year (or $0.01 per quarter). Our Second Lien Notes indenture further restricts our ability to make distributions in respect of our common
units in any amount exceeding $0.04 per common unit per year, unless such increased distribution is funded by proceeds from an equity offering.
Under the terms of our partnership agreement, the amount of cash otherwise available for distribution is reduced by our operating expenses and the
amount of cash reserves that our general partner establishes to provide for future operations, future capital expenditures, future debt service
requirements, and future cash distributions to our common unitholders. In order to make cash distributions at this current distribution rate of $0.01
per common unit per quarter, or $0.04 per common unit per year, we will require available cash of approximately $1.4 million per quarter, or $5.7
million per year, based on the number of common units outstanding as of February 28, 2024. We may not have sufficient available cash each
quarter to enable us to increase cash distributions or make any distribution at all. To the extent we issue additional partnership units in connection
with our growth, the payment of distributions on those additional partnership units may further increase the risk that we will be unable to increase
our per-unit distribution. There are no limitations in our partnership agreement or Credit Agreement on our ability to issue additional common units.
The amount of cash we can distribute to our common unitholders principally depends upon the amount of cash we generate from our operations,
which fluctuates from quarter to quarter based on, among other things, the market conditions described in these “Risk Factors.”
Many of our operating expenses have been volatile and may continue to be volatile or increase in the future. To the extent our efforts to contain
these costs are not successful, our generation of operating cash flows to fund or increase our quarterly distributions will be negatively impacted.
13
Our long-term debt agreements contain covenants and other provisions that restrict our ability to take certain actions and may limit our ability to
grow our business in the future.
Our Credit Agreement includes a maximum credit commitment of $35.0 million, which is available for loans, letters of credit (with a sublimit of
$25.0 million), and swingline loans (with a sublimit of $3.0 million), subject to a borrowing base determined by reference to the value of certain of
our accounts receivable and inventory. We are required to maintain a $3.5 million reserve with respect to the borrowing base, which results in
reduced liquidity. The maximum credit commitment may be increased by $25.0 million, subject to the terms and conditions of the Credit Agreement.
The Credit Agreement contains certain affirmative and negative covenants, including covenants that restrict our ability to take certain actions
including, among other things and subject to certain significant exceptions, incurring debt, granting liens, making investments, entering into or
amending existing transactions with affiliates, paying dividends, and selling assets.
The Spartan Credit Agreement includes a maximum credit commitment of $70.0 million, which is available for loans, letters of credit (with a
sublimit of $5.0 million), and swingline loans (with a sublimit of $7.0 million), subject to a borrowing base determined by reference to the value of
certain of our accounts receivable and inventory. The maximum credit commitment may be increased by $30.0 million, subject to the terms and
conditions of the Spartan Credit Agreement. The Spartan Credit Agreement contains certain affirmative and negative covenants, including
covenants that restrict our ability to take certain actions including, among other things and subject to certain significant exceptions, incurring debt,
granting liens, making investments, entering into or amending existing transactions with affiliates, paying dividends, and selling assets.
In addition, the indentures governing our First Lien Notes and Second Lien Notes contain customary covenants restricting our ability and the
ability of our restricted subsidiaries to: (i) pay distributions on, purchase, or redeem our common units, make certain investments and other
restricted payments, or purchase or redeem any subordinated debt; (ii) incur or guarantee additional indebtedness or issue certain kinds of
preferred equity securities; (iii) create or incur certain liens securing indebtedness; (iv) sell assets, including dispositions of the collateral securing
our First Lien Notes and Second Lien Notes; (v) consolidate, merge, or transfer all or substantially all of our assets; (vi) enter into transactions with
affiliates; and (vii) enter into agreements that restrict distributions or other payments from our restricted subsidiaries to us. Our Second Lien Notes
indenture further restricts our ability to make distributions in respect of our common units in any amount exceeding $0.04 per common unit per year,
unless such increased distribution is funded by proceeds from an equity offering. These covenants are subject to a number of important limitations
and exceptions, including certain provisions permitting us, subject to the satisfaction of certain conditions, to transfer assets to certain of our
unrestricted subsidiaries. The indentures also contain customary events of default and acceleration provisions relating to events of default, which
provide that upon an event of default under the indentures, the Trustee or the holders of at least 25% in aggregate principal amount of the then
outstanding First Lien Notes and Second Lien Notes may declare all of the First Lien Notes and Second Lien Notes to be due and payable
immediately.
The loss of any of our most significant customers would result in a decline in our revenue and cash available to pay distributions to our common
unitholders.
Our five most significant customers collectively accounted for approximately 31% of our 2023 revenues. Our services and products are
provided to these customers pursuant to short-term contract compression services agreements, many of which are cancellable with 30 days’ notice.
The loss of all or even a portion of the services we provide to these customers, as a result of competition or otherwise, could have a material
adverse effect on our business, results of operations, financial condition, and our ability to make cash distributions to our unitholders.
The credit and risk profile of Spartan could adversely affect our business and our ability to make distributions to our common unitholders.
The credit and business risk profile of Spartan could adversely affect our ability to incur indebtedness in the future or obtain a credit rating, as
credit rating agencies may consider the leverage and credit profile of Spartan and its affiliates in assigning a rating because of Spartan’s control of
us, their performance of certain administrative functions for us, and our contractual relationships with them. Furthermore, the trading price of our
common units may be adversely affected by financial or operational difficulties or excessive debt levels at Spartan. If the pledge of Spartan
ownership of our general partner becomes effective in the future, control over our general partner could be transferred to Spartan’s lenders in the
event of a default by Spartan.
14
Our ability to manage and grow our business effectively and provide quality services to our customers may be adversely affected if our general
partner loses its management or is unable to retain trained personnel.
We rely primarily on the executive officers and other senior management of our general partner and Spartan to manage our operations and
make decisions on our behalf. Our ability to provide quality compression services depends to a significant extent upon our general partner’s and
Spartan’s ability to hire, train, and retain an adequate number of trained personnel. The departure of any of our general partner’s executive officers
or other senior management could have a significant negative effect on our business, operating results, financial condition, and our ability to
compete effectively in the marketplace. In connection with Spartan’s acquisition of our general partner, most of our general partner’s executive
officers and other senior management resigned their positions, and Spartan appointed new officers in their place. Such significant turnover in
management of our general partner could have negative impact on our business. We operate in an industry characterized by highly competitive
labor markets, and, similar to many of our competitors, we have experienced high employee turnover in certain regions. It is possible that our labor
expenses could increase if there is a shortage in the supply of skilled regional service supervisors and other service professionals. Our general
partner may be unable to maintain an adequate skilled labor force necessary for us to operate efficiently and to support our growth strategy. Failure
to do so could impair our ability to operate efficiently and to retain current customers and attract prospective customers, which could cause our
business to suffer materially. Additionally, increases in labor expenses may have an adverse impact on our operating results and may reduce the
amount of cash available for distribution to our common unitholders.
Further changes in the economic environment, including any future supply disruptions, could result in further significant impairments of certain of our
long-lived assets.
Beginning in 2020 and continuing into 2021, decreased commodity prices had a negative impact on oil and gas drilling and capital expenditure
activity, which affected the demand for a portion of our products and services. In the latter half of 2021 and through 2022 and 2023, the prices of
and demand for oil and natural gas began to recover to prior levels. If prices or demand levels begin to decline again, demand for our products and
services may significantly decrease, which could impact the expected utilization rates of our compressor package fleet.
Although equipment used in providing services to our customers is normally readily available, market conditions could trigger constraints in the
supply chain of certain equipment, and replacement parts for such equipment, used in providing services to our customers. If we experience future
supply chain disruptions, it could also impact the expected utilization rate of our compressor package fleet.
Under U.S. GAAP, we review the carrying value of our long-lived assets when events or changes in circumstances indicate that the carrying
value of these assets may not be recoverable, based on their expected future cash flows. The impact of reduced expected future cash flow could
require the write-down of all or a portion of the carrying value for these assets, which would result in impairments, resulting in decreased earnings.
We do not insure against all potential losses and could be seriously harmed by unexpected liabilities.
Our assets and operations are subject to inherent risks such as vehicle accidents, equipment defects, malfunctions and failures, as well as
other incidents that result in releases or uncontrolled flows of gas or well fluids, fires, or explosions. These risks could expose us to substantial
liability for personal injury, death, property damage, pollution, and other environmental damages. On occasion, we have experienced fires that have
damaged or destroyed certain units in our compression services fleet, and additional accidents or fires could occur in the future. We do not insure
all of our assets and the insurance we do obtain may be inadequate to cover our liabilities. Further, insurance covering the risks we face or in the
amounts we desire may not be available in the future, or, if available, the premiums may not be commercially feasible. If we were to incur
substantial liability and such damages were not covered by insurance or were in excess of policy limits, or if we were to incur liability at a time when
we did not maintain liability insurance, our business, results of operations, and financial condition could be adversely affected. In addition, our
business interruption insurance does not cover all potential losses. Please read “Health, Safety, and Environmental Affairs Regulations” for a
description of how we are subject to federal, state, and local laws and regulations governing the discharge of materials into the environment or
otherwise relating to protection of human health and environment.
15
Our sales to and operations in non-U.S. markets exposes us to additional risks and uncertainties, including with respect to U.S. trade and economic
sanctions, export control laws, and the Foreign Corrupt Practices Act
(“FCPA”), and similar anti-bribery laws. If we are not in compliance with applicable legal requirements, we may be subject to civil or criminal
penalties and other remedial measures that could have a material impact on our business.
We have operations in Mexico, Canada, Argentina and Chile as well as a number of other non-U.S. markets. A portion of our expected future
growth could include expansion in these and other non-U.S. markets. Non-U.S. operations carry special risks. Our operations in the countries in
which we currently operate and those countries in which we may operate in the future, could be adversely affected by:
•
•
•
•
•
•
•
•
government controls and actions, such as expropriation of assets and changes in legal and regulatory environments;
import and export license requirements;
political, social, or economic instability;
trade restrictions;
changes in tariffs and taxes;
currency exposure;
restrictions on repatriating foreign profits back to the United States; and
the impact of anti-corruption laws.
Sanctions imposed by the U.S. Office of Foreign Assets Control (“OFAC”) prohibit our operations in or sales to customers in certain non-U.S.
markets. We are also subject to the FCPA, which prohibits U.S. companies and their intermediaries from bribing overseas officials for the purpose of
obtaining or keeping business or otherwise obtaining favorable treatment, and other similar laws governing our foreign operations. The FCPA’s non-
U.S. counterparts, including the UK Bribery Act, contain similar prohibitions, although varying in both scope and jurisdiction. We operate in parts of
the world that have experienced governmental corruption in the past.
We have policies and procedures to maintain our compliance with the FCPA, OFAC sanctions, export controls, and similar laws and regulations.
The implementation of such policies and procedures may be time consuming and expensive and could result in the discovery of issues or violations
with respect to the foregoing by us or our employees, independent contractors, subcontractors, or agents of which we were previously unaware. If
we violate any of these regulations, significant administrative, civil, and criminal penalties could be assessed on us. In addition, foreign governments
and agencies often establish permit and regulatory standards different from those in the U.S. If we cannot obtain foreign regulatory approvals or
cannot obtain them in a timely manner, our growth and profitability from international operations could be adversely affected.
Security disruptions in regions of Mexico served by us could adversely affect our Mexican operations, and, as a result, the levels of revenue and
operating cash flow from our Mexican operations could be reduced.
In recent years, incidents of security disruptions throughout many regions of Mexico have increased. Drug-related gang activity has grown in
Mexico. Certain incidents of violence have occurred in regions in which we operate and have resulted in the interruption of our operations, and
these interruptions could increase in the future. To the extent that such security disruptions increase, the levels of revenue and operating cash flow
from our Mexican operations could be reduced.
Our operations in Argentina and Chile expose us to the changing economic, legal, and political environment in those countries, including changing
regulations governing the repatriation of cash generated from our operations in Argentina.
The current economic, legal, and political environment in Argentina and the recent devaluations of the Argentine peso have created increased
instability for foreign investment in Argentina. The Argentine government is currently attempting to address the current high rate of inflation and the
continuing currency devaluation pressure. Fiscal and monetary expansion in Argentina has led to devaluations of the Argentine peso. Additional
devaluation may be necessary to help boost the current Argentina economy, and they may be accompanied by fiscal and monetary tightening,
including additional restrictions on the transfer of U.S. dollars out of Argentina. On June 30, 2018, we determined the economy in Argentina to be
highly inflationary. As a result of this determination and in accordance with U.S. generally accepted accounting principles ("GAAP"), on July 1, 2018,
the functional currency of
16
our operations in Argentina was changed from the Argentine peso to the U.S. dollar. The remeasurement did not have a material impact on our
consolidated financial position or results of operations.
As a result of our operations in Argentina, consolidated revenues and operating cash flow generated in Argentina have experienced growth over
the past five years. The process of repatriating this cash to the U.S. is subject to increasingly complex regulations. There can be no assurances that
our growing Argentine operations will not expose us to the loss of liquidity, foreign exchange losses, and other potential financial impacts.
The Chilean government is currently attempting to address the current high rate of inflation and the continuing currency devaluation
pressure. The government has raised borrowing costs, higher commodity prices are keeping consumer prices under pressure and the central bank
has begun to withdraw monetary stimulus by raising the benchmark interest rate.
The employees conducting our operations in Mexico and Argentina are party to collective labor agreements, and a prolonged work stoppage of our
operations in Mexico or Argentina could adversely impact our revenues, cash flows and net income.
The personnel conducting our operations in Mexico are currently subject to collective labor agreements. These collective labor agreements
consist of “evergreen” contracts that have no expiration date and whose terms remain in full force and effect from year-to-year, unless the parties
agree to negotiate new terms. The employees subject to these “evergreen” agreements may, however, request a renegotiation of their employee
compensation terms on an annual basis or a renegotiation of the entire agreement on a biannual basis, although we are not required to honor any
such request. The personnel conducting operations in Argentina are also subject to collective labor agreements. We have not experienced work
stoppages in Mexico or Argentina in the past but cannot guarantee that we will not experience work stoppages in the future. A prolonged work
stoppage could adversely impact our revenues, cash flows, and net income. Mexico’s Federal Labor Law was reformed effective August 1, 2021, in
relation to labor subcontracting which resulted in an increase in statutory profit sharing.
A terrorist attack, armed conflict or political or civil unrest could harm our business.
Terrorist activities, anti‑terrorist efforts, war and other armed conflicts and political or civil unrest could adversely affect the U.S. and global
economies and could prevent us from meeting financial and other obligations. We could experience loss of business, delays or defaults in payments
from payors or disruptions of fuel supplies and markets if pipelines, production facilities, processing plants, refineries or transportation facilities are
direct targets or indirect casualties of an act of terror or war. Such activities could reduce the overall demand for oil and natural gas, which, in turn,
could also reduce the demand for our services. War and other armed conflicts, including conflict related to Russia’s invasion of Ukraine, the conflict
between Israel and Hamas, and regional conflict in the Middle-East and any resulting economic downturn could adversely affect our results of
operations, impair our ability to raise capital or otherwise adversely impact our ability to realize certain business strategies. In addition, sanctions
imposed on foreign countries by the U.S. or other foreign governments could adversely affect our results of operations, impair our ability to raise
capital or otherwise adversely impact our ability to realize certain business strategies.
Our exposure to currency exchange rate fluctuations may result in fluctuations in our cash flows and could have an adverse effect on our results of
operations.
Because we have operations in Mexico, Canada, Argentina and Chile, and in certain other non-U.S. jurisdictions, a portion of our business is
conducted in foreign currencies. As a result, we are exposed to currency exchange rate fluctuations that could have an adverse effect on our results
of operations. If a foreign currency weakened significantly, we would be required to convert more of that foreign currency to U.S. dollars to satisfy
our obligations, which would cause us to have less cash available for distribution. A significant strengthening of the U.S. dollar could result in an
increase in our financing expenses and could materially affect our financial results under U.S. GAAP. Because we report our operating results in
U.S. dollars, changes in the value of the U.S. dollar also result in fluctuations in our reported revenues and earnings. Most of our billings under the
contracts with PEMEX and other clients in Mexico are in U.S. dollars; however, a large portion of our expenses and costs under those contracts are
incurred in Mexican pesos. In addition, future contract awards with PEMEX may require us to bill a larger portion of our revenues in Mexican pesos,
which would expose us to additional foreign currency exchange rate risks.
17
As a result of the above, we are exposed to fluctuations in the values of the Mexican peso, Argentine peso and Chilean peso against the U.S.
dollar. A material increase in the values of these foreign currencies relative to the U.S. dollar would adversely affect our cash flows and net income.
On June 30, 2018, we determined the economy in Argentina to be highly inflationary. As a result of this determination and in accordance with U.S.
GAAP, on July 1, 2018, the functional currency of our operations in Argentina was changed from the Argentine peso to the U.S. dollar. In addition,
for our operations in Canada, where the Canadian dollar is the functional currency under U.S. GAAP, all U.S. dollar-denominated monetary assets
and liabilities, such as cash and cash equivalents, accounts receivable, restricted cash, accounts payable, long-term debt and capital lease
obligations, are revalued and reported based on the prevailing exchange rate at the end of the reporting period. This revaluation may cause us to
report significant foreign currency exchange gains and losses in certain periods.
Environmental and Technology Risks
We are subject to environmental regulations, and changes in these regulations could increase our costs or liabilities.
We are subject to federal, state, local, and foreign laws and regulatory standards, including laws and regulations regarding the discharge of
materials into the environment, emission controls, and other environmental protection and occupational health and safety concerns. Environmental
laws and regulations may, in certain circumstances, impose strict and joint and several liability for environmental contamination, rendering us liable
for remediation costs, natural resource damages, and other damages resulting from our ownership of property or conduct that was lawful at the time
it occurred or the conduct of, or conditions caused by, prior owners or operators or other third parties. 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. Remediation costs and other damages arising as a result of environmental laws and regulations, and costs associated with new
information, changes in existing environmental laws and regulations or the adoption of new environmental laws and regulations could be substantial
and could adversely affect our financial condition or results of operations. Moreover, failure to comply with these environmental laws and regulations
may result in the imposition of administrative, civil and criminal penalties, and the issuance of injunctions delaying or prohibiting operations.
We routinely deal with natural gas, oil, and other petroleum products. Hydrocarbons or other hazardous wastes may have been released during
our operations or by third parties on wellhead sites where we provide services or store our equipment or on or under other locations where wastes
have been taken for disposal. These properties may be subject to investigatory, remediation, and monitoring requirements under foreign, federal,
state, and local environmental laws and regulations.
The modification or interpretation of existing environmental laws or regulations, the more vigorous enforcement of existing environmental laws or
regulations, or the adoption of new environmental laws or regulations may also adversely affect oil and natural gas exploration and production,
which in turn could have an adverse effect on us.
Climate change legislation or regulations restricting emissions of GHGs could result in increased operating costs and reduced demand for the oil
and natural gas our customers produce, while the physical effects of climate change could disrupt production and cause us to incur costs in
preparing for or responding to those effects.
The EPA has adopted regulations to restrict emissions of GHGs under existing provisions of the CAA. Such EPA rules regulate GHG emissions
under the CAA and require a reduction in emissions of GHGs from motor vehicles and from certain large stationary sources. For example, the EPA
published final rules in June 2016 that require the reduction of volatile organic compounds and methane emissions from certain hydraulically
fractured natural gas wells and further require that most wells use so-called “green” completions at certain hydraulically fractured natural gas wells.
These regulations also established new requirements regarding emissions from production-related wet seal and reciprocating compressors, and
from pneumatic controllers and storage vessels. Certain of our compressor packages are subject to these requirements and additional control
equipment and maintenance operations are required. In December 2023, the EPA finalized more stringent methane rules for new, modified, and
reconstructed facilities, known as OOOOb, as well as standards for existing sources, known as OOOOc. Under the final rules, states have two
years to prepare and submit their plans to impose methane emissions controls on existing sources. The presumptive standards established under
the final rule are generally the same for both new and existing sources and include enhanced leak detection survey requirements using optical
18
gas imaging and other advanced monitoring to encourage the deployment of innovative technologies to detect and reduce methane emissions,
reduction of emissions by 95% through capture and control systems, zero-emission requirements for certain devices, and the establishment of a
“super emitter” response program that would allow third parties to make reports to EPA of large methane emission events, triggering certain
investigation and repair requirements. Fines and penalties for violations of these rules can be substantial. It is likely, however, that the final rule and
its requirements will be subject to legal challenges. In addition, the EPA requires the annual reporting of GHG emissions from specified large GHG
emission sources in the U.S., including petroleum refineries, as well as from certain oil and gas production facilities. The requirements of the EPA’s
final methane rules and other rules and regulations regarding GHG emissions could accelerate the transition away from fossil fuels, which could in
turn reduce the demand for our services.
In addition, in December 2015, over 190 countries, including the U.S., reached an agreement to reduce global GHG emissions (the “Paris
Agreement”). The Paris Agreement entered into force in November 2016 after more than 170 nations, including the U.S., ratified or otherwise
indicated their intent to be bound by the Paris Agreement. Although the U.S. withdrew from the Paris Agreement in November 2020, President
Biden recommitted the United States in February 2021, and, in April 2021, announced a new, more rigorous nationally determined emissions
reduction level of 50-52% reduction from 2005 levels in economy-wide net GHG emissions by 2030. The international community gathered in
Glasgow in November 2021 at the 26th Conference to the Parties (“COP26”) during which multiple announcements were made, including a call for
parties to eliminate fossil fuel subsidies, amongst other measures. Relatedly, the United States and European Union jointly announced at COP26
the launch of the Global Methane Pledge, an initiative committing to a collective goal of reducing global methane emissions by at least 30% from
2020 levels by 2030, including “all feasible reductions” in the energy sector. In December 2023, the United Arab Emirates hosted the 28th
Conference to the Parties (“COP28”) where parties signed onto an agreement to transition “away from fossil fuels in energy systems in a just,
orderly, and equitable manner” and increase renewable energy capacity so as to achieve net zero by 2050, although no timeline for doing so was
set. The full impact of these actions is uncertain at this time, and it is unclear what additional initiatives may be adopted or implemented that may
have adverse effects on us and our customers’ operations.
There are also increasing financial risks for fossil fuel producers as stockholders currently invested in fossil-fuel energy companies may
elect in the future to shift some or all of their investments into non-fossil fuel related sectors. Institutional lenders who provide financing to fossil fuel
energy 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. For example, at COP26, the Glasgow Financial Alliance for Net Zero (“GFANZ”) announced that commitments from over
450 firms across 45 countries had resulted in over $130 trillion in capital committed to net zero goals. The various sub-alliances of GFANZ generally
require participants to set short-term, sector-specific targets to transition their financing, investing, and/or underwriting activities to net zero
emissions by 2050. There is also a risk that financial institutions will be required to adopt policies that have the effect of reducing the funding
provided to the fossil fuel sector. For example, in late October 2023, the Federal Reserve, Office of the Comptroller of the Currency and the Federal
Deposit Insurance Corp. released a finalized set of principles guiding financial institutions with $100 billion or more in assets on the management of
physical and transition risks associated with climate change. Although we cannot predict the effect of these various actions, such limitation of
investments in and financing for fossil fuel energy companies could adversely impact our customers and, therefore, our operations. Additionally, the
SEC published a proposed rule that would require climate disclosures from registrants, include data on Scope 1 and Scope 2 GHG emissions and,
in some cases, Scope 3. Although the final form and substance of these requirements is not yet known, this may result in additional costs to comply
with any such disclosure requirements. Relatedly, California has enacted new laws requiring additional disclosure with respect to certain climate-
related risks and GHG emission reduction claims. Other states are consisting similar laws. We cannot predict how financial institutions and investors
might consider information disclosed under any such rules as these, and it is possible that as a result we could face increases with respect to the
costs of, or restrictions imposed on, our access to capital. Additionally, any new laws or regulations imposing more stringent requirements on our
business related to disclosure of climate-related risks may result in reputation harms.
President Biden has also issued executive orders that commit to substantial action on climate change, calling for, among other things, the
increased use of zero-emissions vehicles by the federal government, the elimination of subsidies provided to the fossil fuel industry, and an
increased emphasis on climate-related risk across government agencies and economic sectors. The adoption and implementation of any
regulations imposing reporting obligations on, or limiting emissions of GHGs from, our facilities and operations could require us to incur costs.
Further, Congress has considered and almost one-half of the states have adopted legislation that seeks to
19
control or reduce emissions of GHGs from a wide range of sources and has passed laws such as the IRA 2022 that advance numerous climate-
related activities. Any such legislation could adversely affect demand for the oil and natural gas our customers produce and, in turn, demand for our
products and services. Litigation risks are also increasing as a number of parties have sought to bring suit against certain oil and natural gas
companies in state or federal court, alleging among other things, that such companies created public nuisances by producing fuels that contributed
to climate change or alleging that the companies have been aware of the adverse effects of climate change for some time, but defrauded their
investors or customers by failing to adequately disclose those impacts.
Finally, it should be noted that increasing concentrations of GHGs in the Earth’s atmosphere may produce climate changes that have
significant physical effects, such as the increased frequency or intensity of extreme weather events or changes in meteorological and hydrological
patterns, which could adversely impact our operations. Such physical risks may result in damage to our customers’ facilities and otherwise
adversely impact their operations, such as if they become subject to water use curtailments in response to drought, or demand for their products,
such as to the extent warmer winters reduce the demand for energy for heating purposes. If any such effects were to occur, they could have an
adverse effect on our operations and cause us to incur costs in preparing for or responding to those effects.
Regulatory initiatives related to hydraulic fracturing in the countries where we and our customers operate could result in operating restrictions or
delays in the completion of oil and gas wells that may reduce demand for our services.
Although we do not directly engage in hydraulic fracturing, our operations support many of our exploration and production customers in such
activities. The practice continues to be controversial in certain parts of the country, resulting in increased scrutiny and regulation of the hydraulic
fracturing process, including by federal and state agencies and local municipalities.
Hydraulic fracturing typically is regulated by state oil and gas commissions or similar state agencies, but several federal agencies have asserted
regulatory authority over certain aspects of the process. For example, the EPA asserted regulatory authority pursuant to the federal Safe Drinking
Water Act, Underground Injection Control program over hydraulic fracturing activities involving the use of diesel and issued guidance covering such
activities; published final rules under the CAA in 2012 and published additional final regulations in June 2016 governing methane and volatile
organic compound performance standards, including standards for the capture of air emissions released by the oil and natural gas hydraulic
fracturing industry; published in June 2016 an effluent limitations guidelines final rule prohibiting the discharge of waste water from shale natural-gas
extraction operations to a treatment plant; and in 2014 published an Advance Notice of Proposed Rulemaking regarding Toxic Substances Control
Act reporting of the chemical substances and mixtures used in hydraulic fracturing. In 2021, the Biden Administration took multiple actions to pause
new oil and gas leases and drilling permits on non-Indian federal lands and waters for a period of 60 days. In addition, President Biden issued an
executive order on January 27, 2021, that suspended new leasing activities for oil and gas exploration and production on non-Indian federal lands
and offshore waters pending completion of a comprehensive review and reconsideration of federal oil and gas permitting and leasing practices that
take into consideration potential climate and other impacts associated with oil and gas activities on such lands and waters. The suspension of these
federal leasing activities prompted legal action by several states against the Biden Administration resulting in the issuance of a nationwide
permanent injunction by a federal district judge in Louisiana effectively halting implementation of the leasing suspension. Federal oil and gas leasing
has since then resumed, although at a reduced level. Relatedly, the Department of the Interior released its report on federal gas leasing and
permitting practices in November 2021, referencing a number of recommendations and an overarching intent to modernize the federal oil and gas
leasing program, including by adjusting royalty and bonding rates, which have been addressed in the IRA 2022, prioritizing leasing in areas with
known resource potential, and avoiding leasing that conflicts with recreation, wildlife habitat, conservation, and historical and cultural resources.
Additionally, the Bureau of Land Management proposed a rule in November 2022 that would limit flaring from well sites on federal lands, as well as
allow the delay or denial of permits if the Bureau finds that an operator’s methane waste minimization plan is insufficient. A final rule is expected in
2024. Implementation of many of the recommendations in the report will require Congressional action and provisions of the reforms have been
subject to litigation. We cannot predict the extent to which the recommendations may be implemented now or in the future, but restrictions on
federal oil and gas activities have the potential to result in increased costs on our customers, decreased demand for our services on federal lands,
and an adverse impact on our business.
20
The U.S. Congress (“Congress”) has from time to time considered legislation to provide for federal regulation of hydraulic fracturing and to require
disclosure of the chemicals used in the hydraulic fracturing process. At the state level, some states, including Texas, Oklahoma and New Mexico
have adopted, and other states are considering adopting legal requirements that could impose new or more stringent permitting, public disclosure,
or well construction requirements on hydraulic fracturing activities. States could elect to prohibit high volume hydraulic fracturing altogether,
following the approach taken by the State of New York in 2015 and, more recently, California in 2024. Local governments also may seek to adopt
ordinances within their jurisdictions regulating the time, place and manner of drilling activities in general or hydraulic fracturing activities in particular.
If new or more stringent federal, state, or local legal restrictions relating to the hydraulic fracturing process are adopted, our customers could incur
potentially significant added costs to comply with such requirements, experience delays or curtailment in the pursuit of exploration, development or
production activities, and perhaps even be precluded from drilling wells.
Increased regulation and attention given to the hydraulic fracturing process could lead to greater opposition to oil and gas production
activities using hydraulic fracturing techniques. Additional legislation or regulation could also lead to operational delays or increased operating costs
for our customers in the production of oil and gas, including from the developing shale plays, or could make it more difficult to perform hydraulic
fracturing. The adoption of any federal, state or local laws or the implementation of additional regulations regarding hydraulic fracturing could
potentially cause a decrease in the completion of new oil and gas wells and an associated decrease in demand for our services and increased
compliance costs and time, which could have a material adverse effect on our liquidity, consolidated results of operations, and consolidated financial
condition.
Increased attention to Environmental, Social, and Governance (“ESG”) matters and conservation measures may adversely impact our business.
Increasing attention to, and societal expectations on companies to address, climate change and other environmental and social impacts,
investor and societal expectations regarding voluntary ESG disclosures, and consumer demand for alternative forms of energy may result in
increased costs, reduced demand for fossil fuels and, consequently, demand for our services, reduced profits, increased risk of investigation and
litigation, and negative impacts on the value of our services and access to capital. Increasing attention to climate change and environmental
conservation, for example, may result in demand shifts for oil and natural gas products and additional governmental investigations and private
litigation against our customers or us. To the extent that societal pressures or political or other factors are involved, it is possible that such liability
could be imposed without regard to our causation or contribution to the asserted damage, or to other mitigating factors. While we may in the future
participate in various voluntary frameworks and certification programs to improve the ESG profile of our operations and services, we cannot
guarantee that such participation or certification will have the intended results on our ESG profile.
Moreover, while we may create and publish voluntary disclosures regarding ESG matters from time to time, many of the statements in those
voluntary disclosures will be based on hypothetical expectations and assumptions that may or may not be representative of current or actual risks or
events or forecasts of expected risks or events, including the costs associated therewith. Such expectations and assumptions are necessarily
uncertain and may be prone to error or subject to misinterpretation given the long timelines involved and the lack of an established single approach
to identifying, measuring, and reporting on many ESG matters. Additionally, while we may also announce various voluntary ESG targets in the
future, such targets are aspirational. We may not be able to meet such targets in the manner or on such a timeline as initially contemplated,
including, but not limited to as a result of unforeseen costs or technical difficulties associated with achieving such results. To the extent that we do
meet such targets, it may be achieved through various contractual arrangements, including the purchase of various credits or offsets that may be
deemed to mitigate our ESG impact instead of actual changes in our ESG performance. Also, despite these aspirational goals, we may receive
pressure from investors, lenders, or other groups to adopt more aggressive climate or other ESG-related goals, but we cannot guarantee that we
will be able to implement such goals because of potential costs or technical or operational obstacles. Any failure or perceived failure to pursue our
targets, goals and objectives could negatively impact our reputation.
In addition, organizations that provide information to investors on corporate governance and related matters have developed ratings
processes for evaluating companies on their approach to ESG matters. Unfavorable ESG ratings and recent activism directed at shifting funding
away from companies with energy-related assets could lead to increased negative investor sentiment toward us and our industry and to the
diversion of investment to other industries, which could have a negative impact on our access to and costs of capital. Additionally, to the extent ESG
21
matters negatively impact our reputation, we may not be able to compete as effectively to recruit or retain employees, which may adversely affect
our operations. Such ESG matters may also impact our customers, which may adversely impact our business, financial condition, or results of
operations.
Furthermore, public statements with respect to ESG matters, such as emissions reduction goals, other environmental targets or other
commitments addressing certain social issues, are becoming increasingly subject to heightened scrutiny from public and governmental authorities
related to the risk of potential “greenwashing,” i.e., misleading information or false claims overstating potential ESG benefits. For example, in March
2021, the SEC established the Climate and ESG Task Force in the Division of Enforcement to identify and address potential ESG-related
misconduct, including greenwashing. Certain non-governmental organizations and other private actors have also filed lawsuits under various
securities and consumer protection laws alleging that certain ESG-statements, goals or standards were misleading, false or otherwise deceptive. As
a result, we and our customers may face increased litigation risks from private parties and governmental authorities related to ESG efforts.
Additionally, we and our customers could face increasing costs as we attempt to comply with and navigate further regulatory focus and scrutiny.
The Inflation Reduction Act of 2021 could accelerate the transition to a low carbon economy and could impose new costs on our customers’
operations.
In August 2022, President Biden signed the Inflation Reduction Act of 2021 (the “IRA 2022”) into law. The IRA 2022 contains hundreds of
billions in incentives for the development of renewable energy, clean hydrogen, clean fuels, electric vehicles and supporting infrastructure and
carbon capture and sequestration, among other provisions. In addition, the IRA 2022 imposes the first ever federal fee on the emission of
greenhouses gases through a methane emissions charge. The IRA 2022 amends the federal CAA to impose a fee on the emission of methane from
sources required to report their GHG emissions to the EPA, including those sources in the onshore petroleum and natural gas production and
gathering and boosting source categories. The methane emissions charge starts in calendar year 2024 at $900.00 per ton of methane, increases to
$1,200.00 in 2025, and be set at $1,500.00 for 2026 and each year after. Calculation of the fee is based on certain thresholds established in the IRA
2022. Compliance with the EPA’s new, finalized methane rules would exempt an otherwise covered facility from the requirement to pay the fee.
Nevertheless, the methane charge imposed on our oil and gas customers could further accelerate the transition of the economy away from the use
of fossil fuels towards lower- or zero-carbon emissions alternatives. This could decrease demand for oil and gas and consequently adversely affect
the business of our customers, thereby reducing demand for our services.
Our operations and reputation may be impaired if certain information technology systems fail to perform adequately or if we are the subject of a data
breach or cyberattack.
Our information technology systems and operational technology systems are critically important to operating our business efficiently. We rely on
these information technology systems to manage business data, communications, supply chain, customer invoicing, employee information, and
other business processes. We outsource certain business process functions to third-party providers and we rely on these third-parties to maintain
and store confidential information on their systems. The failure of these information technology systems to perform as we anticipate could disrupt
our business and could result in transaction errors, processing inefficiencies, and the loss of sales and customers, causing our business and results
of operations to suffer.
In addition, as a general matter, the frequency and magnitude of cyberattacks is increasing and attackers have become more sophisticated.
Cyberattacks are similarly evolving and include without limitation use of malicious software, surveillance, credential stuffing, spear phishing, social
engineering, use of deepfakes (i.e., highly realistic synthetic media generated by artificial intelligence), attempts to gain unauthorized access to
data, and other electronic security breaches that could lead to disruptions in critical systems, unauthorized release of confidential or otherwise
protected information and corruption of data. The Partnership may be unable to anticipate, detect or prevent future attacks, particularly as the
methodologies used by attackers change frequently or are not recognizable until deployed. We may also be unable to investigate or remediate
incidents as attackers are increasingly using techniques and tools designed to circumvent controls, to avoid detection, and to remove or obfuscate
forensic evidence.
Although we allocate significant resources to protect these information technology and operational technology systems, we have experienced
varying degrees of cyber-incidents in the normal conduct of our business, including viruses, worms, other destructive software, process
breakdowns, phishing and other malicious
22
activities. On January 6, 2020, the Department of Homeland Security issued a public warning that indicated companies in the energy industry might
be specific targets of cybersecurity threats. Such breaches have in the past and could again in the future result in unauthorized access to
information including customer, supplier, employee, or other company confidential data. We are investing in security technology and designing
business processes to attempt to mitigate the risk of such breaches. While we believe these measures are generally effective, there can be no
assurance that security breaches will not occur. Moreover, the development and maintenance of these measures requires continuous monitoring as
technologies change and efforts to overcome security measures evolve. We have experienced and expect to continue to experience, cybersecurity
threats and incidents, none of which has been material to us to date. However, a successful breach or attack could have a material negative impact
on our operations or business reputation and subject us to consequences such as litigation and direct costs associated with incident response and
remediation.
Risks Inherent in an Investment in Us
The market price of our common units has been and may continue to be volatile.
The market price of our common units has fluctuated in the past and is subject to significant fluctuations in response to many factors, some
of which are beyond our control, including the following:
•
•
•
•
•
•
•
•
our operational performance;
supply, demand, and prices of oil and natural gas;
the activity levels of our customers;
deviations in our earnings from publicly disclosed forward-looking guidance or analysts’ projections;
recommendations by research analysts that cover us and other companies in our industry;
risks related to acquisitions and our growth strategy;
uncertainty about current global economic conditions; and
other general economic conditions.
During 2023, the market price for our common units ranged from a high of $1.97 per common unit to a low of $1.06 per common unit. In
recent years, the stock market in general has experienced extreme price and volume fluctuations that have affected the market price for many
companies in industries similar to ours. Some of these fluctuations have been unrelated to operating performance and are attributable, in part, to
outside factors such as the COVID-19 pandemic, the conflict between Russia and Ukraine, or U.S. Federal Reserve policy, and their respective
impacts on the world economy. The volatility of our common units may make it difficult for investors to resell our common units at attractive prices.
If we cannot meet the continued listing requirements of the NASDAQ Stock Market (the “NASDAQ”), the NASDAQ may delist our common units.
The Partnership has been notified by the NASDAQ in the past from time to time that the closing price of the Partnership’s common units over
the prior 30 consecutive trading day period was below $1.00 per unit, which is the minimum closing price per unit required to maintain listing on the
NASDAQ under Rule 5450 (“Rule 5450”). While the Partnership is currently in compliance with Rule 5450, there can be no assurance that the
Partnership will maintain compliance with such rule or the NASDAQ’s other listing rules in the future. On February 28, 2024, the trading price of our
common units closed at $1.97 per unit.
Upon receipt of notice of noncompliance from NASDAQ, the Partnership has a period of six months to regain compliance with Rule 5450,
during which time our common units continue to be listed and traded on the NASDAQ, subject to our compliance with other continued listing
standards. If we fail to regain compliance with Rule 5450 by the end of the cure period, the common units will be subject to the NASDAQ’s
suspension and delisting procedures. If necessary, to regain compliance with NASDAQ listing standards, we may, subject to approval of the board
of directors of our general partner, implement a reverse split of our common units. A delisting of our common units from the NASDAQ could
negatively impact us by, among other things, reducing the liquidity and market price of our common units, reducing the number of investors willing to
hold or acquire our common units, limiting our ability to issue securities or obtain financing in the future, and limiting our ability to use a registration
statement to offer and sell freely tradable securities, thereby restricting our ability to access the public capital markets.
23
Our partnership agreement requires us to distribute all of the available cash that we generate each quarter after paying expenses and establishing
prudent operating reserves, which could limit our ability to grow.
Our partnership agreement requires us to distribute all of the available cash we generate each quarter. Under the terms of our partnership
agreement, the amount of cash otherwise available for distribution will be reduced by our operating expenses and the amount of cash reserves that
our general partner establishes to provide for future operations, future capital expenditures, future debt service requirements and future cash
distributions to our common unitholders. As a result, our general partner relies primarily upon external financing sources, including existing debt
arrangements and the issuance of additional debt and equity securities, as well as cash flows from operations to a certain extent, to fund our
expansion capital expenditures. To the extent that we are unable to finance growth externally, this requirement significantly impairs our ability to
grow. In addition, also as a result of this requirement, our growth may not be as fast as that of businesses that reinvest their available cash to
expand ongoing operations. To the extent that we issue additional units in connection with any expansion of capital expenditures, the payment of
distributions on those additional units may decrease the amount we distribute on each outstanding unit. Our Second Lien Notes indenture further
restricts our ability to make distributions in respect of our common units in any amount exceeding $0.04 per common unit per year, unless such
increased distribution is funded by proceeds from an equity offering. See also “—We may not have sufficient cash from operations following the
establishment of cash reserves and payment of debt service and other contractual obligations, fees and expenses, including cost reimbursements
to our general partner, to enable us to increase cash distributions to our common unitholders.”
Spartan controls our general partner, which has sole responsibility for conducting our business and managing our operations, and thereby controls
us. Spartan has conflicts of interest, which may permit it to favor its own interests to our unitholders’ detriment.
Spartan controls our general partner, and through the general partner controls us. Some of our general partner’s directors are directors or officers
of Spartan or its affiliates that own our general partner. Therefore, conflicts of interest may arise between Spartan and its affiliates, including our
general partner, on the one hand, and us and our common unitholders, on the other hand. In resolving these conflicts of interest, our general
partner may favor its own interests and the interests of Spartan and its affiliates over the interests of our common unitholders. These conflicts
include, among others, the following situations:
•
•
•
•
•
•
•
•
•
•
•
neither our partnership agreement nor any other agreement requires Spartan to pursue a business strategy that favors us. The directors
and officers of Spartan and its affiliates have a fiduciary duty to make these decisions in the best interests of Spartan, which may be
contrary to our interests;
our general partner controls the interpretation and enforcement of contractual obligations between us and our affiliates, on the one hand,
and Spartan, on the other hand, including provisions governing administrative services, acquisitions, and non-competition provisions;
our general partner is allowed to take into account the interests of parties other than us, including Spartan and its affiliates, in resolving
conflicts of interest;
our general partner has limited its liability and reduced its fiduciary duties to our common unitholders and us, and has also restricted the
remedies available to our common unitholders for actions that, without the limitations, might constitute breaches of fiduciary duty;
our general partner will determine the amount and timing of asset purchases and sales, capital expenditures, borrowings, repayment of
indebtedness, and issuances of additional partnership interests, each of which can affect the amount of cash that is available for distribution
to our common unitholders;
our general partner determines the amount and timing of any capital expenditures which can affect the amount of cash that is distributed to
our common unitholders;
our general partner may cause us to borrow funds in order to permit the payment of cash distributions;
our general partner determines which costs incurred by it and its affiliates are reimbursable by us and Spartan will determine the allocation
of shared overhead expenses;
our partnership agreement does not restrict our general partner from causing us to pay it or its affiliates for any services rendered to us or
entering into additional contractual arrangements with any of these entities on our behalf;
our general partner intends to limit its liability regarding our contractual and other obligations and, in some circumstances, is entitled to be
indemnified by us;
our general partner decides whether to retain separate counsel, accountants, or others to perform services for us; and
24
•
our general partner determines the amount and timing of distributions to our unitholders.
Our partnership agreement limits our general partner’s fiduciary duties to our common unitholders and restricts the remedies available to our
common unitholders for actions taken by our general partner that might otherwise constitute breaches of fiduciary duty.
Our partnership agreement contains provisions that reduce the fiduciary standards to which our general partner would otherwise be held by state
fiduciary duty laws. For example, our partnership agreement:
•
•
•
•
•
permits our general partner to make a number of decisions in its individual capacity, as opposed to in its capacity as our general partner.
This entitles our general partner to consider only the interests and factors that it desires, and it has no duty or obligation to consider any
interest of, or factors affecting, us, our affiliates or any limited partner. Examples include the exercise of its limited call right, the exercise of
its rights to transfer or vote the partnership units it owns, the exercise of its registration rights and its determination whether or not to
consent to any merger or consolidation of the partnership or amendment to the partnership agreement;
provides that our general partner will not have any liability to us or our common unitholders for decisions made in its capacity as a general
partner so long as it acted in good faith, meaning it believed the decision was in the best interests of our partnership;
generally provides that affiliated transactions and resolutions of conflicts of interest not approved by the conflicts committee of the board of
directors of our general partner acting in good faith and not involving a vote of our common unitholders must be on terms no less favorable
to us than those generally being provided to or available from unrelated third parties or must be “fair and reasonable” to us, as determined
by our general partner in good faith and that, in determining whether a transaction or resolution is “fair and reasonable,” our general partner
may consider the totality of the relationships between the parties involved, including other transactions that may be particularly
advantageous or beneficial to us;
provides that our general partner and its executive officers and directors will not be liable for monetary damages to us, our limited partners
or assignees for any acts or omissions unless there has been a final and non-appealable judgment entered by a court of competent
jurisdiction determining that our general partner or those other persons acted in bad faith or engaged in fraud or willful misconduct or, in the
case of a criminal matter, acted with knowledge that the conduct was criminal; and
provides that in resolving conflicts of interest, it will be presumed that in making its decision our general partner acted in good faith, and in
any proceeding brought by or on behalf of any limited partner or us, the person bringing or prosecuting such proceeding will have the
burden of overcoming such presumption.
Our common unitholders have limited voting rights and are not entitled to elect our general partner or its directors.
Unlike the holders of common stock in a corporation, our unitholders have only limited voting rights on matters affecting our business and,
therefore, limited ability to influence management’s decisions regarding our business. Unitholders will have no right to elect our general partner or
its board of directors. The board of directors of our general partner will be chosen indirectly by Spartan through its subsidiary that is the sole
shareholder of our general partner. Furthermore, if our unitholders are dissatisfied with the performance of our general partner, they will have little
ability to remove our general partner. The vote of the holders of at least 66.7% of all outstanding common units is required to remove our general
partner. As of February 28, 2024, our general partner and its affiliates own 44.6% of our aggregate outstanding common units. Due to these
limitations, the price at which the common units will trade could be diminished because of the absence or reduction of a takeover premium in the
trading price.
We can issue an unlimited number of partnership units in the future, including units that are senior in right of distributions, liquidation and voting to
the common units, without the approval of our common unitholders and without the approval of the conflicts committee of our general partner, which
would dilute our common unitholders’ existing ownership interests.
Our partnership agreement does not limit the number of additional partnership units that we may issue at any time without the approval of our
common unitholders. In addition, we may issue an unlimited number of partnership units that are senior to the common units in right of distribution,
liquidation, or voting.
25
The issuance by us of additional common units or other equity securities of equal or senior rank will have the following effects:
•
•
•
•
•
our previously existing common unitholders’ proportionate ownership interests in us will decrease;
the amount of cash available for distribution on each common unit may decrease;
the ratio of taxable income to distributions may increase;
the relative voting strength of each previously outstanding common unitholders may be diminished; and
the market price of the common units may decline.
Control of our general partner has been and may be transferred to a third party without common unitholder consent.
On January 29, 2021, control of our general partner was transferred from TETRA to Spartan. Our general partner may transfer its general partner
interest to a third party in a merger or in a sale of all or substantially all of its assets without the consent of our unitholders. Furthermore, our
partnership agreement does not restrict the ability of Spartan or its subsidiaries from transferring all or a portion of its indirect ownership interest in
our general partner to a third party. The new owners of our general partner would then be in a position to replace the board of directors and
executive officers of our general partner with its own choices and thereby influence the decisions taken by the board of directors and executive
officers.
Our partnership agreement restricts the voting rights of unitholders owning 20% or more of our common units, other than our general partner and its
affiliates, including Spartan. Accordingly, such unitholders’ voting rights may be limited.
Unitholders’ voting rights are further restricted by the partnership agreement provision providing that any partnership units held by a person that
owns 20% or more of any class of partnership units then outstanding, other than our general partner, its affiliates, including Spartan, its transferees
and persons who acquired such partnership units with the prior approval of the board of directors of our general partner, cannot vote on any matter.
Our partnership agreement also contains provisions limiting the ability of our common unitholders to call meetings or to acquire information about
our operations.
Our general partner has a limited call right that may require our unitholders to sell common units at an undesirable time or price.
If at any time our general partner and its affiliates own more than 90% of the common units, our general partner will have the right, but not the
obligation, which it may assign to any of its affiliates or to us, to acquire all, but not less than all, of the common units held by unaffiliated persons at
a price not less than the then-current market price. As a result, our unitholders may be required to sell common units at an undesirable time or price
and may not receive any return on their investment. Our unitholders may also incur a tax liability upon a sale of common units. As of February 28,
2024, our general partner and its affiliates own an aggregate of 44.6% of our common units.
Our common unitholders’ liability may not be limited if a court finds that common unitholder action constitutes control of our business.
A general partner of a partnership generally has unlimited liability for the obligations of the partnership, except for those contractual obligations of
the partnership that are expressly made without recourse to our general partner. Our partnership is organized under Delaware law, and we conduct
business in a number of other states. The limitations on the liability of holders of limited partner interests for the obligations of a limited partnership
have not been clearly established in some of the other states in which we do business. Our common unitholders could be liable for any and all of
our obligations as if they were a general partner if:
•
•
a court or government agency determined that we were conducting business in a state but had not complied with that particular state’s
partnership statute; or
our common unitholders’ right to act with other unitholders to remove or replace our general partner, to approve some amendments to our
partnership agreement, or to take other actions under our partnership agreement constitutes “control” of our business.
26
Our common unitholders may have liability to repay distributions that were wrongfully distributed to them.
Under certain circumstances, our common unitholders may have to repay amounts wrongfully returned or distributed to them. Under Section 17-
607 of the Delaware Revised Uniform Limited Partnership Act, we may not make a distribution to our common unitholders if the distribution would
cause our liabilities to exceed the fair value of our assets. Delaware law provides that for a period of three years from the date of the impermissible
distribution, limited partners who received the distribution and who knew at the time of the distribution that it violated Delaware law will be liable to
the limited partnership for the distribution amount. Substituted limited partners are liable for the obligations of the assignor to make contributions to
the partnership that are known to the substituted limited partner at the time it became a limited partner and for unknown obligations if the liabilities
could be determined from the partnership agreement. Liabilities to partners because of their partnership interest and liabilities that are non-recourse
to the partnership are not counted for purposes of determining whether a distribution is permitted.
While our partnership agreement requires us to distribute all of our available cash, our partnership agreement, including provisions requiring us to
make cash distributions contained therein, may be amended.
While our partnership agreement requires us to distribute all of our available cash, our partnership agreement, including provisions requiring us to
make cash distributions contained therein, may be amended. Our partnership agreement can be amended with the consent of our general partner
and the approval of a majority of the outstanding common units (including common units held by affiliates of Spartan). As of February 28, 2024, our
general partner and its affiliates own an aggregate of 44.6% of our common units.
We are exempt from certain corporate governance requirements that provide additional protection to stockholders of other public companies.
Companies listed on the NASDAQ are required to meet the high standards of corporate governance set forth in the NASDAQ Listing Rules.
These requirements generally do not apply to limited partnerships or to a “controlled company,” within the meaning of the NASDAQ rules. We are a
limited partnership and a “controlled company,” within the meaning of the NASDAQ rules, and, as a result, we rely on exemptions from certain
corporate governance requirements that provide protection to stockholders of other public companies.
Tax Risks to Common Unitholders
Our tax treatment depends on our status as a partnership for U.S. federal income tax purposes. If the IRS were to treat us as a corporation for U.S.
federal income tax purposes, then our cash available for distribution to our unitholders would be substantially reduced.
The anticipated after-tax economic benefit of an investment in our common units depends largely on our being treated as a partnership for
U.S. federal income tax purposes. Despite the fact that we are a limited partnership under Delaware law, we will be treated as a corporation for U.S.
federal income tax purposes unless we satisfy a "qualifying income" requirement. Based upon our current operations and current Treasury
Regulations, we believe that we satisfy the qualifying income requirement. However, no ruling has been or will be requested regarding our treatment
as a partnership for U.S. federal income tax purposes. Failing to meet the qualifying income requirement or a change in current law could cause us
to be treated as a corporation for U.S. federal income tax purposes or otherwise subject us to taxation as an entity.
If we were treated as a corporation for U.S. federal income tax purposes, we would pay U.S. federal income tax on all of our taxable income at
the corporate tax rate and would likely pay additional state and local income tax at varying rates. Distributions to our unitholders would generally be
taxed again as corporate distributions, and no income, gains, losses, deductions or credits would flow through to our unitholders. Because a tax
would be imposed upon us as a corporation, our cash available for distribution to our unitholders would be substantially reduced. Therefore,
treatment of us as a corporation would result in a material reduction in the anticipated cash flow and after-tax return to our unitholders, likely causing
a substantial reduction in the value of our common units.
27
We have subsidiaries that are treated as corporations for U.S. federal income tax purposes and are subject to corporate-level income taxes.
We conduct a portion of our operations through subsidiaries that are organized as corporations for U.S. federal income tax purposes. We may
elect to conduct additional operations through these corporate subsidiaries in the future. These corporate subsidiaries are subject to U.S. corporate-
level tax, which reduces the cash available for distribution to us and, in turn, to our unitholders. If the IRS were to successfully assert that these
corporations have more tax liability than we anticipate or legislation were enacted that increases the corporate tax rate, our cash available for
distribution to our unitholders would be further reduced. Distributions from any such corporate subsidiary will generally be treated as dividend
income to the extent of the current and accumulated earnings and profits of such corporate subsidiary. An individual unitholder's share of dividend
income from any corporate subsidiary would constitute portfolio income that could not be offset by the unitholder's share of our other losses or
deductions.
The tax treatment of publicly traded partnerships or an investment in our common units could be subject to potential legislative, judicial, or
administrative changes and differing interpretations, possibly on a retroactive basis.
The present U.S. federal income tax treatment of publicly traded partnerships, including us, or an investment in our common units may be
modified by administrative, legislative or judicial changes or differing interpretations at any time. From time to time, members of the U.S. Congress
have proposed and considered substantive changes to the existing U.S. federal income tax laws that would affect publicly traded partnerships,
including proposals that would eliminate our ability to qualify for partnership tax treatment. Recent proposals have provided for the expansion of the
qualifying income exception for publicly traded partnerships in certain circumstances, and other proposals have provided for the total elimination of
the qualifying income exception upon which we rely for our partnership tax treatment. Further, while unitholders of publicly traded partnerships are,
subject to certain limitations, entitled to a deduction equal to 20% of their allocable share of a publicly traded partnership’s “qualified business
income,” this deduction is scheduled to expire with respect to taxable years beginning after December 31, 2025.
In addition, the Treasury Department has issued, and in the future may issue, regulations interpreting those laws that affect publicly traded
partnerships. There can be no assurance that there will not be further changes to U.S. federal income tax laws or the Treasury Department’s
interpretation of the qualifying income rules in a manner that could impact our ability to qualify as a partnership in the future.
Any modification to the U.S. federal income tax laws and interpretations thereof may or may not be applied retroactively and could make it more
difficult or impossible for us to meet the exception for certain publicly traded partnerships to be treated as partnerships for U.S. federal income tax
purposes. We are unable to predict whether any of these changes or other proposals will ultimately be enacted. Any similar or future legislative
changes could negatively impact the value of an investment in our common units. You are urged to consult with your own tax advisor with respect to
the status of regulatory or administrative developments and proposals and their potential effect on your investment in our common units.
If we were subjected to a material amount of additional entity-level taxation by individual states, it would reduce our cash available for distribution to
our unitholders.
Changes in current state law may subject us to additional entity-level taxation by individual states. Because of state budget deficits and other
reasons, several states have been evaluating ways to subject partnerships to entity-level taxation through the imposition of state income, franchise,
and other forms of taxation. For example, we are subject to an entity-level Texas franchise tax. Imposition of any such taxes may substantially
reduce the cash available for distribution to our unitholders.
Although we are not subject to U.S. federal income tax other than with respect to our operating U.S. subsidiaries that are treated as corporations for
U.S. federal income tax purposes, certain of our foreign operations are subject to certain non-U.S. taxes. If a taxing authority were to successfully
assert that we have more tax liability than we anticipate or legislation were enacted that increased the taxes to which we are subject, our cash
available for distribution to our unitholders could be further reduced.
Approximately 8.0% of our consolidated revenues for the year ended December 31, 2023, were generated in non-U.S. jurisdictions,
primarily Mexico, Canada, Argentina and Chile. Our non-U.S. operations and subsidiaries
28
are generally subject to income, withholding, and other taxes in the non-U.S. jurisdictions in which they are organized or from which they receive
income, reducing the amount of cash available for distribution. In computing our tax obligation in these non-U.S. jurisdictions, we are required to
take various tax accounting and reporting positions on matters that are not entirely free from doubt and for which we have not received rulings from
the governing tax authorities, such as whether withholding taxes will be reduced by the application of certain tax treaties. Upon review of these
positions the applicable authorities may not agree with our positions. A successful challenge by a tax authority could result in additional taxes being
imposed on us, reducing the cash available for distribution to our unitholders. In addition, changes in our operations or ownership could result in
higher than anticipated taxes being imposed in jurisdictions in which we are organized or from which we receive income and further reduce the cash
available for distribution. Although these taxes may be properly characterized as foreign income taxes, our unitholders may not be able to credit
them against the liability for U.S. federal income taxes on the unitholders’ share of our earnings. In addition, our operations in countries in which we
operate now or in the future may involve risks associated with the legal structure used and the taxation on assets transferred into a particular
country. Tax laws of non-U.S. jurisdictions are subject to potential legislative, judicial, or administrative changes and differing interpretations,
possibly on a retroactive basis. Any such changes may result in additional taxes above the amounts we currently anticipate and further reduce our
cash available for distribution to our unitholders.
If the IRS contests the U.S. federal income tax positions we take, the market for our common units may be adversely impacted, and the cost of any
IRS contest will reduce our cash available for distribution to our unitholders.
We have not requested a ruling from the IRS with respect to our treatment as a partnership for U.S. federal income tax purposes. The IRS may
adopt positions that differ from the positions we take, and the IRS’s positions may ultimately be sustained. It may be necessary to resort to
administrative or court proceedings to sustain some or all of the positions we take. A court may not agree with some or all of the positions we take.
Any contest with the IRS may materially and adversely impact the market for our common units and the price at which they trade. In addition, our
costs of any contest with the IRS will be borne indirectly by our unitholders and our general partner, because the costs will reduce our cash
available for distribution.
If the IRS makes audit adjustments to our income tax returns, it (and some states) may assess and collect any taxes (including any applicable
penalties and interest) resulting from such audit adjustments directly from us, in which case our cash available for distribution to our unitholders may
be substantially reduced.
If the IRS makes audit adjustments to our income tax returns, it (and some states) may assess and collect any taxes (including any applicable
penalties and interest) resulting from such audit adjustments directly from us. To the extent possible, our general partner may elect to either pay the
taxes (including any applicable penalties and interest) directly to the IRS or, if we are eligible, issue a revised information statement to each
unitholder and former unitholder with respect to an audited and adjusted return. If we are required to pay taxes, penalties and interest as a result of
audit adjustments, cash available for distribution to our unitholders may be substantially reduced. In addition, because payment would be due for
the taxable year in which the audit is completed, unitholders during that taxable year would bear the expense of the adjustment even if they were
not unitholders during the audited tax year.
Our unitholders are required to pay taxes on their share of our income, even if they do not receive any cash distributions from us.
Our unitholders are required to pay any U.S. federal income taxes, and, in some cases, state and local income taxes on their share of our taxable
income, even if they do not receive cash distributions from us. Unitholders with a greater than 10% interest in us may also be required to include
their pro rata share of any global intangible low-taxed income attributable to our foreign corporate subsidiaries in the year in which such income is
earned, even if the unitholder receives no cash distributions from us. Unitholders may not receive cash distributions from us equal to their share of
our taxable income or even equal to the actual tax liability that results from that income.
In response to current market conditions, we may engage in transactions to de-lever the Partnership and manage our liquidity that may result in
income and gain to our unitholders without a corresponding cash distribution. For example, if we sell assets and use the proceeds to repay existing
debt or fund capital expenditures, you may be allocated taxable income and gain resulting from the sale without receiving a cash distribution.
Further, taking advantage of opportunities to reduce our existing debt, such as debt exchanges, debt repurchases, or modifications
29
of our existing debt, could result in “cancellation of indebtedness income” (also referred to as “COD income”) being allocated to our unitholders as
taxable income. Unitholders may be allocated COD income, and income tax liabilities arising therefrom may exceed cash distributions. The ultimate
effect of any such allocations will depend on the unitholder’s individual tax position with respect to its units. Unitholders are encouraged to consult
their tax advisors with respect to the consequences to them of COD income.
Tax gain or loss on the disposition of our common units could be more or less than expected.
If our unitholders sell common units, they will recognize a gain or loss for U.S. federal income tax purposes equal to the difference between the
amount realized and their tax basis in those common units. Because distributions in excess of their allocable share of our net taxable income
decrease the tax basis in their common units, the amount, if any, of such prior excess distributions with respect to the units our unitholders sell will,
in effect, become taxable income to our unitholders if they sell such units at a price greater than their tax basis in those units, even if the price they
receive is less than their original cost. In addition, because the amount realized includes a unitholder’s share of our nonrecourse liabilities, if our
unitholders sell their units, they may incur a tax liability in excess of the amount of cash the unitholders receive from the sale.
A substantial portion of the amount realized from a unitholder’s sale of our units, whether or not representing gain, may be taxed as ordinary
income to such unitholder due to potential recapture items, including depreciation recapture. Thus, a unitholder may recognize both ordinary income
and capital loss from the sale of units if the amount realized on a sale of such units is less than such unitholder’s adjusted basis in the units. Net
capital loss may only offset capital gains and, in the case of individuals, up to $3,000 of ordinary income per year. In the taxable period in which a
unitholder sells its units, such unitholder may recognize ordinary income from our allocations of income and gain to such unitholder prior to the sale
and from recapture items that generally cannot be offset by any capital loss recognized upon the sale of units.
Unitholders may be subject to limitation on their ability to deduct interest expense incurred by us.
In general, we are entitled to a deduction for interest paid or accrued on indebtedness properly allocable to our trade or business during our
taxable year. However, our deduction for “business interest” is limited to the sum of our business interest income and 30% of our “adjusted taxable
income.” For the purposes of this limitation, our adjusted taxable income is computed without regard to any business interest expense or business
interest income.
If our “business interest” is subject to limitation under these rules, our unitholders will be limited in their ability to deduct their share of any
interest expense that has been allocated to them. As a result, unitholders may be subject to limitation on their ability to deduct interest expense
incurred by us.
Tax-exempt entities face unique tax issues from owning our common units that may result in adverse tax consequences to them.
Investment in our common units by tax-exempt entities, such as employee benefit plans and individual retirement accounts (known as IRAs),
raises issues unique to them. For example, virtually all of our income allocated to organizations that are exempt from U.S. federal income tax,
including IRAs and other retirement plans, will be unrelated business taxable income and will be taxable to them. Additionally, all or part of any gain
recognized by such tax-exempt organization upon a sale or other disposition of our units may be unrelated business taxable income and may be
taxable to them. Tax-exempt entities should consult a tax advisor before investing in our common units.
Non-U.S. Unitholders will be subject to U.S. taxes and withholding with respect to their income and gain from owning our units.
Non-U.S. unitholders are generally taxed and subject to income tax filing requirements by the U.S. on income effectively connected with a
U.S. trade or business (“effectively connected income”). Income allocated to our unitholders and any gain from the sale of our units will generally be
considered to be “effectively connected” with a U.S. trade or business. As a result, distributions to a non-U.S. unitholder will be subject to
withholding at the highest applicable effective tax rate and a non-U.S. unitholder who sells or otherwise disposes of a unit will also be subject to
U.S. federal income tax on the gain realized from the sale or disposition of that unit. In addition to the withholding tax imposed on distributions of
effectively connected income, distributions to a non-U.S. unitholder will also be subject to a 10% withholding tax on the amount of any distribution in
excess of our cumulative net income. As we do
30
not compute our cumulative net income for such purposes due to the complexity of the calculation and lack of clarity in how it would apply to us, we
intend to treat all of our distributions as being in excess of our cumulative net income for such purposes and subject to such 10% withholding tax.
Accordingly, distributions to a non-U.S. unitholder will be subject to a combined withholding tax rate equal to the sum of the highest applicable
effective tax rate and 10%.
Moreover, the transferee of an interest in a partnership that is engaged in a U.S. trade or business is generally required to withhold 10% of the
“amount realized” by the transferor unless the transferor certifies that it is not a foreign person. While the determination of a partner’s “amount
realized” generally includes any decrease of a partner’s share of the partnership’s liabilities, the Treasury regulations provide that the “amount
realized” on a transfer of an interest in a publicly traded partnership, such as our units, will generally be the amount of gross proceeds paid to the
broker effecting the applicable transfer on behalf of the transferor, and thus will be determined without regard to any decrease in that partner’s share
of a publicly traded partnership’s liabilities. For a transfer of interests in a publicly traded partnership that is effected through a broker, the obligation
to withhold is imposed on the transferor’s broker. Current and prospective non-U.S. unitholders should consult their tax advisors regarding the
impact of these rules on an investment in our common units.
We will treat each purchaser of our common units as having the same tax benefits without regard to the actual common units purchased. The IRS
may challenge this treatment, which could adversely affect the value of the common units.
Due to a number of factors, including our inability to match transferors and transferees of common units, we have adopted depreciation and
amortization positions that may not conform to all aspects of existing Treasury Regulations. A successful IRS challenge to those positions could
adversely affect the amount of tax benefits available to our unitholders. It also could affect the timing of these tax benefits or the amount of gain
from the sale of common units and could have a negative impact on the value of our common units or result in audit adjustments to our unitholders’
tax returns.
We prorate our items of income, gain, loss, and deduction for U.S. federal income tax purposes between transferors and transferees of our units
each month based upon the ownership of our units on the first day of each month, instead of on the basis of the date a particular unit is transferred.
The IRS may challenge aspects of our proration method and could change the allocation of items of income, gain, loss, and deduction among our
unitholders.
We prorate our items of income, gain, loss, and deduction for U.S. federal income tax purposes between transferors and transferees of our units
each month based upon the ownership of our units on the first day of each month (the “Allocation Date”), instead of on the basis of the date a
particular unit is transferred. Similarly, we generally allocate (i) certain deductions for depreciation of capital additions, (ii) gain or loss realized on a
sale or other disposition of our assets, and (iii) in the discretion of the general partner, any other extraordinary item of income, gain, loss or
deduction based upon ownership on the Allocation Date. Although final Treasury Regulations allow publicly traded partnerships to use a similar
monthly simplifying convention to allocate tax items among transferor and transferee unitholders, these regulations do not specifically authorize all
aspects of the proration method we have adopted. If the IRS were to successfully challenge our proration method, we may be required to change
our allocation of items of income, gain, loss, and deduction among our unitholders.
Taxable income from our non-U.S. businesses is not eligible for the 20% deduction for qualified publicly traded partnership income.
For taxable years beginning after December 31, 2017 and ending on or before December 31, 2025, a unitholder is generally allowed a deduction
equal to 20% of our “qualified publicly traded partnership income” that is allocated to such unitholder. For purposes of the deduction, the term
qualified publicly traded partnership income includes the net amount of such unitholder’s allocable share of our income that is effectively connected
to our U.S. trade or business activities. Because our non-U.S. business operations earn income that is not effectively connected with a U.S. trade or
business, unitholders may not apply the 20% deduction for qualified publicly traded partnership income to that portion of our income.
31
A unitholder whose units are loaned to a “short seller” to cover a short sale of units may be considered as having disposed of those units. If so, the
unitholder would no longer be treated for tax purposes as a partner with respect to those units during the period of the loan and may recognize gain
or loss from the disposition.
Because there are no specific rules governing the U.S. federal income tax consequence of loaning a partnership interest, a unitholder whose
units are loaned to a “short seller” to cover a short sale of units may be considered as having disposed of the loaned units. In that case, the
unitholder may no longer be treated for tax purposes as a partner with respect to those units during the period of the loan to the short seller, and the
unitholder may recognize gain or loss from such disposition. Moreover, during the period of the loan to the short seller, any of our income, gain, loss,
or deduction with respect to those units may not be reportable by the unitholder, and any cash distributions received by the unitholder as to those
units could be fully taxable as ordinary income. Unitholders desiring to assure their status as partners and avoid the risk of gain recognition from a
loan to a short seller are urged to consult a tax advisor to discuss whether it is advisable to modify any applicable brokerage account agreements to
prohibit their brokers from borrowing their units.
We have adopted certain valuation methodologies in determining a unitholder’s allocations of income, gain, loss and deduction. The IRS may
challenge these methodologies or the resulting allocations, and such a challenge could adversely affect the value of our common units.
In determining the items of income, gain, loss and deduction allocable to our unitholders, we must routinely determine the fair market value of our
assets. Although we may from time to time consult with professional appraisers regarding valuation matters, we make many fair market value
estimates ourselves using a methodology based on the market value of our common units as a means to determine the fair market value of our
assets. The IRS may challenge these valuation methods and the resulting allocations of income, gain, loss and deduction for U.S. federal income
tax purposes.
A successful IRS challenge to these methods or allocations could adversely affect the timing or amount of taxable income or loss being allocated
to our unitholders. It also could affect the amount of gain from our unitholders’ sale of common units and could have a negative impact on the value
of the common units or result in audit adjustments to our unitholders’ tax returns without the benefit of additional deductions.
Unitholders will likely be subject to non-U.S., state and local taxes, and return filing requirements in jurisdictions where they do not live as a result of
investing in our common units.
In addition to U.S. federal income taxes, unitholders will likely be subject to other taxes, including non-U.S., state and local taxes, unincorporated
business taxes and estate, inheritance, or intangible taxes that are imposed by the various jurisdictions in which we do business or control property
now or in the future, even if they do not live in any of those jurisdictions. Unitholders will likely be required to file non-U.S., state, and local income
tax returns and pay non-U.S., state and local income taxes in some or all of these various jurisdictions. Further, unitholders may be subject to
penalties for failure to comply with those requirements. In the United States, we own assets and conduct business in many states, most of which
currently impose a personal income tax on individuals and an income tax on corporations and other entities. As we make acquisitions or expand our
business, we may own or control assets or conduct business in additional jurisdictions that impose a personal income tax. It is our unitholders’
responsibility to file all U.S. federal, non-U.S., state and local tax returns and pay any taxes due in these jurisdictions. Unitholders should consult
with their own tax advisors regarding the filing of such tax returns, the payment of such taxes, and the deductibility of any taxes paid.
Unitholders may be subject to tax in one or more non-U.S. jurisdictions, including Canada, Mexico, Argentina and Chile as a result of owning our
common units if, under the laws of any such jurisdiction, we are considered to be carrying on business there. If unitholders are subject to tax in any
such jurisdiction, they may be required to file a tax return with, and pay taxes to, that jurisdiction based on their allocable share of our income. We
may be required to reduce distributions to unitholders on account of any withholding obligations imposed upon us by that jurisdiction in respect of
such allocation to the unitholders. In addition, the U.S. may not allow a tax credit for any foreign income taxes that unitholders directly or indirectly
incur.
Item 1B. Unresolved Staff Comments.
None.
32
Item 1C. Cybersecurity.
Description of Processes for Assessing, Identifying, and Managing Cybersecurity Risks
We seek to assess, identify and manage cybersecurity risks through the processes described below:
• Risk Assessment:
A multi-layered system designed to protect and monitor data and cybersecurity risk has been implemented.
An overall assessment of our cybersecurity safeguards was conducted by an independent cybersecurity
vendor. Our internal Cybersecurity Team conducts regular evaluations designed to assess, identify and
manage material cybersecurity risks, and we endeavor to update cybersecurity infrastructure, procedures,
policies, and education programs on a regular basis. We use firewalls and protection software, and we
additionally periodically rely on a third-party vendor for alerts regarding suspicious activity.
•
Incident Identification and Response:
A monitoring and detection system has been implemented to help promptly identify cybersecurity incidents.
In the event of any breach or cybersecurity incident, we have a cross-functional incident response plan that
includes an executive management team, established incident levels, and associated notification
procedures, including escalation procedures upon discovery of cybersecurity risks deemed to have a
moderate or higher business impact, even if immaterial to us, and identifies what is needed to restore
normal operations efficiently.
• Cybersecurity Training and Awareness:
All employees and contractors are required to receive annual cybersecurity awareness training. New hires
also receive training in response to drills and simulated attacks. We perform cybersecurity quarterly
exercises to test the effectiveness of our training and discuss “lessons learned” with management to
enhance user awareness and increase users’ responses.
•
•
Access Controls:
The Partnership has endeavored to adopt a zero-trust architecture approach that authenticates and
authorizes interactions between its network and users. Users are provided with access consistent with the
principle of least privilege, which requires that users be given no more access than necessary to complete
their job functions. A multi-factor authentication process has been implemented for employees accessing
company information.
Encryption and Data Protection:
Encryption methods are used to protect sensitive financial information and other confidential data. We
also have programs in place to monitor our retained data with the goal of identifying personal
identifiable information and taking appropriate actions to secure the data.
We incorporate external expertise and reviews as part of our cybersecurity program. For example, we have engaged an independent
cybersecurity advisor to review, assess, and make recommendations regarding our information security program and information technology
strategic plan. We recognize that third-party service providers introduce cybersecurity risks. In an effort to mitigate these risks, before engaging with
any third-party service provider for information technology (“IT”) services, we conduct due diligence to evaluate their cybersecurity capabilities.
Additionally, we endeavor to include cybersecurity requirements in our contracts with these providers and endeavor to require them to adhere to
security standards and protocols. Further, we request that third-party service providers with access to personally identifiable information enter into
data processing services agreements and adhere to our policies and standards.
The above cybersecurity risk management processes are integrated into the Partnership’s overall enterprise risk management program.
Cybersecurity risks are understood to be significant business risks, and as such, are considered an important component of our enterprise-wide risk
management approach.
33
Impact of Risks from Cybersecurity Threats
As of the date of this Report, though the Partnership and our services providers have experienced certain cybersecurity incidents, we are
not aware of any previous cybersecurity threats that have materially affected or are reasonably likely to materially affect the Partnership. However,
we acknowledge that cybersecurity threats are continually evolving, and the possibility of future cybersecurity incidents remains. Despite the
implementation of our cybersecurity processes, our security measures cannot guarantee that a significant cyberattack will not occur. A successful
attack on our IT or operational technology (“OT”) systems could have significant consequences to the business. While we devote resources to our
security measures to protect our systems and information, these measures cannot provide absolute security. No security measure is infallible. See
“Risk Factors” for additional information about the risks to our business associated with a breach or compromise of our IT or OT systems.
Board of Directors’ Oversight and Management’s Role
Through the Partnership’s enterprise risk management program, the Board of Directors is responsible for overseeing cybersecurity,
information security, and information technology risks, as well as management’s actions to identify, assess, mitigate, and remediate those risks. As
part of its program of regular risk oversight, the Audit Committee assists the Board in exercising oversight of the Partnership’s cybersecurity,
information security, and information technology risks. The Board or Audit Committee periodically reviews and discusses with management the
Partnership’s policies, procedures and practices with respect to cybersecurity, information security and information and operational technology,
including related risks. In addition, the IT Director is responsible for upward reporting of cybersecurity incidents deemed to have a moderate or
higher business impact, even if immaterial to us.
Recognizing the importance of cybersecurity to the success and resilience of our business, the Board considers cybersecurity to be a vital
aspect of corporate governance. To facilitate effective oversight, our cybersecurity leadership team holds discussions on cybersecurity risks,
incident trends, and the effectiveness of cybersecurity measures as necessitated by emerging material cyber risks.
Our cybersecurity leadership team is made up of highly experienced professionals with an extensive background in information security, risk
management, and incident response. This background includes a dynamic team, comprised of military veterans versed in forensic analysis and
regulatory compliance with over 23 years of combined Cybersecurity experience in private and public sector, supported by a Master’s degree in
Cybersecurity as well as several industry certifications.
Item 2. Properties.
As of December 31, 2023, we owned four service facilities in North Dakota and Texas. We lease 24 additional service facilities in Alabama,
Arkansas, Colorado, Louisiana, New Mexico, Oklahoma, Texas, Utah, West Virginia, and Wyoming. We also lease service facilities and
administrative offices in Argentina, Canada and Mexico. We also lease a number of storage facilities located across the geographic markets we
serve. Since January 2022, we have leased our own office space in The Woodlands, Texas for our headquarters. Our primary assets include our
fleet of compression and other equipment. See “Item 1 Business - Products and Services - Contract Services,” for a discussion and description of
our compression fleet. All obligations under our First Lien Notes and our Second Lien Notes are secured by security interests in substantially all of
our compression assets but excluding other real property assets. In January 2022, we sold our facilities in Oklahoma City, and we currently do not
own real property in Oklahoma.
Item 3. Legal Proceedings.
From time to time, we may be involved in litigation relating to claims arising out of our operations in the normal course of business. While the
outcome of lawsuits against us cannot be predicted with certainty, management does not consider it reasonably possible that a loss resulting from
such lawsuits in excess of any amounts accrued has been incurred that is expected to have a material adverse effect on our financial condition,
results of operations, or cash flows.
Item 4. Mine Safety Disclosures.
Not applicable.
34
PART II
Item 5. Market for Registrant’s Common Equity, Related Stockholder Matters, and Issuer Repurchases of Equity Securities.
Market Information
Our common units are traded on NASDAQ under the symbol “CCLP.” As of February 28, 2024, there were 46 holders of record of the common
units. The actual number of common unitholders is greater than this number of record holders and includes common unitholders who are beneficial
owners but whose shares are held in street name by banks, brokers and other nominees.
Distribution Policy
Our partnership agreement requires us to distribute, no later than 45 days after the end of each quarter, all of our available cash, as defined
below, at the end of each quarter. There is no guarantee that we will pay any specific distribution in any quarter.
Definition of Available Cash. We define Available Cash in the partnership agreement, and it means, for any quarter, all cash on hand at the
end of that quarter:
•
•
less the amount of cash reserves established by our general partner to:
◦
◦
◦
provide for the proper conduct of our business after the end of the quarter;
comply with applicable law, any of our future debt instruments or other agreements; or
provide funds for future distributions;
plus, if our general partner so determines, all or any portion of any additional cash and cash equivalents on hand on the date of
determination of Available Cash for the quarter resulting from working capital borrowings made after the end of the quarter.
Working capital borrowings are borrowings that are made under a credit agreement, commercial paper facility, or similar financing
arrangement, and in all cases are used solely for working capital purposes or to pay distributions to partners and with the intent of the borrower to
repay such borrowings within twelve months from sources other than additional working capital borrowings.
Common Units. We pay quarterly distributions to the holders of common units to the extent we have sufficient cash from our operations
after establishment of cash reserves and payment of debt service and other contractual obligations, fees and expenses. Beginning with the
distribution for the fourth quarter of 2018, we have paid a distribution of $0.01 per common unit, or $0.04 on an annualized basis. There is no
guarantee that we will continue to pay the reduced current quarterly distribution on the common units or be able to increase it in the future. Our
Second Lien Notes indenture further restricts our ability to make distributions in respect of our common units in any amount exceeding $0.04 per
common unit per year, unless such increased distribution is funded by proceeds from an equity offering. Even if our cash distribution policy is not
modified or revoked, the amount of distributions paid under our policy and the decision to make any distribution is determined by our general
partner, taking into consideration the terms of our partnership agreement. Distributions attributable to the year ended 2023 totaled $0.04 per
common unit. See “Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations — Liquidity and Capital
Resources - Cash Flows - Financing Activities” for a discussion of restrictions on our ability to make distributions.
General Partner Interest. Initially, our general partner was entitled to approximately 2.0% of all distributions that we make prior to our
liquidation. Our general partner has the right, but not the obligation, to contribute a proportionate amount of capital to us to maintain its initial 2.0%
general partner interest. Our general partner’s initial 2.0% interest in our distributions has been decreased to approximately 0.5% and may be
reduced further if we issue additional limited partner units in the future and our general partner does not contribute a proportionate amount of capital
to us to maintain its current general partner interest.
Purchases of Equity Securities by the Issuer and Affiliated Purchasers
None.
35
Securities Authorized for Issuance under Equity Compensation Plans.
See “Item 12. Security Ownership of Certain Beneficial Owners and Management” for information regarding our equity compensation plans as of
December 31, 2023.
Item 6. Reserved.
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations.
The following discussion is intended to analyze major elements of our consolidated financial statements and provide insight into important
areas of management’s focus. This section should be read in conjunction with the Consolidated Financial Statements and accompanying Notes
included elsewhere in this Annual Report. Statements in the following discussion may include forward-looking statements. These forward-looking
statements involve risks and uncertainties. See “Item 1A. Risk Factors,” for additional discussion of these factors and risks.
Business Overview
We provide services including natural gas compression and treating services. Natural gas compression equipment is used for natural gas and oil
production, gathering, artificial lift, production enhancement, transmission, processing and storage. We also provide a variety of natural gas treating
services. Our compression business includes a fleet of approximately 4,300 compressor packages providing approximately 1.2 million in aggregate
horsepower, utilizing a full spectrum of low-, medium-, and high-horsepower engines. Our treating fleet includes amine units, gas coolers, and
related equipment. Our aftermarket business provides compressor package overhaul, repair, engineering and design, reconfiguration and
maintenance services, as well as the sale of compressor package parts and components manufactured by third-party suppliers. Our customers
operate throughout many of the onshore producing regions of the United States, as well as in a number of international locations, including Mexico,
Canada, Argentina and Chile.
Demand for our services is directly driven by the production of crude oil and associated natural gas from unconventional shale plays, production
of natural gas from conventional plays and the transmission of natural gas to and within sales pipelines. Our fleet of compressors, ranging from 20
to 2,500 horsepower per unit, allows us to service our customers’ compression needs at the wellhead through high-horsepower compression needs
at centralized gathering and gas lift facilities.
Oil and natural gas commodity prices decreased from the first half of 2022 through December 2023. West Texas Intermediate oil prices
averaged $79 per barrel in the fourth quarter of 2023. Over this same time period, Henry Hub U.S. natural gas prices averaged $2.74 per million
British thermal unit. While there has been a decline in commodity prices since 2022, they remained at strong levels through the end of 2023.
Accordingly, we did not have a negative impact in the demand for our contract services, aftermarket services, and equipment rentals. In addition, as
a result of increased customer demand, we were able to implement price increases and improved contract terms on many of our compression
contracts. Revenue from contract services increased each quarter in 2023. The stronger market environment has increased, competition for field
and corporate employees. Supply chain issues, increased commodity prices, and inflationary pressures have increased costs and impacted the
availability of our parts and supplies. External factors including Russia’s invasion of Ukraine, recent events in the Middle East, inflationary pressures
and related monetary policy, such as Federal Reserve rate increases, could adversely affect our results of operations, impair our ability to raise
capital, or otherwise adversely impact our ability to realize certain business strategies. We continue to monitor these risks and take the necessary
actions to mitigate them. We have and will continue to evaluate the sale of non-core assets, including our low-horsepower compression fleet. We
can provide no assurance that we will consummate a future sale of our low-horsepower compression fleet.
With the continued market strength and inflationary pressures, we will continue to proactively manage our capital allocation strategies, our
liquidity requirements and monitor our expenses and financial performance. In addition, continued capital discipline throughout the energy sector
may limit production growth even as the economy recovers from these external factors. Despite these challenges, we will continue to maintain our
commitment to safety and service quality for our customers.
36
Results of Operations
The following data should be read in conjunction with the Consolidated Financial Statements and the associated Notes contained
elsewhere in this document.
2023 Compared to 2022
Year Ended December 31,
Period-to-
Period
Change
2023 vs. 2022
2023
Percentage of Total Revenues
Consolidated Results of Operations
2023
2022
(In Thousands)
Revenues:
Contract services
Aftermarket services
Equipment rentals
Equipment sales
Total revenues
Cost of revenues:
Cost of contract services
Cost of aftermarket services
Cost of equipment rentals
Cost of equipment sales
Total cost of revenues
Depreciation and amortization
Impairments and other charges
Selling, general, and administrative expense
Interest expense, net
Other (income) expense, net
Loss before taxes and discontinued operations
Provision for income taxes
Loss from continuing operations
Income (loss) from discontinued operations, net of taxes
Net loss
Revenues
$
$
284,049 $
83,621
17,209
1,249
386,128
140,663
66,355
2,094
1,344
210,456
77,409
—
47,552
53,899
2,519
(5,707)
3,773
(9,480)
—
(9,480) $
263,241 $
72,928
14,865
2,364
353,398
135,639
58,199
2,346
1,382
197,566
78,231
135
42,563
49,481
2,904
(17,482)
4,786
(22,268) $
173 $
(22,095) $
20,808
10,693
2,344
(1,115)
32,730
5,024
8,156
(252)
(38)
12,890
(822)
(135)
4,989
4,418
(385)
11,775
(1,013)
12,788
(173)
12,615
73.6 %
21.7 %
4.5 %
0.3 %
100.0 %
36.4 %
17.2 %
0.5 %
0.3 %
54.5 %
20.0 %
— %
12.3 %
14.0 %
0.7 %
(1.5)%
1.0 %
(2.5)%
— %
(2.5)%
Perio
Per
Cha
2023 vs
(
(
(1
(
(
(
(
(1
(
2022
74.5 %
20.6 %
4.2 %
0.7 %
100.0 %
38.4 %
16.5 %
0.7 %
0.4 %
55.9 %
22.1 %
— %
12.0 %
14.0 %
0.8 %
(4.9)%
1.4 %
(6.3)%
— %
(6.3)%
Contract services revenues increased by $20.8 million, or 7.9%, during 2023 compared to the prior year. The increase in revenues is due to price
increases and inflation adjustments built into contracts. Compression fleet horsepower utilization and operating horsepower remained consistent in
2023 compared to the prior year.
Aftermarket services revenues increased $10.7 million, or 14.7%, during 2023 compared to the prior year due to increased demand for
compression parts and services resulting from an increase in activity levels by our customers. With the improvement in market conditions and the
strong oil and gas commodity prices, customers have increased production of oil and gas which, in turn, increased the demand for parts and
services needed to maintain their compression fleet.
Equipment rentals revenues increased $2.3 million, or 15.8%, compared to the prior year due to an increase in the number of revenue-
generating gas coolers, an increase in customer demand, and higher activity levels.
Equipment sales revenues decreased $1.1 million, or 47.2%, during 2023 compared to the prior year due to a decrease in used unit sales.
37
Cost of revenues
Cost of contract services increased $5.0 million compared to the prior year due to an increase in revenues and higher activity levels. This
increase is also due in part to the effect of inflation resulting in increased costs in certain operating cost categories including parts, field labor, and
fluids costs.
Cost of aftermarket services increased $8.2 million in 2023 compared to 2022 consistent with the increase in revenues.
Cost of equipment rentals decreased $0.3 million compared to 2022 despite an increase in the corresponding revenues due to rate
increases. Additionally, to support the growth in the gas cooler rental business, equipment rental expense increased compared to the prior year
period.
Cost of equipment sales remained consistent during the current year as a result of selling aged units with decreased market value.
Depreciation and amortization
Depreciation and amortization expense consists primarily of the depreciation of compressor packages in our service fleet. In addition, it
includes the depreciation of other operating equipment and facilities and the amortization of intangibles. Depreciation and amortization expense
remained relatively consistent compared to the prior year.
Impairments and other charges
During 2023, we did not record any impairments or other charges. During 2022, a specific engine in inventory was written off due to an engine
being sold at a loss, resulting in a charge of $0.1 million.
Selling, general, and administrative expense
Selling, general, and administrative expenses increased $5.0 million during 2023 compared to 2022 largely due to increased employment
expenses, including wages, incentives, benefits, and other employee-related expenses of $3.7 million, increased bad debt expenses and other
expenses of $1.3 million, and increased professional services fees of $0.2 million. These decreases were offset by decreased general expenses
such as office, tax, and insurance expenses of $0.2 million.
Interest expense, net
Interest expense, net increased to $53.9 million during 2023 compared to $49.5 million in 2022 due to increased expenses associated with
the balances of our credit agreements.
Other (income) expense, net
Other (income) expense, net, was $2.5 million of expense during 2023 compared to $2.9 million of expense in 2022. This increase in
expense is primarily due to increased losses associated with foreign currency and the disposal of assets offset by investment income primarily from
our operations in Mexico and Argentina.
Provision for income taxes
As a partnership, we are generally not subject to income taxes at the entity level, and our partners are separately taxed on their share of our
taxable income. However, a portion of our business is conducted through taxable U.S. corporate subsidiaries. Accordingly, a U.S. federal and state
income tax provision has been reflected in the accompanying statements of operations. Certain of our operations are located outside of the United
States and the Partnership, through its foreign subsidiaries, is responsible for income taxes in these countries.
Our effective tax rate for the year ended December 31, 2023, was negative 66.1% primarily due to taxes in certain foreign jurisdictions and Texas
gross margin taxes combined with losses generated in entities for which no
38
related tax benefit has been recorded. Included in our deferred tax assets are net operating loss carryforwards and tax credits that are available to
offset future income tax liabilities in the U.S. as well as in certain foreign jurisdictions.
Income (loss) from discontinued operations, net of tax
Income (loss) from discontinued operations, net of tax was $0.2 million income for the prior year related to the warranty reserve related to
our discontinued new unit sales business not being utilized. The Partnership exited the new unit sales business during 2020, with final deliveries
made in October 2020.
How We Evaluate Our Operations
Operating Expenses. We use operating expenses as a performance measure for our business. We track our operating expenses using
month-to-month, quarter-to-quarter, year-to-date, and year-to-year comparisons and as compared to budget. This analysis is useful in identifying
adverse cost trends and allows management to investigate the cause of these trends and put corrective measures in place where possible. The
most significant portions of our operating expenses are for our field labor, repair and maintenance of our equipment, and fluids cost. The costs of
other materials consumed while performing our services, other labor costs, vehicle leases and maintenance cost, rent on facilities, and insurance
expenses comprise the significant remainder of our operating expenses. Our operating expenses generally fluctuate with our level of activity.
Our labor costs consist primarily of wages and benefits for our field personnel, as well as expenses related to their training and safety.
Additional information regarding our operating expenses for the year ended December 31, 2023, is provided within the Results of Operations
sections above.
Adjusted EBITDA. We view Adjusted EBITDA as one of our primary management tools, and we track it on a monthly basis, both in dollars
and as a percentage of revenues (typically compared to the prior month, prior year period, and to budget). We define Adjusted EBITDA as earnings
before interest, taxes, depreciation and amortization, and before certain charges, including impairments, bad debt expense attributable to
bankruptcy of customers, equity compensation, non-cash costs of compressors sold, gain on extinguishment of debt, write-off of unamortized
financing costs, and excluding severance and other non-recurring or unusual expenses or charges. Adjusted EBITDA is used as a supplemental
financial measure by our management to:
assess our ability to generate available cash sufficient to make distributions to our common unitholders and general partner;
evaluate the financial performance of our assets without regard to financing methods, capital structure, or historical cost basis;
•
•
• measure operating performance and return on capital as compared to those of our competitors; and
•
determine our ability to incur and service debt and fund capital expenditures.
39
The following table reconciles net income (loss) to Adjusted EBITDA for the periods indicated:
Net loss
Provision for income taxes
Depreciation and amortization
Impairments and other charges
Interest expense, net
Equity compensation
Transaction costs
Severance
Non-cash cost of compressors sold
Outside services costs related to unit disposals
Fire damaged unit
(Benefit) provision for income taxes, depreciation, amortization and
impairments attributed to discontinued operations
Other
Adjusted EBITDA
Year Ended December 31,
2022
2023
(In Thousands)
$
$
(9,480) $
3,773
77,409
—
53,899
1,798
1,278
277
1,345
155
893
—
430
131,777 $
(22,095)
4,786
78,231
135
49,481
1,622
210
432
1,382
—
—
(173)
440
114,451
Free Cash Flow. We define Free Cash Flow as cash from operations less capital expenditures, net of sales proceeds. Management
primarily uses this metric to assess our ability to retire debt, evaluate our capacity to further invest and grow, and measure our performance as
compared to our peers. The following table reconciles cash provided by operations, net, to Free Cash Flow for the periods indicated:
Net cash provided by operating activities
Capital expenditures, net of sales proceeds
Free cash flow
Year Ended December 31,
2022
2023
$
$
(In Thousands)
62,170
(51,459)
10,711
$
$
35,544
(43,939)
(8,395)
Net cash provided by operating activities for the year ended December 31, 2023, includes $72.1 million of revenues in excess of cash
expenses partially offset by $10.0 million in working capital changes.
Adjusted EBITDA and Free Cash Flow are financial measures that are not in accordance with U.S. GAAP and should not be considered an
alternative to net income, operating income, cash from operating activities, or any other measure of financial performance presented in accordance
with U.S. GAAP. These measures may not be comparable to similarly titled financial metrics of other entities, as other entities may not calculate
Adjusted EBITDA or Free Cash Flow in the same manner as we do. Management compensates for the limitations of Adjusted EBITDA and Free
Cash Flow as analytical tools by reviewing the comparable U.S. GAAP measures, understanding the differences between the measures, and
incorporating this knowledge into management’s decision-making processes. Adjusted EBITDA and Free Cash Flow should not be viewed as
indicative of the actual amount of cash we have available for distributions or that we plan to distribute for a given period, nor should it be equated
with “available cash” as defined in our partnership agreement.
Horsepower Utilization Rate of our Compressor Packages. We measure the horsepower utilization rate across our fleet of compressor
packages as the amount of horsepower of compressor packages used to provide services as of a particular date, divided by the amount of
horsepower of compressor packages in our services fleet as of such date. Management primarily uses this metric to determine our future need for
additional compressor packages for our service fleet and to measure marketing effectiveness.
40
The following table sets forth the total horsepower in our compression fleet, our total horsepower in service and our horsepower utilization
rate by each horsepower class of our compression fleet as of the dates shown.
Horsepower in fleet
Low-horsepower (0-100)
Medium-horsepower (101-1,000)
High-horsepower (1,001 and over)
Total horsepower in fleet
Horsepower in service
Low-horsepower (0-100)
Medium-horsepower (101-1,000)
High-horsepower (1,001 and over)
Total horsepower in service
Horsepower utilization rate
Low-horsepower (0-100)
Medium-horsepower (101-1,000)
High-horsepower (1,001 and over)
Total horsepower utilization rate
December 31,
2023
2022
116,701
400,271
658,945
1,175,917
65,744
328,591
630,195
1,024,530
127,289
407,428
652,640
1,187,357
79,464
343,737
607,370
1,030,571
56.3 %
82.1 %
95.6 %
87.1 %
62.4 %
84.4 %
93.1 %
86.8 %
Net Increases/Decreases in Compression Fleet Horsepower. We measure the net increase (or decrease) in our compression fleet
horsepower during a given period by taking the difference between the aggregate horsepower of compressor packages added to the fleet during the
period, less the aggregate horsepower of compressor packages removed from the fleet during the period.
Liquidity and Capital Resources
Our primary cash requirements are for distributions, working capital requirements, debt service, normal operating expenses, and capital
expenditures. Our potential sources of funds are our existing cash balances, cash generated from our operations, asset sales, and long-term and
short-term borrowings, which we believe will be sufficient to meet our working capital and growth capital requirements during 2024. We have
secured orders from key customers for high-horsepower and electric compressors which will drive our investment in growth capital and consume
liquidity in 2024.
During 2023, oil and gas commodity prices remained strong resulting in an increase in activity levels by our customers and higher demand
for our products and services. Although uncertainty remains, the outlook for the energy sector continues to be favorable. Despite these
uncertainties, we remain committed to a long-term growth strategy. Our near-term focus is to reduce our leverage, preserve and enhance liquidity,
and grow our profitability through strategic operating and financial measures. We periodically evaluate engaging in strategic transactions and may
consider divesting assets where our evaluation suggests such transactions are in the best interests of our business. We are subject to business and
operational risks that could materially and adversely affect our cash flows and, when coupled with risks associated with current debt and equity
market conditions, our ability or desire to issue securities. Please read “Item 1A. Risk Factors.”
Following the redeployment of our idle assets, meeting increased demand for our contract services will require ongoing capital expenditure
investment, which could be significant. We will determine appropriate funding of future capital expenditures, along with potential acquisitions, on a
case-by-case basis. Funding sources may include existing cash balances, cash flow generated from our operations, borrowing against our Credit
Agreement and the Spartan Credit Agreement, finance leases with third parties, and issuance of equity.
41
The level of future growth capital expenditures depends on demand for our contract services, the level of cash available to fund these
expenditures and our decisions whether to utilize available cash to fund increases in our quarterly common unit distribution, retire debt, or make
capital expenditures. We expect capital expenditures in 2024 will range from $52.0 million to $69.0 million. These capital expenditures include
approximately $20.0 million to $27.5 million of maintenance capital expenditures, approximately $30.0 million to $37.5 million of capital expenditures
primarily associated with the expansion of our contract services fleet and $2.0 million to $4.0 million of capital expenditures related to investments in
technology and facilities. We expect cash on hand and cash generated from operations will be sufficient to meet cash needs throughout 2024.
On January 18, 2024, our general partner declared a cash distribution attributable to the quarter ended December 31, 2023, of $0.01 per
common unit. This distribution equates to a distribution of $0.04 per outstanding common unit on an annualized basis. This quarterly distribution
was paid on February 14, 2024, to each of the holders of common units of record as of the close of business on January 31, 2024.
Cash Flows
A summary of our sources and uses of cash during the year ended December 31, 2023 and 2022 is as follows:
Year Ended December 31,
2022
2023
(In Thousands)
Operating activities
Investing activities
Financing activities
$
$
$
62,170 $
(51,459) $
(12,272) $
35,544
(43,939)
10,270
Operating Activities
Net cash provided by operating activities increased by $26.6 million during the year ended December 31, 2023, to $62.2 million compared
to $35.5 million provided by operating activities in 2022. Our cash provided from operating activities was primarily generated from the provision of
contract compression and treating services.
Cash provided from our foreign operations is subject to various uncertainties, including the volatility associated with interruptions caused by
customer budgetary decisions, uncertainties regarding the renewal of our existing customer contracts, and other changes in contract arrangements,
the timing of collection of our receivables, and the repatriation of cash generated by our international operations.
Investing Activities
Capital expenditures during the year ended December 31, 2023, increased by $5.8 million compared to 2022 driven by an increase in
investments in growth capital. Maintenance capital expenditures increased compared to the prior year. Total capital expenditures during 2023 were
$59.2 million, offset by $1.3 million from compression units sold. Total capital expenditures for 2023 include $21.3 million of maintenance capital
expenditures.
The level of growth capital expenditures depends on our ability to redeploy existing fleet equipment and demand for compression services.
Improved market conditions have provided opportunities with our customer base to provide new large horsepower compression, resulting in
increased demand for growth capital. If the demand for compression services increases or decreases, the amount of planned expenditures on
growth and expansion will be adjusted. We continue to review all capital expenditure plans carefully in an effort to conserve cash and fund our
liquidity needs.
Financing Activities
Distributions
During the year ended December 31, 2023, we distributed $5.7 million of cash distributions to our common unitholders and general partner.
42
Credit Agreement
On June 30, 2022, the Partnership amended the Loan and Security Agreement dated June 29, 2018 (as amended, restated, amended and
restated, supplemented or otherwise modified from time to time, the “Credit Agreement”). The Credit Agreement provides for maximum revolving
credit commitments of $35.0 million and includes a $3.5 million reserve, which results in reduced borrowing availability.
The maturity date of the Credit Agreement is June 29, 2025. As of December 31, 2023, we had an outstanding balance of $9.8 million and
had $1.3 million in letters of credit against our Credit Agreement, leaving availability under the Credit Agreement of $17.7 million, subject to
compliance with the covenants, borrowing base, and other provisions of the agreements that may limit borrowings under the Credit Agreement. As
of February 28, 2024, we had no balance outstanding under our Credit Agreement and $1.3 million in letters of credit, leaving availability under the
Credit Agreement of $26.5 million, subject to compliance with the covenants, borrowing base, and other provisions of the agreements that may limit
borrowings under the Credit Agreement. The amounts the Partnership may borrow under the Credit Agreement are based on the amounts of the
Partnership’s accounts receivable and the value of certain inventory. Decreases in the amount of the Partnership’s accounts receivable and the
value of its inventory would result in reduced borrowing availability under the Credit Agreement.
Spartan Credit Agreement
On October 19, 2022, certain unrestricted subsidiaries of the Partnership, Spartan Energy Services LLC, as borrower, and Treating Holdco,
as guarantor, amended the Loan, Security and Guaranty Agreement dated January 29, 2021 (as amended, restated, amended and restated,
supplemented or otherwise modified from time to time, the “Spartan Credit Agreement”) with Bank of America, N.A., in its capacity as agent, and the
other lenders and loan parties party thereto. As of December 31, 2023, and subject to compliance with the covenants, borrowing base, and other
provisions of the agreements that may limit borrowings under the Spartan Credit Agreement, we had availability of $22.8 million.
The maturity date of the Spartan Credit Agreement is October 17, 2025. As of December 31, 2023, we had a $47.0 million outstanding
balance. As of February 28, 2024, we have $44.4 million balance outstanding under the Spartan Credit Agreement and no letters of credit, leaving
availability under the Spartan Credit Agreement of $25.4 million, subject to compliance with the covenants, borrowing base, and other provisions of
the agreement that may limit borrowings under the Spartan Credit Agreement. The amounts that may be borrowed under the Spartan Credit
Agreement are based on the amounts of accounts receivable, the value of certain inventory, and appraised value of fixed assets, and fixed asset
net book value. Decreases in the amount of accounts receivable and the value of its inventory and fixed assets would result in reduced borrowing
availability under the Spartan Credit Agreement.
Notes
We may from time to time seek to retire or purchase certain amounts of our outstanding senior notes through cash purchases, in open
market purchases, privately negotiated transactions or otherwise. Such repurchases, if any, will depend on prevailing market conditions, our liquidity
requirements, contractual restrictions and other factors.
7.50% First Lien Notes due 2025
As of December 31, 2023, our 7.50% First Lien Notes due 2025 (the “First Lien Notes”) had $400.1 million outstanding net of unamortized
discounts, unamortized deferred financing costs and deferred restructuring gains. Interest on these notes is payable on April 1 and October 1 of
each year. The First Lien Notes are secured by a first-priority security interest in substantially all of the Partnership’s and its subsidiaries assets,
subject to certain permitted encumbrances and exceptions, and are guaranteed on a senior secured basis by each of the Partnership’s U.S.
restricted subsidiaries (other than CSI Compressco Finance Inc. (“Finance Corp,” certain immaterial subsidiaries and certain other excluded U.S.
subsidiaries).
43
10.000%/10.750% Second Lien Notes due 2026
As of December 31, 2023, our 10.000%/10.750% Second Lien Notes due 2026 (the “Second Lien Notes”) had $172.6 million outstanding,
net of unamortized discounts, unamortized deferred financing costs and deferred restructuring gains. Interest on the Second Lien Notes is payable
on April 1 and October 1 of each year. The Second Lien Notes are secured by a second-priority security interest in substantially all of the
Partnership’s and its subsidiaries assets, subject to certain permitted encumbrances and exceptions, and are guaranteed on a senior secured basis
by each of the Partnership’s U.S. restricted subsidiaries (other than Finance Corp, certain immaterial subsidiaries and certain other excluded U.S.
subsidiaries). In connection with the payment of PIK Interest (as defined below), if any, in respect of the Second Lien Notes, the issuers will be
entitled, to increase the outstanding aggregate principal amount of the Second Lien Notes or issue additional notes (“PIK notes”) under the Second
Lien Notes indenture on the same terms and conditions as the already outstanding Second Lien Notes. Interest will accrue at (1) the annual rate of
7.250% payable in cash, plus (2) at the election of the Issuers (made by delivering a notice to the Second Lien Trustee not less than five business
days prior to the record date), the annual rate of (i) 2.750% payable in cash (together with the annual rate set forth in clause (1), the “Cash Interest
Rate”) or (ii) 3.500% payable by increasing the principal amount of the outstanding Second Lien Notes or by issuing additional PIK notes, in each
case rounding up to the nearest $1.00 (such increased principal amount or additional PIK notes, the “PIK Interest”). We elected to cash pay interest
starting April 1, 2022; prior to this we elected to pay interest by issuing additional PIK Notes.
In addition, the indentures governing our First Lien Notes and Second Lien Notes contain customary covenants restricting our ability and
the ability of our restricted subsidiaries to: (i) pay distributions on, purchase, or redeem our common units, make certain investments and other
restricted payments, or purchase or redeem any subordinated debt; (ii) incur or guarantee additional indebtedness or issue certain kinds of
preferred equity securities; (iii) create or incur certain liens securing indebtedness; (iv) sell assets, including dispositions of the collateral securing
our First Lien Notes and Second Lien Notes; (v) consolidate, merge, or transfer all or substantially all of our assets; (vi) enter into transactions with
affiliates; and (vii) enter into agreements that restrict distributions or other payments from our restricted subsidiaries to us. Our Second Lien Notes
indenture further restricts our ability to make distributions in respect of our common units in any amount exceeding $0.04 per common unit per year,
unless such increased distribution is funded by proceeds from an equity offering. These covenants are subject to a number of important limitations
and exceptions, including certain provisions permitting us, subject to the satisfaction of certain conditions, to transfer assets to certain of our
unrestricted subsidiaries. The indentures also contain customary events of default and acceleration provisions relating to events of default, which
provide that upon an event of default under the indentures, the Trustee or the holders of at least 25% in aggregate principal amount of the then
outstanding First Lien Notes and Second Lien Notes may declare all of the First Lien Notes and Second Lien Notes to be due and payable
immediately. We are in compliance with all covenants of the First Lien Notes and Second Lien Notes indentures as of December 31, 2023.
Finance Agreements
During the year ended December 31, 2022, we entered into Master Finance Agreements with a third party in the amount of $16.6 million to
finance certain compression equipment. The notes are payable in monthly installments totaling $0.5 million for thirty-six months. The current portion
of this amount is classified in accrued liabilities and other and the long-term portion is classified in other long-term liabilities on the accompanying
consolidated balance sheet.
During the first quarter of 2023, CSI Compressco Leasing LLC and CSI Compressco Operating LLC (individually and collectively as
Debtor), with CSI Compressco LP (as Guarantor), entered into a Master Equipment Finance Agreements with a third party totaling $5.1 million to
finance certain compression equipment. The notes are payable in monthly installments totaling $0.2 million for 36 months. The current portion of
these amounts are classified in accrued liabilities and other and the long-term portion is classified in other long-term liabilities on the accompanying
consolidated balance sheet.
44
Leases
We have operating leases for some of our office space, warehouse space, operating locations, and machinery and equipment. Our leases
have remaining lease terms up to 10 years. Some of our leases have options to extend for various periods or purchase the equipment, while some
have termination options with prior notice of generally 30 days or six months. See Note 5 - “Leases” in the Notes to Consolidated Financial
Statements in this Annual Report for further information.
Off Balance Sheet Arrangements
As of December 31, 2023, we had no “off balance sheet arrangements” that may have a current or future material effect on our consolidated
financial condition or results of operations.
Supplemental Guarantor Financial Information
The $400.0 million and $172.7 million in aggregate principal amounts outstanding of the First Lien Notes and the Second Lien Notes,
respectively, as of December 31, 2023 are fully and unconditionally guaranteed, subject to certain customary release provisions, on a joint and
several senior secured basis, by the following U.S. restricted subsidiaries which are each a 100% owned subsidiary (each a “Guarantor Subsidiary”
and collectively the “Guarantor Subsidiaries”):
CSI Compressco Field Services International LLC
CSI Compressco Holdings LLC
CSI Compressco International LLC
CSI Compressco Leasing LLC
CSI Compressco Operating LLC
CSI Compressco Sub, Inc.
CSI Compression Holdings, LLC
Rotary Compressor Systems, Inc.
As a result of these guarantees, we are presenting the following summarized financial information of the obligor group pursuant to Rule 1-02(bb)
of Regulation S-X. These schedules are presented using the equity method of accounting for all periods presented. Under this method, investments
in subsidiaries are recorded at cost and adjusted for our share in the subsidiaries’ cumulative results of operations, capital contributions and
distributions and other changes in equity. Elimination entries relate primarily to the elimination of investments in subsidiaries and associated
intercompany balances and transactions. The Other Subsidiaries column includes financial information for those subsidiaries that do not guarantee
the First Lien Notes or the Second Lien Notes. In addition to the financial information of the Partnership, financial information of the Issuers includes
CSI Compressco Finance Inc., which had no assets or operations for any of the periods presented.
45
Year Ended December 31, 2023
(In Thousands)
Issuers
Guarantor
Subsidiaries
Other
Subsidiaries
Eliminations
Consolidated
$
— $
500,828 $
69,544 $
(184,244) $
Revenues
Cost of revenues (excluding depreciation and
amortization expense)
Depreciation and amortization
Selling, general, and administrative expense
Interest (income) expense, net
Other (income) expense, net
Equity in net (income) loss of subsidiaries
Income (loss) before taxes and discontinued
operations
Provision for income taxes
Income (loss) from continuing operations
Income from discontinued operations, net of taxes
Net income (loss)
Other comprehensive income
Comprehensive income (loss)
$
—
—
1,842
56,168
(153)
(48,376)
(9,481)
(1)
(9,480)
—
(9,480)
92
(9,388) $
363,157
66,436
40,985
(2,269)
1,304
(19,446)
50,661
2,285
48,376
—
48,376
92
48,468 $
31,543
10,973
4,725
—
1,368
—
20,935
1,489
19,446
—
19,446
92
19,538 $
(184,244)
—
—
—
—
67,822
(67,822)
—
(67,822)
—
(67,822)
(184)
(68,006) $
386,128
210,456
77,409
47,552
53,899
2,519
—
(5,707)
3,773
(9,480)
—
(9,480)
92
(9,388)
December 31, 2023
(In Thousands)
Guarantor
Subsidiaries
Issuers
Other Subsidiaries
Eliminations
Consolidated
$
$
$
$
— $
545,625
545,625 $
11,817 $
572,667
—
—
—
584,484
(38,859)
545,625 $
86,992 $
543,106
630,098 $
46,946 $
9,420
17,669
306,419
6,606
387,060
243,038
630,098 $
33,031 $
118,689
151,720 $
— $
(640,407)
(640,407) $
11,609 $
46,500
1,857
(3,832)
804
56,938
94,782
151,720 $
— $
—
—
(302,587)
—
(302,587)
(337,820)
(640,407) $
120,023
567,013
687,036
70,372
628,587
19,526
—
7,410
725,895
(38,859)
687,036
ASSETS
Current assets
Total non-current assets
Total assets
LIABILITIES AND PARTNERS’ CAPITAL
Other current liabilities
Long-term debt
Operating lease liabilities
Intercompany payables
Other long-term liabilities
Total liabilities
Total partners’ capital
Total liabilities and partners’ capital
Critical Accounting Policies and Estimates
This discussion and analysis of our financial condition and results of operations is based upon our consolidated financial statements. We
prepared these financial statements in conformity with U.S. GAAP. In preparing our consolidated financial statements, we make assumptions,
estimates, and judgments that affect the
46
reported amounts of assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the
periods presented. We base these estimates on historical experience, available information, and various other assumptions that we believe are
reasonable under the circumstances. We periodically evaluate these estimates and judgments, which may change as new events occur, as new
information is acquired, and with changes in our operating environment. Actual results are likely to differ from current estimates, and those
differences may be material.
While our significant accounting policies are more fully described in Note 2 – Summary of Significant Accounting Policies to our
consolidated financial statements, we believe that there were no critical accounting policies and estimates that affect the preparation of financial
statements.
Commitments and Contingencies
From time to time, we are involved in litigation relating to claims arising out of our operations in the normal course of business. While the
outcome of these lawsuits or other proceedings against us cannot be predicted with certainty, management does not consider it reasonably possible
that a loss resulting from such lawsuits or proceedings in excess of any amounts accrued has been incurred that is expected to have a material
adverse effect on our financial condition, results of operations or cash flows.
Recently Issued Accounting Pronouncements
For a discussion of new accounting pronouncements that may affect our consolidated financial statements, see Note 2 - “Summary of Significant
Accounting Policies, New Accounting Pronouncements,” in the Notes to Consolidated Financial Statements in this Annual Report.
Item 7A. Quantitative and Qualitative Disclosures about Market Risk.
Not applicable.
Item 8. Financial Statements and Supplementary Data.
Our financial statements and supplementary data for us and our subsidiaries required to be included in this Item 8 are set forth in Item 15 of
this Annual Report.
Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure.
None.
Item 9A. Controls and Procedures.
Conclusion Regarding the Effectiveness of Disclosure Controls and Procedures
Under the supervision and with the participation of our management, including the Principal Executive Officer and Principal Financial Officer
of our general partner, we conducted an evaluation of our disclosure controls and procedures, as such term is defined under Rule 13a-15(e)
promulgated under the Securities Exchange Act of 1934, as amended (the Exchange Act) as of the end of the period covered by this Annual
Report. Based on this evaluation, the Principal Executive Officer and Principal Financial Officer of our general partner concluded that our disclosure
controls and procedures were effective as of December 31, 2023.
Management’s Report on Internal Control over Financial Reporting
Management of our general partner is responsible for establishing and maintaining adequate internal control over financial reporting, as
such term is defined in Exchange Act Rule 13a-15(f). Our internal control over financial reporting is a process to provide reasonable assurance
regarding the reliability of our financial reporting for external purposes in accordance with accounting principles generally accepted in the United
States of America.
Our internal control over financial reporting includes those policies and procedures that (i) pertain to the maintenance of records that, in
reasonable detail, accurately and fairly reflect our transactions and dispositions of our assets; (ii) provide reasonable assurance that transactions
are recorded as necessary to permit preparation of
47
financial statements in accordance with generally accepted accounting principles and that our receipts and expenditures are being made only in
accordance with authorizations of our management and directors; and (iii) provide reasonable assurance regarding prevention or timely detection of
unauthorized acquisition, use or disposition of our assets that could have a material effect on our financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. In addition, projections of any
evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that
the degree of compliance with the policies or procedures may deteriorate.
Under the supervision and with the participation of management of our general partner, including the Principal Executive Officer and
Principal Financial Officer of our general partner, an evaluation of the effectiveness of our internal control over financial reporting as of
December 31, 2023 was conducted based on the framework in Internal Control – Integrated Framework issued by the Committee of Sponsoring
Organizations of the Treadway Commission (2013 framework) (“COSO”). Based on this assessment, management of our general partner has
determined that our internal control over financial reporting was effective as of December 31, 2023.
Changes in Internal Control over Financial Reporting
There were no changes in our internal control over financial reporting that occurred during the fourth quarter of the fiscal year ended
December 31, 2023, that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
Board of Directors of CSI Compressco GP LLC and the Unitholders of CSI Compressco LP
Opinion on internal control over financial reporting
We have audited the internal control over financial reporting of CSI Compressco LP (a Delaware limited partnership) and subsidiaries (the
“Partnership”) as of December 31, 2023, based on criteria established in the 2013 Internal Control—Integrated Framework issued by the Committee
of Sponsoring Organizations of the Treadway Commission (“COSO”). In our opinion, the Partnership maintained, in all material respects, effective
internal control over financial reporting as of December 31, 2023, based on criteria established in the 2013 Internal Control—Integrated Framework
issued by COSO.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), the
consolidated financial statements of the Partnership as of and for the year ended December 31, 2023, and our report dated March 1, 2024
expressed an unqualified opinion on those financial statements.
Basis for opinion
The Partnership’s management is responsible for maintaining effective internal control over financial reporting and for its assessment of the
effectiveness of internal control over financial reporting, included in the accompanying Management’s Report on Internal control over Financial
Reporting. Our responsibility is to express an opinion on the Partnerhsip’s internal control over financial reporting based on our audit. We are a
public accounting firm registered with the PCAOB and are required to be independent with respect to the Partnership 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 effective internal control over financial reporting was maintained in all material respects. Our audit included
obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, testing and evaluating the
design and operating effectiveness of internal control based on the assessed risk, and performing such other procedures as we considered
necessary in the circumstances. We believe that our audit provides a reasonable basis for our opinion.
Definition and limitations of internal control over financial reporting
A company’s internal control over financial reporting is a process designed to provide reasonable assurance regarding the reliability of financial
reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles. A
company’s internal control over financial reporting includes those policies and procedures that (1) pertain to the maintenance of records that, in
reasonable detail,
48
accurately and fairly reflect the transactions and dispositions of the assets of the company; (2) provide reasonable assurance that transactions are
recorded as necessary to permit preparation of financial statements in accordance with generally accepted accounting principles, and that receipts
and expenditures of the company are being made only in accordance with authorizations of management and directors of the company; and (3)
provide reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that
could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also, projections of any
evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because of changes in conditions, or that
the degree of compliance with the policies or procedures may deteriorate.
/s/ GRANT THORNTON LLP
Houston, Texas
March 1, 2024
49
Item 9B. Other Information.
During the three months ended December 31, 2023, none of our general partner’s directors or officers (as defined in Rule 16a-1(f) of the
Exchange Act) adopted, modified or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as defined in Item
408 of Regulation S-K.
Item 9C. Disclosure Regarding Foreign Jurisdictions that Prevent Inspections.
Not Applicable.
PART III
Item 10. Directors, Executive Officers, and Corporate Governance.
Corporate Governance and Director Independence
Our general partner is an indirect, wholly owned subsidiary of Spartan and has sole responsibility for conducting our business and
managing our operations. The members of our board of directors (our “Board”) oversee our operations. Unitholders are not entitled to elect the
members of our Board or directly or indirectly participate in our management or operation. All of the members of our Board are appointed by
Spartan Energy Holdco LLC, a direct, wholly owned subsidiary of Spartan. We do not hold annual unitholder meetings. References in this Part III to
the “Board,” “directors,” “executive officers,” or “officers” refer to the Board, directors, executive officers, and officers of our general partner, unless
otherwise indicated.
Our Board has adopted Corporate Governance Guidelines that outline important policies and practices regarding our governance and
provide a framework for the functioning of the Board and its committees. The Corporate Governance Guidelines and the charter of the Audit
Committee are available in the Corporate Governance section of the Investor Relations area of our website at www.csicompressco.com. In addition,
our Board and our general partner have adopted a Code of Business Conduct and a Financial Code of Ethics and a Policy on Trading in
Partnership Securities, copies of which are also available in the Corporate Governance section of the Investor Relations area of our website at
www.csicompressco.com. We will post on our website all waivers to or amendments of our Code of Business Conduct and Financial Code of Ethics
and a Policy on Trading in Partnership Securities that are required to be disclosed by applicable law or the listing requirements of the NASDAQ. We
will provide to our unitholders, without charge, printed copies of the foregoing materials upon written request to Investor Relations, CSI Compressco
LP, 1735 Hughes Landing Boulevard, Suite 200, The Woodlands, Texas, 77380.
The NASDAQ does not require a listed limited partnership like us to have a majority of independent directors on the Board or to establish a
compensation committee or a nominating committee. Our Board currently consists of nine directors, five of whom, Denise G. Essenberg, Stephen
R. Gill, James R. Larson, Joseph P. McElroy and Michael J. Tucker are independent as defined under the listing standards of the NASDAQ.
Name
Derek J. Anchondo
Jonathan W. Byers
Denise G. Essenberg
Ted A. Gardner
Stephen R. Gill
John E. Jackson
James R. Larson
Joseph P. McElroy
Riplee L. Parkening
Matthew B. Pitcock
Robert W. Price
Age
50
45
65
66
66
65
74
39
35
41
56
Position with CSI Compressco GP
Assistant General Counsel
Chief Financial Officer, Director
Independent Director
Director, Chairman of the Board of Directors
Independent Director
Chief Executive Officer, Director
Independent Director
Independent Director
Controller
Vice President North America Sales, Compression Services
Chief Operating Officer, Director
50
Name
Rodney P. Pruski
Michael J. Tucker
Age
51
52
Position with CSI Compressco GP
Vice President of Operations
Independent Director
Directors and Executive Officers
.Our directors hold office until the earlier of their death, resignation, removal, or until their successors have been appointed. Our executive
officers are appointed by and serve at the discretion of our Board. There are no family relationships among any of our directors or executive officers.
The following table shows information regarding our current directors and executive officers. Directors are appointed for one-year terms.
Biographical summaries of the directors and executive officers, including the experiences, qualifications, attributes, and skills of each
director that have been considered by the Board in determining that these individuals should serve as directors, are set forth below. See “Item 12.
Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters - Beneficial Ownership of Certain Unitholders
and Management” included under Item 12 of this Annual Report for information regarding the number of common units owned by each individual.
Derek J. Anchondo has served as Assistant General Counsel of our general partner since August 2021. Prior to his current role, he was a
Partner with large domestic and international law firms from 2011 to 2021. Prior to that, Mr. Anchondo held the role of Chief Counsel and Division
Counsel with Pride International from 2006 to 2011 and held the role of Counsel – U.S. Operations with Hanover Compressor Company from 2003
to 2006. He began his career as an attorney in 1999 with large domestic and international law firms. Mr. Anchondo received his B.A. from Trinity
University and his J.D. from the University of Houston Law Center. He is admitted to practice in the State of Texas and the State of New York.
Jonathan W. Byers has served as the Chief Financial Officer of our general partner and as a member of its Board since January 2021 and
as Head of Corporate Development and Secretary of Spartan since 2010. Prior to joining Spartan, Mr. Byers served as Vice President, Corporate
Development for Price Gregory Services (“Price Gregory”), a leading energy infrastructure services provider specializing in pipeline construction.
Prior to joining Price Gregory, Mr. Byers held positions at SCF Partners (an energy focused investment firm) and General Atlantic (a global, growth
focused private equity firm). Prior to General Atlantic, Mr. Byers was employed with Goldman Sachs Group in the Investment Banking Division. Mr.
Byers holds a B.S. in Business Administration from Georgetown University and an M.B.A. from Harvard Business School.
Denise G. Essenberg has served as an independent director of our general partner’s Board since February 2021. Ms. Essenberg is a
retired Partner with PwC, retiring in June 2019 after forty years serving numerous insurance clients across the property/casualty, life and health
payor sectors of the insurance industry and advising on acquisitions, pre- and post-transaction integration issues, business divestitures and the
adoption of new technologies. Ms. Essenberg served as the managing partner of the PwC Grand Rapids and Hartford offices from 2003 to 2008
and 2008 to 2011, respectively, with oversight and responsibility for client service, office operations and resource management and was the audit
transformation leader of PwC’s insurance practice from 2014 to 2019. Ms. Essenberg has served on the board of directors and as a member of its
audit and compliance committee and finance committee of Health Alliance Plan of Michigan since January 2021 and as a member of the board of
directors and audit committee chairperson of Atain Insurance Company and Atain Specialty Insurance Company since June 2020. In December
2021, Ms. Essenberg was elected to the board of directors and was appointed audit committee chairperson of Frankenmuth Mutual Insurance
Company. Ms. Essenberg received her B.A. from Michigan State University and attended the Kellogg School of Management Women’s Director
Development Program at Northwestern University in 2015.
Ted A. Gardner has served as a director and as Non-Executive Chairman of our general partner’s Board since January 2021. Mr. Gardner
is a co-founder and Managing Partner of Silverhawk Capital Partners. Mr. Gardner is currently a director of Incline Energy Partners, L.P., Kinder
Morgan, Inc. (NYSE: KMI), Meridian Chemicals and Spartan. He was previously a director of Kinder Morgan Energy Partners, Athlon Energy,
Summit Materials Inc. and Encore Acquisition Company. Ted earned a B.A. degree in Economics from Duke University and both a J.D. and an MBA
from the University of Virginia.
51
Stephen R. Gill has served as an independent director of our general partner’s Board and as member of its Audit Committee since January
2021. Mr. Gill has served as the Chief Executive Officer of Lindsayca Solutions, an EPC firm specializing in production and processing facilities,
since December 2018. From March 2017 to December 2018, Mr. Gill was retired. From January 2014 to January 2017, Mr. Gill was the Chief
Executive Officer of Valerus, a global provider of compression, production, and processing equipment and turnkey facilities. Prior to Valerus, Mr. Gill
served in various senior positions at Exterran Corporation (NYSE: EXTN) and Hanover Compression Company, including Vice President –
International and at Ingersoll Rand & Dresser Rand. Mr. Gill holds a B.S. degree in Mechanical Engineering from Texas A&M University.
John E. Jackson has served as the Chief Executive Officer of our general partner and as a member of its Board since January 2021 and
as President and Chief Executive Officer of Spartan since 2010. Prior to joining Spartan, Mr. Jackson was the Chairman and CEO of Price Gregory.
Prior to serving in his roles at Price Gregory, Mr. Jackson served as President and Chief Executive Officer of Hanover Compressor Company. Prior
to that, he held several positions at Duke Energy Field Services, including Chief Financial Officer, and Union Pacific Resources. Mr. Jackson has
served on the board of directors of Main Street Capital Corporation (NYSE: MAIN) since May 2014. He was previously a director of CNX Midstream
Partners and Basic Energy Services, Inc. Mr. Jackson holds a B.B.A. in Accounting from Baylor University.
James R. Larson has served as an independent director of our general partner’s Board and as Chairman of its Audit Committee since July
2011 and as a member of its Conflicts Committee since April 2012. Since January 1, 2006, Mr. Larson has been retired. From September 2005 until
January 1, 2006, Mr. Larson served as senior vice president of Anadarko Petroleum Corporation (“Anadarko”). From December 2003 to September
2005, Mr. Larson served as senior vice president, finance and chief financial officer of Anadarko. From 2002 to 2003, Mr. Larson served as senior
vice president, finance of Anadarko where he oversaw treasury, investor relations, internal audits and acquisitions and divestitures. From 1995 to
2002, Mr. Larson served as vice president and controller of Anadarko where he was responsible for accounting, financial reporting, budgeting,
forecasting, and tax. Prior to that, he held various tax and financial positions within Anadarko after joining the company in 1981. Mr. Larson currently
serves as a director, chairman of the audit committee and a member of the governance committee of Magnolia Oil & Gas Corporation, a publicly
traded company that is subject to the reporting requirements of the Exchange Act. From September 2006 until June 2018, Mr. Larson served as a
director of EV Management, LLC, the general partner of EV Energy GP, which was the general partner of EV Energy Partners, L.P. a publicly traded
limited partnership. Mr. Larson is a current member of the American Institute of Certified Public Accountants, Financial Executives International, the
Tax Executives Institute and the National Association of Corporate Directors. He received his B.B.A. degree in business from the University of Iowa.
Joseph P. McElroy has served as an independent director of our general partner’s Board since July 2023. Mr. McElroy has fifteen years of
analytical and investing experience, with the past eight years at Merced Capital, preceded by analytical and investment positions at Merrill Lynch,
Norwest Equity, and CarVal. He received his B.A. in Finance, Investment, and Banking from the University of Wisconsin and an M.B.A. from
Harvard Business School.
Riplee L. Parkening has served as the Principal Accounting Officer as of October 2022. She served as Controller of the Partnership since July
2022 and as Director of Accounting since 2018. Prior to joining the Partnership, Ms. Parkening served as Controller of Premium Inspection and
Testing from 2016 to 2018 where her responsibilities included managing the accounting process, financial reporting, and working with the external
auditors. Prior to joining Premium Inspection and Testing, Ms. Parkening held positions at Martin Resource Management Corporation from 2011 to
2016. Her responsibilities included managing the accounting department, internal operational reporting, and communicating with auditors. Ms.
Parkening received her B.B.A. in accounting from The University of Texas at Tyler, is a certified public accountant in the State of Texas, and a
certified fraud examiner.
Matthew B. Pitcock has served as Vice President North America Sales, Compression Services of our general partner since January 2020
and as Regional Sales Manager for the Permian Basin from March 2014 to January 2020. Mr. Pitcock returned to work for our general partner in
2014 after serving for two years as a Category Management Advisor (Compression) at Devon Energy. In 2006, Mr. Pitcock joined the Account
Manager Training Program of Compressor Systems Inc., which was acquired by the partnership in 2014. He continued to serve in several sales
leadership roles with increasing responsibilities for Compressor Systems through 2012. Mr. Pitcock received his B.B.A. in Management from Angelo
State University in 2004 and his M.B.A from Oklahoma Christian University in 2012.
52
Robert W. Price has served as the Chief Operating Officer of our general partner and as a member of its Board since January 2021 and as
Chief Operating Officer of Spartan since 2010. Prior to joining Spartan, Mr. Price held senior management positions with Exterran Corporation
(NYSE: EXTN), Hanover Compressor Company and Ariel Compressor Corporation. Mr. Price has spent most of his career developing and
executing gas treating and processing applications in the U.S. and Latin America. Mr. Price holds a B.S. in Mechanical Engineering from The
University of Notre Dame and an M.B.A from Carnegie Mellon.
Rodney P. Pruski has served as Vice President of Operations of our general partner since January 2022, responsible for North American
Compression Services, Aftermarket Operations and Supply Chain. Mr. Pruski joined Compressor Systems, Inc. in November 1998, which was
acquired by the partnership in 2014. He served in numerous roles as Controller (1999-2006), Operational Support (2006-2012), Regional Manager
for South Texas (2012-2020), and as Director of Operations (2020-2022). Mr. Pruski earned a B.B.A. in Accounting and Computer Information
Systems from Texas State University.
Michael J. Tucker has served as an independent director of our general partner’s Board since October 2022. Mr. Tucker is the Founder
and Managing Partner of Orvieto Partners, L.P. Mr. Tucker has twenty-six years of experience investing in the publicly traded debt and equity
securities companies in the gaming, lodging, leisure and energy sectors and 28 years of experience in finance. Before founding Orvieto Partners,
Mr. Tucker was a Partner/Portfolio Manager at PAR Capital Management, Inc, a Boston-based long/short equity fund founded in 1990, which makes
concentrated investments based on narrowly focused and rigorous fundamental research with a long-term orientation. Prior to joining PAR capital,
Mr. Tucker was a Partner and Portfolio Manager at Andover Capital Advisors, LLC, a long-short hedge fund that made concentrated investments in
the debt and equity securities of companies with levered capital structures. Before Andover Capital, Mr. Tucker worked at Standish Mellon Assets
Management (formerly Standish, Ayer, & Wood, Inc.) He serves on the Providence College Business Advisory Council and the Men’s Basketball
Vision Team. Mr. Tucker is a graduate of Providence College and received an MBA from the Carroll School of Management at Boston College.
Board Meetings and Committees
During 2023, the Board held seven meetings. The standing committees of the Board during 2023 consisted of an Audit Committee. During
2023, the Audit Committee held five meetings. The Conflicts Committee did not hold any meetings during 2023.
Audit Committee. During 2023, the Audit Committee was composed of Mr. Larson, as Chairman, Mr. Gill and Ms. Essenberg. The
purposes of the Audit Committee are to (i) oversee the financial and reporting processes of the Partnership and the general partner, and the audit of
the Partnership’s financial statements, (ii) assist the Board in fulfilling its oversight responsibilities with regard to the integrity of the Partnership’s
financial statements, the Partnership’s and the general partners’ compliance with legal and regulatory requirements, the qualifications,
independence and performance of the Partnership’s independent registered public accounting firm, and the effectiveness and performance of the
Partnership’s and the general partner’s internal audit function, and (iii) perform such other functions as the Board may assign from time to time. The
Audit Committee has sole authority to retain and terminate our independent registered public accounting firm, approve all auditing services and
related fees and terms, and approve any non-audit service to be performed by our independent registered public accounting firm. To promote the
independence of its audit, the Audit Committee consults separately and jointly with the independent registered public accounting firm, our internal
auditor, and management.
As required by NASDAQ and SEC rules regarding audit committees, the Board has reviewed the qualifications of the Audit Committee and
has determined that no current committee member has a relationship with us that might interfere with the exercise of his independence from us or
our affiliates. Included within such determination, the Board has determined that Messrs. Larson and Gill and Ms. Essenberg are independent as
defined in Section 10A of the Exchange Act and the listing standards of the NASDAQ. In addition, the Board has determined that Mr. Larson, the
Chairman of the Audit Committee, is an audit committee financial expert within the definition established by the SEC.
Conflicts Committee. Membership of the Conflicts Committee, which was formed in April 2012, was on an ad hoc basis during 2023. It is
anticipated that committee membership will be established on an ad hoc basis going forward. The purposes of the Conflicts Committee are to (i) as
requested by the Board, review and evaluate any
53
potential conflicts of interest between us and the owner of our general partner or its affiliates or us and Spartan or its subsidiaries or affiliates, and
(ii) carry out any other duties assigned by the Board that relate to potential conflicts of interest between us and the owner of our general partner or
its affiliates or us and Spartan or its subsidiaries or affiliates. The Conflicts Committee has the sole authority to retain and terminate any consultants,
attorneys, independent accountants or other service providers to assist it in the evaluation of conflicts matters, including the sole authority to
approve their fees and other terms of retention.
As required by the Third Amended and Restated Agreement of Limited Partnership of the Partnership, the Board reviewed the
independence of Messrs. Larson and Gill and Ms. Essenberg and determined that each of them meets the independence standards established
thereunder as required for service on the Conflicts Committee. Included within such determination, the Board also determined that each of Messrs.
Larson, Gill and Tucker and Ms. Essenberg was independent as defined in Section 10A of the Exchange Act and the listing standards of the
NASDAQ.
Item 11. Executive Compensation.
Compensation of Named Executive Officers
Introductory Note
Beginning in February 2021, we reimbursed our general partner under the terms of our partnership agreement for any expenses and
expenditures incurred or payments made on our behalf, including operating expenses related to our operations and for the provision of various
general and administrative services for our benefit.
Pursuant to the Management Services Agreement dated November 10, 2021, the general partner, Spartan Operating and Spartan GP will
provide certain services reasonably necessary for the operation of the businesses of the Partnership and its subsidiaries, Spartan, Spartan GP and
Spartan Treating, including certain corporate and general and administrative services. The general partner and Spartan GP will allocate any costs
and expenses incurred on a reasonable basis, and the parties will reimburse such other parties for costs and expenses allocated to them.
Summary Compensation
The following table sets forth the aggregate compensation earned by (i) each individual serving as our President or Chief Executive Officer
(our “Principal Executive Officer”), and (ii) each of our two other most highly compensated executive officers (each a “Named Executive Officer” or
“NEO”) for the fiscal years ended December 31, 2023 and 2022.
54
Summary Compensation Table
Name and Principal Position
Year
John E. Jackson
Chief Executive Officer, Director
Jonathan W. Byers
Chief Financial Officer, Director
Robert W. Price
Chief Operations Officer, Director
2023
2022
2023
2022
2023
2022
Salary
($)
529,616 $
516,202 $
422,962 $
412,962 $
422,962 $
412,962 $
$
$
$
$
$
$
Bonus
($)
Unit Awards
($)
Non-Equity Incentive
(1)
Plan Compensation
All Other
Compensation
(2)
($)
($)
— $
— $
— $
— $
— $
— $
— $
— $
— $
— $
— $
— $
732,000 $
660,000 $
365,000 $
330,000 $
365,000 $
330,000 $
23,496 $
19,623 $
23,496 $
16,373 $
23,496 $
19,623 $
(3)
Total
($)
1,285,112
1,195,825
811,458
759,335
811,458
762,585
(1) Amounts shown in the “Non-Equity Incentive Compensation Plan” column are the earned portions of awards granted under CSI Compressco’s Cash Incentive Compensation Plan
(the “CICP”) for the annual performance period ending December 31, 2022, and the annual performance period ending December 31, 2023. Such awards are payable, to the extent
earned, based on financial and operational performance measures. Amounts earned as of December 31, 2023, are expected to be paid by April 2024.
(2) The amounts reflected represent (i) matching contributions under the CSI Compressco 401(k) Retirement Plan for 2022 and 2023, and (ii) the value of distribution equivalent rights
settled in connection with the vesting of phantom unit awards that relate to CSI Compressco’s common units which was $12,246 for Mr. Jackson, Mr. Byers, and Mr. Price in fiscal
year ended December 31, 2023.
(3) As noted above, the formula that determines the compensation costs allocated to us pursuant to the Management Services Agreement does not divide the costs between specific
compensation elements, therefore out of an abundance of caution we have chosen to report the total compensation provided to each of the applicable Named Executive Officers for
fiscal years 2022 and 2023 within this column.
Salary and Bonus Compensation
None of the NEOs were a party to an employment agreement during the 2023 year. Base salary amounts were determined by the Board of
Directors. As noted above, each NEO participated in the CICP during the 2023 year. The CICP budget pool for the 2023 awards under the CICP is
based on EBITDA and Net Debt to EBITDA and pays out in accordance with the following table:
EBITDA
Net Debt to EBITDA
Payout %
Threshold
$120M
5.0x
30%
Target
$130M
4.8x
100%
Maximum
$140M
4.6x
150%
Individual bonus payouts may be increased or decreased by 0-200% of the CICP target based on individual performance at the discretion of the
Board of Directors. The 2023 CICP target for John Jackson was 120% and 75% for Jonathan Byers and Robert Price, respectively.
Retirement, Health and Welfare Benefits
Our employees are eligible to participate in a variety of health and welfare and retirement programs sponsored by the Partnership. Our
NEOs are generally eligible for the same benefit programs on the same basis as the remainder of our employees. Our health and welfare programs
are intended to protect employees against catastrophic loss and to encourage a healthy lifestyle. These health and welfare programs include
medical, wellness, pharmacy, dental, life insurance, short-term and long-term disability insurance, and insurance against accidental death and
disability.
55
401(k) Plan
The NEOs became eligible to participate in the CSI Compressco 401(k) Retirement plan (the “CSI Compressco 401(k) Plan”) effective
January 1, 2022. The CSI Compressco 401(k) Plan is intended to supplement a participant’s personal savings and social security. Under this plan,
the NEOs may contribute on a pre-tax basis up to 70% of their compensation, subject to an annual maximum established under the Internal
Revenue Code (the “Code”). The Partnership makes a matching contribution under these plans equal to 50% of the first 8% of the NEOs annual
compensation that is contributed to the plan. All employees (other than nonresident aliens) who have reached the age of eighteen are eligible to
participate in the CSI Compressco 401(k) Plan beginning on the first day of the month following their completion of thirty (30) days of service with
us.
Perquisites
Perquisites (“perks”) are not a material component of our compensation. In general, NEOs do not receive reimbursements for meals, airline
and travel costs other than those costs allowed for all employees, or for tickets to sporting events or entertainment events, unless such costs are
incurred for business purposes. During 2023, no NEO received an allowance from us for any of the above or a reimbursement for any expense
incurred for non-business purposes.
Outstanding Equity Awards at Fiscal Year End
The Partnership continued to maintain our LTIP following the GP Sale, and each of Messrs. Jackson, Byers and Price were eligible to
receive a grant of phantom unit awards during fiscal year 2021. Each phantom unit award granted on February 19, 2021, was granted in tandem
with distribution equivalent rights (“DERs”) that entitle the award holder to receive an additional number of units equal in value to any distributions
we pay during the period the award is outstanding times the number of units subject to the award. The awards are intended to cover equity-based
incentive awards for these NEOs for a period of three years and no new equity-based awards are currently planned for Messrs. Jackson, Byers and
Price until 2024.
The following table discloses the number and value of unvested phantom unit awards granted under the CSI Compressco LP Second
Amended and Restated 2011 Long Term Incentive Plan as of December 31, 2023.
Outstanding Equity Awards at Fiscal Year End Table
Name
John E. Jackson
Jonathan W. Byers
Robert W. Price
Unit Awards
(1)
Number of Units
that Have Not
Vested
(#)
153,062 $
153,062 $
153,062 $
Market Value of
Units that Have
Not Vested
($)
(2)
249,491
249,491
249,491
(1) One-third of the unvested phantom unit awards granted on February 19, 2021, vested on February 19, 2022, and one-third vested on February 19, 2023, and February 19, 2024.
(2) All outstanding unit awards relate to our common units. Market value is determined by multiplying the number of units that have not vested by $1.63, the closing price of our common
units on December 29, 2023.
Potential Payments upon a Change of Control or Termination
For the majority of the 2023 year, we did not have a severance plan for, or any agreement with, any Named Executive Officer that would
require us to make any termination payments. However, on December 19, 2023, in connection with the Merger Agreement between the Partnership
and Kodiak, we entered into individual agreements with the Named Executive Officers (the “CIC Agreements”) pursuant to which, each NEO is
eligible to receive certain payments and benefits in the event they are terminated by us without Cause (as defined in the CIC Agreement) or in the
event the NEO terminates his employment for Good Reason (as defined in the CIC Agreement) (in each case, a “Qualifying Termination”) on or
within the twelve month period following the closing of the Merger.
56
Upon a Qualifying Termination, each NEO will be eligible to receive: (i) a severance payment in an amount equal to 2 (or, in the case of Mr.
Jackson, 2.5) times the sum of (x) the NEO’s annualized base salary immediately prior to the date of termination plus (y) the target value of the
NEO’s annual cash bonus opportunity, if any, for the calendar year during which the date of termination occurs; (ii) a pro-rated portion of the NEO’s
target annual bonus for the calendar year that includes the NEO’s date of termination, multiplied by a fraction, (x) the numerator of which equals the
number of calendar days that the NEO was employed by us or one of our affiliates during the calendar year in which the date of termination occurs
and (y) the denominator of which equals 365 or 366, as applicable; and (iii) twenty-four (24) months of continued group health coverage or
payments for the costs thereof following the date of termination. Each NEO will be subject to customary restrictive covenant agreements pursuant to
the CIC Agreements, including a noncompetition restriction for a two year period following the date of NEO’s termination of employment.
In addition to the CIC Agreements, under the LTIP, our general partner’s Board of Directors, in its sole discretion, may accelerate the
vesting of restricted units, phantom units, and performance phantom units held by our Named Executive Officers upon termination of their
employment. Solely for purposes of these disclosures, we have assumed that all outstanding unit awards would be accelerated if the Named
Executive Officer’s employment was terminated without cause in connection with a change of control, or upon the death, disability, or retirement of
such officer, although such an acceleration is not a guaranteed benefit. The amount that each NEO who was providing services to us as of
December 31, 2023, could receive in connection with the potential acceleration of their outstanding equity awards would have been $249,491.
Director Compensation
Each director who is not an employee of our general partner or any of its subsidiaries, receives non-cash compensation of $60,000 per year
for attending regularly scheduled board meetings. The non-cash compensation is paid for the upcoming service year in the form of phantom unit
awards that have an intended grant date value of $60,000, prorated for any newly elected director to such director’s date of election and that vest
over the service year as set forth below. All such awards of phantom units are granted under our LTIP. Each phantom unit award granted to the
directors on February 28, 2023, was granted in tandem with distribution equivalent rights (“DERs”) that entitle the award holder to receive an
additional number of units equal in value to any distributions we pay during the period the award is outstanding times the number of units subject to
the award. Directors are reimbursed for out-of-pocket expenses incurred in connection with their service as directors. In addition, each non-
employee director is paid an annual cash retainer of $60,000 per year, paid in quarterly cash installments. Directors who are appointed as chairmen
of the Audit Committee receive an additional cash retainer of $10,000 per year paid in quarterly installments.
Directors who are also our officers or employees, or officers or employees of our general partner or any of its subsidiaries, did not receive any
compensation for duties performed as our directors. Consequently, none of Mr. Jackson (our current Chief Executive Officer), Mr. Byers (our current
Chief Financial Officer) or Mr. Price (our current Chief Operating Officer) was compensated for their respective service to us as a director during
2023.
57
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 year ended December 31, 2023.
Name
Denise Essenberg
Ted Gardner
Stephen Gill
James R. Larson
Michael Tucker
Joseph McElroy
(5)
(4)
Director Compensation Table
Fees Earned or
(1)
Paid in Cash
Unit Awards
(2)
All Other
Compensation
(3)
Total
$
$
$
$
$
$
60,000 $
60,000 $
60,000 $
70,000 $
60,000 $
30,000 $
60,000 $
60,000 $
60,000 $
60,000 $
60,000 $
— $
1,727 $
1,727 $
1,727 $
1,727 $
— $
— $
121,727
121,727
121,727
131,727
120,000
30,000
(1) The amounts in this column reflect the annual cash retainer payments earned for service as a non-employee director during 2023.
(2) The amounts included in the “Unit Awards” column reflect the aggregate grant date fair value of awards granted on February 28, 2023 (which will vest on February 28, 2024), in
accordance with FASB ASC Topic 718. Phantom unit awards granted under the LTIP on February 28, 2023, relate to our common units and were valued at $1.36 per common unit
in accordance with FASB ASC Topic 718. As of December 31, 2023, each of Messrs. Essenberg, Gardner, Gill, and Larson held 44,118 outstanding phantom units.
(3) The amounts reflected represent the value of distribution equivalent rights settled in connection with the vesting of unit awards that relate to CSI Compressco’s common units.
(4) In 2023 Mr. Larson received an additional $10,000 cash retainer for his service as the Board of Directors Audit Committee Chairman.
(5) In 2023 Mr. McElroy elected that his cash retainer be paid to Merced Capital, L.P.
Indemnification Agreements
We have entered into indemnification agreements with each of our current directors and officers, which will provide that we will indemnify
them to the fullest extent permitted by our Third Amended and Restated Agreement of Limited Partnership, Bylaws, and applicable law. The
indemnification agreement also provides that our directors and officers will be entitled to the advancement of fees as permitted by applicable law
and sets out the procedures required for determining entitlement to and obtaining indemnification and expense advancement. In addition, our
charter documents provide that each of our directors and officers and any person serving at our request as a director or officer of another
corporation, partnership, joint venture, trust, or other enterprise shall be indemnified to the fullest extent permitted by law in connection with any
threatened, pending, or completed action, suit, or proceeding (including civil, criminal, administrative, or investigative proceedings) arising out of or
in connection with his or her services to us or to another corporation, partnership, joint venture, trust, or other enterprise, at our request. We
purchase and maintain insurance on behalf of any person who is a director or officer of the aforementioned corporation, partnership, joint venture,
trust, or other enterprise, against any liability asserted against him or her and incurred by him or her in any such capacity, or arising out of his or her
status as an officer or director, subject to the terms and conditions of that insurance.
Management and Compensation Committee Interlocks and Insider Participation
As previously discussed, our Board is not required to maintain, and does not maintain, a compensation committee. Please read “Item 13.
Certain Relationships and Related Party Transactions, and Director Independence” below, for information about relationships among us, our former
general partner, and TETRA.
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related Stockholder Matters.
Beneficial Ownership of Certain Unitholders and Management
The following table sets forth the beneficial ownership of our units held by each person who beneficially owned 5% or more of our
outstanding common units as of February 21, 2024, and (i) our directors; (ii) our Named Executive Officers (“NEOs”); and (iii) our directors and
executive officers as a group.
The amounts and percentages of units beneficially owned are reported on the basis of regulations of the SEC governing the determination of
beneficial ownership of securities. Under the rules of the SEC, a person is deemed to be a “beneficial owner” of a security if that person has or
shares “voting power,” which includes the power to vote
58
or to direct the voting of such security, or “investment power,” which includes the power to dispose of or to direct the disposition of such security. A
person is also deemed to be a beneficial owner of any securities of which that person has a right to acquire beneficial ownership within 60 days.
Under these rules, more than one person may be deemed a beneficial owner of the same securities and a person may be deemed a beneficial
owner of securities as to which he has no economic interest.
Except as indicated by footnote, the persons named in the following table have sole voting and investment power with respect to all units shown
as beneficially owned by them, subject to community property laws where applicable.
Name and Business Address of Beneficial Owner
Common Units Beneficially
Owned
Spartan Energy Partners LP
1735 Hughes Landing, Boulevard, Suite 200
The Woodlands, Texas 77380
Invesco Ltd.
1555 Peachtree Street, NE, Suite 1800
Atlanta, GA 30309
Merced Capital, L.P.
601 Carlson Parkway, Suite 200
Minnetonka, MN 55305
Hill City Capital Master Fund LP
89 Nexus Way
Camara Bay, Grand Cayman KY1-9009
John E. Jackson
Jonathan W. Byers
Robert W. Price
Denise Essenberg
Ted Gardner
James R. Larson
Stephen R. Gill
Joseph McElroy
Michael J. Tucker
Director and executive officers as a group (14 persons)
(2)
(3)
(4)
(5)
(6)
63,824,877
10,234,420
7,736,528
7,459,259
830,120
705,524
523,484
120,028
1,296,139
270,775
290,028
—
4,343,268
9,075,372
Percentage of
Class
(1)
44.9 %
7.2 %
5.4 %
5.3 %
*
*
*
*
*
*
*
3.1 %
6.4 %
* Less than 1%.
(1) Reflects common units beneficially owned as a percentage of common units outstanding.
(2) The number of Partnership Common Units is based solely on a Schedule 13D/A filed by Spartan Energy Partners LP (“Spartan LP”) on December 21, 2023. The common units
beneficially owned by Spartan Energy Partners LP are directly held of record by our general partner, CSI Compressco GP LLC, and CSI Compressco Investment LLC, each a
wholly owned subsidiary of Spartan Energy Holdco LLC. Each of our general partner and CSI Compressco Investment, L.L.C. has sole voting and investment power over the
common units held by them. As a result, Spartan Energy Holdco LLC has indirect, sole voting and investment power over the common units held by our general partner and CSI
Compressco Investment LLC.
(3) Based on a Schedule 13G/A filed by Invesco Ltd. on February 12, 2024. Invesco Ltd., in its capacity as a parent holding company to its investment advisers, may be deemed to
beneficially own 10,234,420 common units which are held of record by clients of Invesco Ltd. Invesco Advisers, Inc. is a subsidiary or Invesco Ltd. and it advises the Invesco
SteelPath MLP Select 40 Fund which owns the securities reported above. However, no one individual has greater than 5% economic ownership. The shareholders of the Fund
have the right to receive or the power to direct the receipt of dividends and proceeds from the sale of securities listed above.
(4) Based solely on a Schedule 13D/A filed by Merced Capital, L.P. on December 21, 2023. The common units beneficially owned by Merced Capital, L.P. are held for the account of
Merced Partners Limited Partnership, Merced Partners V, L.P. and Athilon Capital Corp. LLC. Merced Capital, L.P. is the general partner of Merced Partners Limited Partnership,
Merced Partners V, L.P. and Athilon Capital Corp. LLC. Merced Capital, L.P. is managed by Series E of Merced Capital Partners, LLC, a series of a Delaware limited liability
company. David A. Ericson, Vincent C. Vertin and Stuart B. Brown have voting control over the interests in Series E of Merced Capital Partners, LLC and may be deemed to have
voting and investment control over the subject common units.
(5) Based solely on a Schedule 13G/A filed by Hill City Capital Master Fund LP on February 13, 2024. The common units beneficially owned by Hill City Capital Master Fund LP are
directly held of record by Hill City Capital Master Fund LP. Hill City Capital Master Fund LP is managed by Hill City Capital LP. Herbert Frazier is the Managing Member of Hill City
Capital LP and may be considered to have voting and investment control over the subject common units.
59
(6) The common units beneficially owned by Michael J. Tucker include 44,118 held directly by Mr. Tucker and 4,299,150 which are directly held by Orvieto Fund LP, a Delaware limited
partnership. Orvieto Fund LP is managed by Orvieto Partners, LP, a Delaware limited partnership. As Managing Partner of Orvieto Partners, L.P., Mr. Tucker has voting and
investment control of Orvieto Partners, LP, and may be deemed to have voting and investment control over the common units.
Equity Compensation Plan Information
The following table provides information as of December 31, 2023, regarding compensation plans (including individual compensation
arrangements) under which our common units are authorized for issuance.
Plan Category
Equity compensation plans
approved by security holders
Equity compensation plans not
approved by security holders
(1)
Total
Number of Securities to be
Issued upon Exercise of
Outstanding Options,
Warrants or Rights
Weighted-Average
Exercise Price of
Outstanding Options,
Warrants or Rights
Number of Securities Remaining
Available for Future Issuance Under
Equity Compensation Plans (Excluding
Securities Shown in the First Column)
1,763,587 $
— $
1,763,587 $
—
(2)
—
—
9,911,311
—
9,911,311
(1) Consisted of the Second Amended and Restated 2011 Long Term Incentive Plan as of December 31, 2023.
(2) Represents phantom unit awards and performance phantom unit awards outstanding under the Second Amended and Restated 2011 Long Term Incentive Plan as of December 31,
2023. These phantom unit awards and performance phantom unit awards do not have an exercise price.
Item 13. Certain Relationships and Related Transactions, and Director Independence.
Certain Transactions
Review, Approval or Ratification of Transactions with Related Persons
The related person transactions in which we engaged in 2023 were typically of a recurring, ordinary course nature, were previously made
known to the Board of our general partner, and generally were of the sort contemplated by our Partnership Agreement. We do not have formal,
specified policies for the review, approval or ratification of transactions required to be reported under paragraph (a) of Regulation S-K Item 404.
However, because related person transactions may result in potential conflicts of interest among management and board-level decision makers, our
Partnership Agreement does set forth procedures that the general partner may utilize in connection with resolutions of potential conflicts of interest,
including the referral of such matters to an independent conflicts committee for its review and approval or disapproval of such matters.
Transactions with our General Partner and its Affiliates
As of February 28, 2024, Spartan and certain of its subsidiaries, including our general partner, owned 63,824,877 common units, which
constitutes a 44.8% limited partner interest in us, and an approximate 0.5% general partner interest in us. Spartan is, therefore, a “related person” to
us as such term is defined by the SEC.
Distributions and Payments to the General Partner and its Affiliates
We will generally make cash distributions 99.5% to unitholders on a pro rata basis, including our general partner, as the holders of
63,824,877 common units and approximately 0.5% to our general partner.
For the year ended December 31, 2023, we paid aggregate cash distributions of approximately $5.7 million on our common units, and
approximately $27,000 on our general partner interest. On February 14, 2024, we paid quarterly distributions with respect to the period from
October 1, 2023 through December 31, 2023, including approximately $0.8 million aggregate cash distribution on our common units and $6,746 on
our general partner interest, including approximately $0.6 million of such cash distribution paid to Spartan and its affiliates.
60
Management Services Agreement
In connection with the Contribution Agreement, the Partnership entered into the Management Services Agreement with the general partner,
Contributor, Spartan Energy Partners GP LLC, Spartan GP, and Spartan Operating. Under the terms of the Management Services Agreement, the
general partner, Spartan Operating and Spartan GP will provide certain services reasonably necessary for the operation of the businesses of the
Partnership and its subsidiaries, Spartan, Spartan GP and Spartan Treating, including certain corporate and general and administrative services.
Pursuant to the Management Services Agreement, the general partner and Spartan GP will allocate any costs and expenses incurred on a
reasonable basis, and the parties will reimburse such other parties for costs and expenses allocated to them.
Director Independence
Please see “Item 10. Directors, Executive Officers, and Corporate Governance” of this Annual Report for a discussion of director
independence matters, which discussion is incorporated by reference into this Item 13.
Item 14. Principal Accounting Fees and Services.
Fees Paid to Principal Accounting Firm
The following table sets forth the aggregate fees for professional services rendered to us by Grant Thornton and its member firms and
respective affiliates during the fiscal years ended December 31, 2023 and 2022, respectively (in thousands):
Audit fees
Audit related fees
Tax fees
All other fees
Total fees
$
$
2023
2022
1,173 $
—
—
—
1,173 $
1,058
—
—
—
1,058
Audit Committee Pre-Approval of Audit and Non-Audit Services
The Audit Committee of our general partner has adopted a pre-approval policy with respect to services which may be performed by our
independent registered public accounting firm (the “Audit Firm”). This policy provides that all audit and non-audit services to be performed by the
Audit Firm must be specifically pre-approved on a case-by-case basis by the Audit Committee. The Audit Committee may delegate pre-approval
authority to one or more of its members. The member to whom such authority is delegated must report, for informational purposes only, any pre-
approval decisions to the entire Audit Committee at or before its next scheduled meeting. As of the date hereof, the Audit Committee has delegated
this authority to the Chairman of the Audit Committee. Neither the Audit Committee, nor the person to whom pre-approval authority is delegated,
may delegate their responsibilities to pre-approve services performed by the Audit Firm to our management.
PART IV
61
Item 15. Exhibits and Financial Statement Schedules.
(a) List of documents filed as part of this Report
1.
Financial Statements of the Partnership
Report of Independent Registered Public Accounting Firms (PCAOB ID Number 248); 700 Milam St, Ste. 300, Houston, TX
77002
Consolidated Balance Sheets at December 31, 2023 and 2022
Consolidated Statements of Operations for the years ended December 31, 2023 and 2022
Consolidated Statements of Comprehensive Income for the years ended December 31, 2023 and 2022
Consolidated Statements of Partners’ Capital for the years ended December 31, 2023 and 2022
Consolidated Statements of Cash Flows for the years ended December 31, 2023 and 2022
Notes to Consolidated Financial Statements
Page
F-1
F-4
F-5
F-6
F-7
F-8
F-9
Financial statement schedules have been omitted as they are not required, are not applicable, or the required information is included in the
financial statements or notes thereto.
List of Exhibits
Agreement and Plan of Merger, dated as of December 19, 2023, by and among CSI Compressco LP, CSI Compressco GP LLC, Kick Stock
Merger Sub, LLC, Kick GP Merger Sub, LLC, Kick LP Merger Sub, LLC and Kodiak Gas Services, Inc. (incorporated by reference to Exhibit 2.1 to
the Partnership’s Current Report on Form 8-K filed on December 19, 2023 (SEC File No. 001-35195)) *
Certificate of Limited Partnership of Compressco Partners, L.P., dated October 31, 2008 (incorporated by reference to Exhibit 3.1 to the
Partnership’s Registration Statement on Form S-1 filed on November 10, 2008 (SEC File No. 333-155260)).
Certificate of Correction of the Certificate of Limited Partnership of Compressco Partners, L.P. (incorporated by reference to Exhibit 3.5 to
Amendment No.1 to the Partnership’s Registration Statement on Form S-1/A filed on December 19, 2008 (SEC File No. 333-155260)).
Amendment to the Certificate of Limited Partnership of Compressco Partners, L.P., dated November 19, 2014 (incorporated by reference to
Exhibit 3.1 to the Current Report on Form 8-K filed on December 1, 2014 (SEC File No. 001-35195)).
Third Amended and Restated Agreement of Limited Partnership of CSI Compressco LP, dated as of January 6, 2022 (incorporated by reference
to Exhibit 3.1 to the Current Report on Form 8-K filed on January 11, 2022 (SEC File No. 001-35195)).
Certificate of Conversion of CSI Compressco GP LLC, dated January 27, 2021 (incorporated by reference to Exhibit 3.1 to the Current Report on
Form 8-K filed on January 29, 2021 (SEC File No. 001-35195)).
Certificate of Formation of CSI Compressco GP LLC, dated January 27, 2021 (incorporated by reference to Exhibit 3.2 to the Current Report on
Form 8-K filed on January 29, 2021 (SEC File No. 001-35195)).
Limited Liability Company Agreement of CSI Compressco GP LLC, dated as of January 27, 2021 (incorporated by reference to Exhibit 3.3 to the
Current Report on Form 8-K filed on January 29, 2021 (SEC File No. 001-35195)).
Specimen Unit Certificate representing Common Units (incorporated by reference to Exhibit 4.1 to Amendment No. 3 to the Partnership’s
Registration Statement on Form S-1/A filed on April 12, 2011 (SEC File No. 333-155260)).
Indenture, dated as of March 22, 2018, by and among CSI Compressco LP, CSI Compressco Finance Inc., the Guarantors party thereto and U.S.
Bank National Association, as Trustee (incorporated by reference to Exhibit 4.1 to the Partnership’s Form 8-K filed on March 27, 2018 (SEC File
No. 001-35195)).
Form of 7.500% Senior Secured First Lien Note due 2025 (incorporated by reference to Exhibit 4.1 to the Partnership’s Form 8-K filed on March
27, 2018 (SEC File No. 001-35195)).
First Supplemental Indenture, dated as of June 12, 2020, by and among CSI Compressco LP, CSI Compressco Finance, Inc., the Guarantors
named therein and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.1 to the Partnership’s Form 8-K filed on
June 12, 2020 (SEC File No. 001-35195)).
First Lien Supplemental Indenture, dated as of June 12, 2020, by and among CSI Compressco LP, CSI Compressco Finance, Inc., the
Guarantors named therein and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit 4.2 to the Partnership’s Form 8-K
filed on June 12, 2020 (SEC File No. 001-35195)).
2.
3.
2.1
3.1
3.2
3.3
3.4
3.5
3.6
3.7
4.1
4.2
4.3
4.4
4.5
62
4.6
4.7
4.8
4.9
4.10
10.1
10.2
10.3***
10.4***
10.5***
10.6***
10.7
10.8
10.9
10.10
10.11
10.12
10.13
10.000%/10.750% Senior Secured Second Lien Notes due 2026 Indenture, dated as of June 12, 2020, by and among CSI Compressco LP, CSI
Compressco Finance, Inc., the Guarantors named therein and U.S. Bank National Association, as trustee (incorporated by reference to Exhibit
4.3 to the Partnership’s Form 8-K filed on June 12, 2020 (SEC File No. 001-35195).
Form of 10.000%/10.750% Senior Secured Second Lien Note due 2026 (incorporated by reference to Exhibit 4.3 to the Partnership’s Form 8-K
filed on June 12, 2020 (SEC File No. 001-35195)).
Second Lien Supplemental Indenture, dated as of November 16, 2021, by and among CSI Compressco LP, CSI Compressco Finance, Inc., the
Guarantors named therein, U.S. Bank National Association, as trustee, and U.S. Bank National Association, as collateral trustee (incorporated by
reference to Exhibit 4.2 to the Partnership’s Current Report on Form 8-K filed November 16, 2021 (SEC File No. 001-35195)).
Registration Rights Agreement, dated November 10, 2021, by and among CSI Compressco LP and each of the holders party thereto
(incorporated by reference to Exhibit 4.1 to the Partnership’s Current Report on Form 8-K filed November 16, 2021 (SEC File No. 001-35195)).
Description of the Registrant’s Securities Registered Pursuant to Section 12 of the Securities Exchange Act of 1934
Contribution, Conveyance and Assumption Agreement, dated June 20, 2011, by and among Compressco, Inc., Compressco Field Services, Inc.,
Compressco Canada, Inc., Compressco de Mexico, S. de R.L. de C.V., Compressco Partners GP Inc., Compressco Partners, L.P., Compressco
Partners Operating, LLC, Compressco Netherlands B.V., Compressco Holdings, LLC, Compressco Netherlands Coöperatief U.A., Compressco
Partners Sub, Inc., TETRA International Incorporated, Production Enhancement Mexico, S. de R.L. de C.V. and TETRA Technologies, Inc.
(incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed on June 24, 2011 (SEC File No. 001-35195)).
Form of Indemnification Agreement (incorporated by reference to Exhibit 10.5 to Amendment No. 4 to the Partnership’s Registration Statement on
Form S-1/A filed on May 27, 2011 (SEC File No. 333-155260)).
Form of Cash Retention Award Agreement under the CSI Compressco LP Second Amended and Restated 2011 Long Term Incentive Plan
(incorporated by reference to Exhibit 10.1 to the Partnership’s Quarterly Report on Form 10-Q filed on November 2, 2020 (SEC File No. 001-
35195)).
CSI Compressco LP Third Amended and Restated 2011 Long Term Incentive Plan (incorporated by reference to Exhibit 10.1 to the Partnership’s
Form 8-K filed on February 28, 2023 (SEC File No. 001-35195)).
Form of Phantom Unit Agreement under the CSI Compressco LP Second Amended and Restated 2011 Long Term Incentive Plan (incorporated
by reference to Exhibit 10.3 to the Partnership’s Quarterly Report on Form 10-Q filed on May 9, 2019 (SEC File No. 001-35195)).
Form of Non-Employee Director Phantom Unit Agreement under the CSI Compressco LP Second Amended and Restated 2011 Long Term
Incentive Plan (incorporated by reference to Exhibit 10.4 to the Partnership’s Quarterly Report on Form 10-Q filed on May 9, 2019 (SEC File No.
001-35195)).
Loan and Security Agreement, dated as of June 29, 2018, by and among CSI Compressco LP, CSI Compressco Sub Inc., CSI Compressco
Operating LLC, as borrowers, certain subsidiaries the borrowers named as guarantors therein, the lenders from time to time party thereto, and
Bank of America, N.A., as administrative agent, collateral agent, letter of credit issuer and swing line issuer (incorporated by reference to Exhibit
10.1 to the Partnership’s Form 8-K filed on July 3, 2018 (SEC File No. 001-35195)).
First Amendment to Loan and Security Agreement, dated June 26, 2019, by and among CSI Compressco LP, CSI Compressco Sub Inc., and CSI
Compressco Operating LLC, as borrowers, and Bank of America, N.A., as administrative agent, collateral agent, letter of credit issuer and swing
line issuer (incorporated by reference to Exhibit 10.1 to the Partnership’s Quarterly Report on Form 10-Q filed on August 8, 2019 (SEC File No.
001-35195)).
Second Amendment to Loan and Security Agreement, dated June 11, 2020, by and among CSI Compressco LP, CSI Compressco Sub, Inc. and
Bank of America, N.A., in its capacity administrative agent, issuing bank and swing line issuer, and the other lenders and loan parties party
thereto (incorporated by reference to Exhibit 10.1 to the Partnership’s Form 8-K filed on June 12, 2020 (SEC File No. 001-35195)).
Third Amendment to Loan and Security Agreement, dated January 29, 2021, by and among CSI Compressco LP, CSI Compressco Sub, Inc. and
Bank of America, N.A., in its capacity administrative agent, issuing bank and swing line issuer, and the other lenders and loan parties party
thereto (incorporated by reference to Exhibit 10.1 to the Partnership’s Form 8-K filed on January 29, 2021 (SEC File No. 001-35195)).
Fourth Amendment to Loan and Security Agreement, dated November 10, 2021, by and among CSI Compressco LP, certain of its subsidiaries,
Bank of America, N.A., as administrative agent, issuing bank and swing line lender, and the lenders party thereto (incorporated by reference to
Exhibit 10.3 to the Partnership’s Form 8-K filed on November 16, 2021 (SEC File No. 001-35195)).
Fifth Amendment to Loan and Security Agreement, dated June 30, 2022, by and among CSI Compressco LP, certain of its subsidiaries, Bank of
America, N.A., as administrative agent, issuing bank and swing line lender, and the lenders party thereto (incorporated by reference to Exhibit
10.1 to the Partnership’s Form 8-K filed on July 1, 2022 (SEC File No. 001-35195)).
Loan, Security and Guaranty Agreement, dated January 29, 2021, by and among Spartan Energy Partners LP, Spartan Energy Services LLC,
Spartan Terminals Operating, Inc., Spartan Operating Company LLC, Treating Holdco LLC, Bank of America, N.A., as agent for the lenders, and
the lenders party thereto.
63
10.14
10.15
10.16
10.17
10.18
10.19+***
10.20
10.21
10.22
10.23
21+
22+
23.1+
31.1+
31.2+
32.1**
32.2**
97.1*
101.INS++
101.SCH++
101.CAL++
101.DEF++
101.LAB++
101.PRE++
104++
First Amendment to Loan, Security and Guaranty Agreement, dated November 10, 2021, by and among Spartan Energy Services LLC, Treating
Holdco LLC, Spartan Energy Partners LP, Spartan Terminals Operating, Inc., Spartan Operating Company LLC, Bank of America, N.A., as agent
for the lenders, and the lenders party thereto (incorporated by reference to Exhibit 10.4 to the Partnership’s Form 8-K filed on November 16, 2021
(SEC File No. 001-35195)).
Second Amendment to Loan, Security and Guaranty Agreement, dated October 19, 2022, by and among Spartan Energy Services LLC, Treating
Holdco LLC, Bank of America, N.A., as agent for the lenders, and the lenders party thereto (incorporated by reference to Exhibit 10.1 to the
Partnership’s Form 8-K filed on October 21, 2022 (SEC File No. 001-35195)).
Collateral Trust Agreement, dated as of March 22, 2018, by and among CSI Compressco LP, CSI Compressco Finance Inc., the other Grantors
from time to time party thereto, U.S. Bank National Association, as Trustee, the other Priority Lien Representatives from time to time party thereto,
and U.S. Bank National Association, as Collateral Trustee (incorporated by reference to Exhibit 10.1 to the Partnership’s Form 8-K filed on March
27, 2018 (SEC File No. 001-35195)).
Collateral Trust Agreement, dated June 12, 2020, by and among CSI Compressco LP, CSI Compressco Finance Inc., the other Grantors from
time to time party thereto, U.S. Bank National Association, as Trustee, the other Junior Lien Representatives from time to time party thereto, and
U.S. Bank National Association, as Collateral Trustee (incorporated by reference to Exhibit 10.2 to the Partnership’s Form 8-K filed on June 12,
2020 (SEC File No. 001-35195)).
Management Services Agreement, dated November 10, 2021, by and among CSI Compressco LP, CSI Compressco GP LLC, Spartan Energy
Partners LP, Spartan Energy Partners GP LLC and Spartan Operating Company LLC (incorporated by reference to Exhibit 10.1 to the
Partnership’s Form 8-K filed on November 16, 2021 (SEC File No. 001-35195)).
Form of Change in Control Severance Agreement entered into between the Partnership and each of John E. Jackson, Jonathan W. Byers and
Robert W. Price.
Support Agreement, dated as of December 19, 2023, by and among Kodiak Gas Services, Inc., CSI Compressco LP, CSI Compressco
Investments LLC, CSI Compressco GP LLC and Spartan Energy Partners LP (incorporated by reference to Exhibit 10.1 to the Partnership’s Form
8-K filed on December 19, 2023 (SEC File No. 001-35195)).
Support Agreement, dated as of December 19, 2023, by and among Kodiak Gas Services, Inc., CSI Compressco LP, CSI Compressco GP LLC
and Orvieto Fund L.P. (incorporated by reference to Exhibit 10.2 to the Partnership’s Form 8-K filed on December 19, 2023 (SEC File No. 001-
35195))
Support Agreement, dated as of December 19, 2023, by and among Kodiak Gas Services, Inc., CSI Compressco LP, CSI Compressco GP LLC
and Merced Capital L.P. (incorporated by reference to Exhibit 10.3 to the Partnership’s Form 8-K filed on December 19, 2023 (SEC File No. 001-
35195))
Support Agreement, dated as of December 19, 2023, by and among Kodiak Gas Services, Inc., CSI Compressco LP, CSI Compressco GP LLC,
John E. Jackson, Jonathan Byers and Robert Price. (incorporated by reference to Exhibit 10.4 to the Partnership’s Form 8-K filed on December
19, 2023 (SEC File No. 001-35195)).
Subsidiaries of the Partnership
List of Subsidiary Guarantors
Consent of Grant Thornton LLP
Certification of Principal Executive Officer Pursuant to Rule 13a-14(a) and 15d-14(a) of the Exchange Act, As Adopted Pursuant to Section 302 of
the Sarbanes-Oxley Act of 2002.
Certification of Principal Financial Officer Pursuant to Rule 13a-14(a) and 15d-14(a) of the Exchange Act, As Adopted Pursuant to Section 302 of
the Sarbanes-Oxley Act of 2002.
Certification of Principal Executive Officer Furnished Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-
Oxley Act of 2002.
Certification of Principal Financial Officer Furnished Pursuant to 18 U.S.C. Section 1350, As Adopted Pursuant to Section 906 of the Sarbanes-
Oxley Act of 2002.
CSI Compressco LP Clawback Policy (adopted July 27, 2023)
XBRL Instance Document
XBRL Taxonomy Extension Schema Document
XBRL Taxonomy Extension Calculation Linkbase Document
XBRL Taxonomy Extension Definition Linkbase Document
XBRL Taxonomy Extension Label Linkbase Document
XBRL Taxonomy Extension Presentation Linkbase Document
Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).
+ Filed with this report.
* Schedules to this Exhibit have been omitted pursuant to Item 601(a)(5) of Regulation S-K. A copy of any omitted schedule and/or exhibit will be furnished to the SEC upon request.
** Furnished with this report.
*** Management contract or compensatory plan or arrangement.
64
++ Attached as Exhibit 101 to this report are the following documents formatted in XBRL (Extensible Business Reporting Language): (i) Consolidated Statements of Operations for the
years ended December 31, 2023 and 2022; (ii) Consolidated Balance Sheets as of December 31, 2023 and 2022; (iii) Consolidated Statements of Partners’ Capital/Net Parent
Equity for the years ended December 31, 2023 and 2022; (iv) Consolidated Statements of Comprehensive Income for the years ended December 31, 2023 and 2022; (v)
Consolidated Statements of Cash Flows for the years ended December 31, 2023 and 2022; and (vi) Notes to Consolidated Financial Statements for the year ended December 31,
2023.
65
Item 16. Form 10-K Summary.
None.
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, CSI Compressco LP has duly caused this report
to be signed on its behalf by the undersigned, thereunto duly authorized.
SIGNATURES
Date:
March 1, 2024
CSI COMPRESSCO LP
By: CSI Compressco GP LLC,
its general partner
By: /s/John E. Jackson
John E. Jackson, Chief Executive Officer
(Principal Executive Officer)
Pursuant to the requirements of the Securities Exchange Act of 1934, as amended, this report has been signed below by the following persons
on behalf of the Registrant and in the capacities with CSI Compressco GP LLC, its general partner, and on the dates indicated:
Signature
/s/Ted A. Gardner
Ted A. Gardner
/s/John E. Jackson
John E. Jackson
/s/Jonathan W. Byers
Jonathan W. Byers
/s/Riplee L. Parkening
Riplee L. Parkening
/s/Denise G. Essenberg
Denise G. Essenberg
/s/Stephen R. Gill
Stephen R. Gill
/s/James R. Larson
James R. Larson
/s/Robert W. Price
Robert W. Price
/s/Michael J. Tucker
Michael J. Tucker
Title
Chairman of the Board of Directors
Chief Executive Officer and Director
(Principal Executive Officer)
Chief Financial Officer and Director
(Principal Financial Officer)
Controller
(Principal Accounting Officer)
Director
Director
Director
Director
Director
66
Date
March 1, 2024
March 1, 2024
March 1, 2024
March 1, 2024
March 1, 2024
March 1, 2024
March 1, 2024
March 1, 2024
March 1, 2024
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
Board of Directors of CSI Compressco GP LLC and the Unitholders of CSI Compressco LP
Opinion on the financial statements
We have audited the accompanying consolidated balance sheets of CSI Compressco LP (a Delaware limited partnership) and subsidiaries (the
“Partnership”) as of December 31, 2023 and 2022, the related consolidated statements of operations, comprehensive income (loss) partners’
capital, and cash flows for each of the two years in the period ended December 31, 2023, and the related notes (collectively referred to as the
“financial statements”). In our opinion, the financial statements present fairly, in all material respects, the financial position of the Partnership as of
December 31, 2023 and 2022, and the results of its operations and its cash flows for each of the two years in the period ended December 31, 2023,
in conformity with accounting principles generally accepted in the United States of America.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (“PCAOB”), the
Partnership’s internal control over financial reporting as of December 31, 2023, sed on criteria established in the 2013 Internal Control—Integrated
Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (“COSO”), and our report dated March 1, 2024
expressed an unqualified opinion.
Basis for opinion
These financial statements are the responsibility of the Partnership’s management. Our responsibility is to express an opinion on the Partnership’s
financial statements based on our audits. We are a public accounting firm registered with the PCAOB and are required to be independent with
respect to the Partnership’s in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and
Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain
reasonable assurance about whether the financial statements are free of material misstatement, whether due to error or fraud.
Our audits included performing procedures to assess the risks of material misstatement of the 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 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 financial statements. We believe that our audits provide a reasonable basis for
our opinion.
Critical audit matters
The critical audit matters are matters arising from the current period audit of the 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/ GRANT THORNTON LLP
We have served as the Partnership’s auditor since 2020.
Houston, Texas
March 1, 2024
F-1
CSI Compressco LP
Consolidated Balance Sheets
(In Thousands, Except Unit Amounts)
December 31, 2023
December 31, 2022
ASSETS
Current assets:
Cash and cash equivalents
Trade accounts receivable, net of allowance for credit losses of $460 in 2023 and $736 in 2022
Trade receivable - affiliate
Inventories
Prepaid expenses and other current assets
Total current assets
Property, plant, and equipment:
Land and building
Compressors and equipment
Vehicles
Construction in progress
Total property, plant, and equipment
Less accumulated depreciation
Net property, plant, and equipment
Other assets:
Deferred tax assets
Intangible assets, net of accumulated amortization of $39,586 in 2023 and $36,627 in 2022
Operating lease right-of-use assets
Other assets
Total other assets
Total assets
LIABILITIES AND PARTNERS’ CAPITAL
Current liabilities:
Accounts payable
Unearned income
Accrued liabilities and other
Current liabilities associated with discontinued operations
Total current liabilities
Other liabilities:
Long-term debt, net
Deferred tax liabilities
Operating lease liabilities
Other long-term liabilities
Total other liabilities
Commitments and contingencies
Partners’ capital:
General partner interest
Common units (141,995,028 units issued and outstanding at December 31, 2023 and 141,237,462
units issued and outstanding at December 31, 2022)
Accumulated other comprehensive loss
Total partners’ capital (deficit)
Total liabilities and partners’ capital
$
7,012 $
58,648
780
44,932
8,651
120,023
7,241
1,134,451
8,783
34,880
1,185,355
(666,075)
519,280
17
16,181
28,244
3,291
47,733
687,036 $
21,996 $
2,525
45,851
—
70,372
628,587
1,768
19,526
5,642
655,523
(1,690)
(22,855)
(14,314)
(38,859)
687,036 $
$
$
$
8,475
65,085
948
45,902
7,905
128,315
7,227
1,103,657
8,640
37,183
1,156,707
(611,734)
544,973
3
19,140
27,205
2,767
49,115
722,403
34,589
2,590
47,076
—
84,255
634,016
1,245
19,419
8,742
663,422
(1,618)
(9,250)
(14,406)
(25,274)
722,403
See Notes to Consolidated Financial Statements
F-2
CSI Compressco LP
Consolidated Statements of Operations
(In Thousands, Except Unit and Per Unit Amounts)
Revenues:
Contract services
Aftermarket services
Equipment rentals
Equipment sales
Total revenues
Cost of revenues (excluding depreciation and amortization expense):
Cost of contract services
Cost of aftermarket services
Cost of equipment rentals
Cost of equipment sales
Total cost of revenues
Depreciation and amortization
Impairments and other charges
Selling, general, and administrative expense
Interest expense, net of capitalized interest of $18 in 2023 and $318 in 2022
Other (income) expense, net
Loss before taxes and discontinued operations
Provision for income taxes
Loss from continuing operations
Income (loss) from discontinued operations, net of taxes
Net loss
General partner interest in net loss
Common units interest in net loss
Basic and diluted net loss per common unit:
Loss from continuing operations per common unit
Income (loss) from discontinued operations per common unit
Net loss per common unit
Weighted average common units outstanding:
Basic and diluted
$
$
$
$
$
$
Year Ended December 31,
2022
2023
284,049 $
83,621
17,209
1,249
386,128
140,663
66,355
2,094
1,344
210,456
77,409
—
47,552
53,899
2,519
(5,707)
3,773
(9,480)
—
(9,480) $
(44) $
(9,436) $
(0.07) $
—
(0.07) $
263,241
72,928
14,865
2,364
353,398
135,639
58,199
2,346
1,382
197,566
78,231
135
42,563
49,481
2,904
(17,482)
4,786
(22,268)
173
(22,095)
(104)
(21,991)
(0.16)
—
(0.16)
141,900,481
141,109,230
See Notes to Consolidated Financial Statements
F-3
CSI Compressco LP
Consolidated Statements of Comprehensive Income (Loss)
(In Thousands)
Net loss
Foreign currency translation adjustment
Comprehensive loss
Year Ended December 31,
2023
2022
$
$
(9,480) $
92
(9,388) $
(22,095)
(2)
(22,097)
See Notes to Consolidated Financial Statements
F-4
CSI Compressco LP
Consolidated Statement of Partners’ Capital
(In Thousands)
Partners’ Capital
Limited Partners
Common
Unitholders
Units
Amount
General
Partner
Amount
Accumulated Other
Comprehensive
Income (Loss)
Total Partners’
Capital (Deficit)
Balance as of December 31, 2021
Net loss for 2022
Distributions ($0.04 per unit)
Equity compensation, net
Vesting of Phantom Units
Translation adjustment, net of taxes of $0
Balance as of December 31, 2022
Net loss for 2023
Distributions ($0.04 per unit)
Equity compensation, net
Vesting of Phantom Units
Translation adjustment, net of taxes of $0
Balance as of December 31, 2023
$
$
$
(1,486)
(104)
(28)
—
—
—
(1,618)
(44)
(28)
—
—
—
(1,690)
140,386 $
—
—
—
851
—
141,237 $
—
—
—
758
—
141,995 $
17,049 $
(21,991)
(5,641)
1,333
—
—
(9,250) $
(9,436)
(5,674)
1,505
—
—
(22,855) $
(14,404) $
—
—
—
—
(2)
(14,406) $
—
—
—
—
92
(14,314) $
1,159
(22,095)
(5,669)
1,333
—
(2)
(25,274)
(9,480)
(5,702)
1,505
—
92
(38,859)
See Notes to Consolidated Financial Statements
F-5
CSI Compressco LP
Consolidated Statements of Cash Flows
(In Thousands)
Operating activities:
Net loss
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation and amortization
Impairments and other charges
Provision (benefit) for deferred income taxes
Equity-based compensation expense, net
Provision (recovery) for credit losses
Amortization of deferred financing costs
Other non-cash charges and credits
Gain (loss) on sale of property, plant, and equipment
Changes in operating assets and liabilities:
Accounts receivable
Inventories
Prepaid expenses and other current assets
Accounts payable and accrued expenses
Other
Net cash provided by operating activities
Investing activities:
Purchases of property, plant, and equipment, net
Proceeds from sale of property, plant, and equipment
Net cash used in investing activities
Financing activities:
Proceeds from long-term debt
Payments of long-term debt
Distributions
Debt issuance costs and other financing activities
Equipment financing lease, net
Net cash provided by (used in) financing activities
Effect of exchange rate changes on cash
Increase (decrease) in cash and cash equivalents and restricted cash
Cash and cash equivalents at beginning of period
Cash and cash equivalents at end of period
Supplemental cash flow information:
Interest paid
Income taxes paid
Decrease (increase) in accrued capital expenditures
Year Ended December 31,
2022
2023
$
(9,480) $
(22,095)
77,409
—
343
1,505
99
182
279
1,798
6,480
(6,027)
(1,055)
(9,028)
(335)
62,170
(57,871)
6,412
(51,459)
343,979
(349,409)
(5,701)
(104)
(1,037)
(12,272)
98
(1,463)
8,475
7,012 $
53,399 $
3,748 $
5,304 $
78,231
135
376
1,333
(407)
318
95
(961)
(12,292)
(17,563)
3,781
4,277
316
35,544
(52,073)
8,134
(43,939)
115,513
(113,360)
(5,669)
(343)
14,129
10,270
2
1,877
6,598
8,475
47,272
6,559
(4,225)
$
$
$
$
See Notes to Consolidated Financial Statements
F-6
CSI COMPRESSCO LP
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
December 31, 2023
NOTE 1 — ORGANIZATION AND OPERATIONS
CSI Compressco LP, a Delaware limited partnership, is a provider of compression and treating services. Natural gas compression is used for oil
production, gathering, artificial lift, transmission, processing, and storage. Treating services include the removal of contaminants from a natural gas
stream and cooling to reduce the temperature of produced gas and liquids. We also sell used standard compressor packages and provide
aftermarket services and compressor package parts and components manufactured by third-party suppliers. We provide contract and treating
services and compressor parts and component sales to a broad base of natural gas and oil exploration and production, midstream, and
transmission companies operating throughout many of the onshore producing regions of the United States as well as in a number of international
locations, including the countries of Mexico, Canada, Argentina and Chile. Unless the context requires otherwise, when we refer to “the
Partnership,” “we,” “us,” and “our,” we are describing CSI Compressco LP and its wholly owned subsidiaries.
Planned Mergers with Kodiak Gas Services, Inc.
On December 19, 2023, we entered into an Agreement and Plan of Merger (the “Merger Agreement”), by and among the Partnership,
Kodiak Gas Services, Inc., a Delaware corporation (“Kodiak”), Kodiak Gas Services, LLC, a Delaware limited liability company and indirect, wholly
owned subsidiary of Kodiak (“Kodiak Services”), Kick Stock Merger Sub, LLC, a Delaware limited liability company and indirect, wholly owned
subsidiary of Kodiak, Kick GP Merger Sub, LLC, a Delaware limited liability company and direct, wholly owned subsidiary of Kodiak Services, and
Kick LP Merger Sub, LLC, a Delaware limited liability company and direct, wholly owned subsidiary of Kodiak Services, pursuant to which Kodiak
will acquire the Partnership through a series of mergers (the “Mergers”). Under the terms of the Merger Agreement, (i) our common unitholders
(excluding certain holders described in clause (ii)) will receive 0.086 (the “Exchange Ratio”) shares of common stock, par value $0.01 per share, of
Kodiak (“Kodiak Common Stock”) in exchange for each common unit, (ii) our common unitholders that meet certain specified conditions may elect
to receive as consideration for each common unit, in lieu of a number of shares of Kodiak Common Stock equal to the Exchange Ratio, a number of
units (“OpCo Units”) in Kodiak Services, equal to the Exchange Ratio and an equal number of shares of Series A Preferred Stock of Kodiak (“Series
A Preferred Stock”), and (iii) the owner of our general partner will receive, in consideration for the notional units representing the general partner
interest in the Partnership, a number of OpCo Units and shares of Series A Preferred Stock equal to the Exchange Ratio for each such notional unit.
Each OpCo Unit will be redeemable for one share of Kodiak Common Stock (together with the cancellation of one share of Series A Preferred
Stock) pursuant to the terms of the Sixth Amended and Restated Limited Liability Company Agreement of Kodiak Services.
On February 21, 2024, upon the delivery of written consents approving the Mergers by each of our named executive officers and certain
large unitholders, we received the requisite unitholder approval to consummate the Mergers. Completion of the Mergers remains subject to certain
conditions, including certain governmental and regulatory approvals. The closing of the Mergers is currently expected to take place in the second
quarter of 2024; however, no assurance can be given as to when, or if, the Mergers will occur.
NOTE 2 — SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Basis of Presentation
Our consolidated financial statements include the accounts of our wholly owned subsidiaries. All intercompany balances and transactions
have been eliminated.
Segments
We operate in one reportable segment. The Partnership’s Chief Executive Officer, who is considered to be the chief operating decision
maker, manages the Partnership’s operations as a whole and reviews financial
F-7
information presented on a consolidated basis, accompanied by information about product revenue, for purposes of evaluating financial
performance and allocating resources.
Use of Estimates
The preparation of financial statements in conformity with U.S. generally accepted accounting principles (“GAAP”) requires us to make
estimates and assumptions that affect the reported amounts of assets and liabilities and disclose contingent assets and liabilities at the date of the
financial statements and the reported amounts of revenues, expenses, and impairments during the reporting period. Actual results could differ from
those estimates, and such differences could be material.
Reclassifications
Certain previously reported financial information has been reclassified to conform to the current year's presentation. The impact of such
reclassifications was not significant to the prior year's overall presentation.
Cash Equivalents
We consider all highly liquid cash investments with maturities of three months or less when purchased to be cash equivalents. We have
concentrated credit risk for cash by maintaining deposits in a major bank, which may at times exceed amounts covered by insurance provided by
the United States Federal Deposit Insurance Corporation (“FDIC”). We monitor the financial health of the bank and have not experienced any losses
in such accounts and believe we are not exposed to any significant credit risk. Management believes the financial institutions are financially sound
and risk of loss is minimal.
Financial Instruments
Financial instruments that subject us to concentrations of credit risk consist principally of trade accounts receivable, which are primarily due
from companies of varying size engaged in oil and gas activities in the United States, Canada, Mexico, Argentina and Chile. Our policy is to review
the financial condition of customers before extending credit and periodically updating customer credit information. Payment terms are on a short-
term basis. The risk of loss from the inability to collect trade receivables is heightened during prolonged periods of low oil and natural gas
commodity prices.
We have currency exchange rate risk exposure related to transactions denominated in a foreign currency as well as to investments in
certain of our international operations. Our risk management activities include the use of foreign currency forward purchase and sale derivative
contracts as part of a program designed to mitigate the currency exchange rate risk exposure on selected international operations.
We have $56.8 million balance outstanding under our variable rate revolving credit facilities pursuant to the Credit Agreement and the
Spartan Credit Agreement as of December 31, 2023 and face market risk exposure related to changes in applicable interest rates.
Significant Customers
During the years ended December 31, 2023 and 2022, one individual customer accounted for 10% or more of our revenues. As of
December 31, 2023 and 2022, one individual customer represented 10% or more of our consolidated trade accounts receivable net of allowance for
credit losses.
Foreign Currencies
We have designated the Canadian dollar as the functional currency for our operations in Canada. We are exposed to fluctuations between
the U.S. dollar and certain foreign currencies, including the Canadian dollar, the Mexican peso, the Argentine peso and the Chilean peso as a result
of our international operations. Foreign currency exchange (gains) losses are included in other (income) expense, net, and totaled $5.1 million and
$1.9 million during the years ended December 31, 2023 and 2022, respectively.
F-8
Leases
Lessee
As a lessee, unless the lease meets the criteria of short-term and is excluded per our policy election described below, we initially recognize a
lease liability and related right-of-use asset on the commencement date. The right-of-use asset represents our right to use an underlying asset and
the lease liability represents our obligation to make lease payments to the lessor over the lease term.
All of our long-term leases are operating leases and are included in operating lease right-of-use assets, accrued liabilities and other, and
operating lease liabilities in our consolidated balance sheet as of December 31, 2023 and 2022. We determine whether a contract is or contains a
lease at inception of the contract. Where we are a lessee in a contract that includes an option to extend or terminate the lease, we include the
extension period or exclude the period covered by the termination option in our lease term in determining the right-of-use asset and lease liability, if
it is reasonably certain that we would exercise the option.
As an accounting policy election, we do not include short-term leases on our balance sheet. Short-term leases include leases with a term of
twelve months or less, inclusive of renewal options we are reasonably certain to exercise. The lease payments for short-term leases are included as
operating lease costs on a straight-line basis over the lease term in cost of revenues or selling, general, and administrative expense based on the
use of the underlying asset. We recognize lease costs for variable lease payments not included in the determination of a lease liability in the period
in which an obligation is incurred.
As allowed by U.S. GAAP, we do not separate non-lease components from the associated lease component for our contract services contracts
and instead account for those components as a single component based on the accounting treatment of the predominant component. In our
evaluation of whether Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 842 “Leases” or ASC 606
“Revenue from Contracts with Customers” is applicable to the combined component based on the predominant component, we determined the
services non-lease component is predominant, resulting in the ongoing recognition of our compression services contracts following ASC 606.
Our operating leases are recognized at the present value of lease payments over the lease term. When the implicit discount rate is not readily
determinable, we use our incremental borrowing rate to calculate the discount rate used to determine the present value of lease payments.
Consistent with other long-lived assets or asset groups that are held and used, we test for impairment of our right-of-use assets when impairment
indicators are present.
Lessor
Our agreements for rental equipment contain an operating lease component under ASC 842 because we, as the lessor, retain substantial
exposure to changes in the underlying asset’s value, unlike a sale or secured lending arrangement. Therefore, we do not derecognize the
underlying asset, and recognize income associated with providing the lessee the right to control the use of the asset ratably over the lease term.
As a lessor, we recognize operating lease revenue on our statements of operations as equipment rentals. This revenue is recognized on a
straight-line basis over the term of the lease based on the monthly rate in the agreement. The leased asset remains on the balance sheets
consistent with other property, plant and equipment. Cash receipts associated with all leases are classified as cash flows from operating activities in
the statement of cash flows. Certain lease agreements provide renewal options. Either party can terminate prior to the next notice period. If neither
party terminates the lease automatically renews.
The leased equipment primarily consists of the Spartan Treating amine plants, gas coolers and production equipment. All of this equipment
is modular and skid mounted. It can be moved between locations. Lease terms for this equipment vary in length. Lease terms for amine plants
range from two to six years while lease terms for the gas coolers range from one month to two years.
F-9
Allowance for Credit Losses
Trade accounts receivable are stated at their net realizable value. The allowance for credit losses against gross trade accounts receivable
reflects the best estimate of expected credit losses of the receivables portfolio determined on the basis of historical experience, current information,
and forecasts of future economic conditions. In developing the estimate for expected credit losses, trade accounts receivables are segmented into
pools of assets depending on market (U.S. versus international), delinquency status, and customer type, and fixed reserve percentages are
established for each pool of trade accounts receivables.
In determining the reserve percentages for each pool of trade accounts receivables, we considered our historical experience with certain
customers and customer types, regulatory and legal environments, country and political risk, and other relevant current and future forecasted
macroeconomic factors. These credit risk indicators are monitored on a quarterly basis to determine whether there have been any changes in the
economic environment that would indicate the established reserve percentages should be adjusted, and are considered on a regional basis to
reflect more geographic-specific metrics. Additionally, write-offs and recoveries of customer receivables are tracked against collections on a
quarterly basis to determine whether the reserve percentages remain appropriate. When management becomes aware of certain customer-specific
factors that impact credit risk, specific allowances for these known troubled accounts are recorded. Trade accounts receivable are written off after all
reasonable means to collect the full amount (including litigation, where appropriate) have been exhausted.
Changes in the allowance are as follows:
At beginning of period
Activity in the period:
Provision (recovery) for credit losses
Account charge-offs, net
At end of period
Year Ended December 31,
2022
2023
(In Thousands)
736 $
99
(375)
460 $
1,223
(407)
(80)
736
$
$
Inventories
Inventories consist primarily of compressor package spare parts and supplies and work in progress. For compressor package spare parts
and supplies, cost is determined using the weighted average cost method. The cost of work in progress is determined using the specific
identification method.
Property, Plant, and Equipment
Property, plant, and equipment are stated at cost. Expenditures that increase the useful lives of assets are capitalized. The cost of repairs
and maintenance is charged to cost of revenues as incurred. Compressors include compressor packages currently placed in service and available
for service. Depreciation is computed using the straight-line method based on the following estimated useful lives:
Buildings
Compressors, Amine plants, and Production equipment
Other equipment
Vehicles
Information systems
15 – 30 years
12 – 25 years
2 – 8 years
3 – 5 years
7 years
Depreciation expense for the years ended December 31, 2023 and 2022 was $74.4 million and $75.1 million, respectively.
Leasehold improvements are depreciated over the shorter of the remaining term of the associated building lease or their useful lives.
F-10
Construction in progress as of December 31, 2023 and 2022 is primarily associated with the expansion of our contract services fleet and
capital expenditures that sustain the capacity of our existing fleet.
Intangible Assets
Trademarks/trade names, customer relationships, and other intangible assets are amortized on a straight-line basis over their estimated
useful lives, ranging from two to fifteen years. Amortization expense related to intangible assets was $2.9 million and $2.9 million for the years
ended December 31, 2023 and 2022, respectively, and is included in depreciation and amortization. The estimated future annual amortization
expense of trademarks/trade names, customer relationships, and other intangible assets is $2.9 million each year for 2024 to 2028.
Our intangible assets are tested for recoverability whenever events or changes in circumstances indicate that the carrying value of the asset may
not be recoverable. In such an event, we will determine the fair value of the asset using an undiscounted cash flow analysis of the asset at the
lowest level for which identifiable cash flows exist. If an impairment has occurred, we will recognize a loss for the difference between the carrying
value and the estimated fair value of the intangible asset.
Impairments and Other Charges
Impairments of long-lived assets, including identified intangible assets, are determined periodically when indicators of impairment are
present. If such indicators are present, the determination of the amount of impairment is based on our judgments as to the future undiscounted
operating cash flows to be generated from the relevant assets throughout their remaining estimated useful lives. If these undiscounted cash flows
are less than the carrying amount of the related asset, an impairment is recognized for the excess of the carrying value over its fair value. Fair value
of intangible assets is generally determined using the discounted present value of future cash flows using discount rates commensurate with the
risks inherent with the specific assets. Assets held for disposal are recorded at the lower of carrying value or estimated fair value less estimated
selling costs.
During 2023, we did not record any impairments of long-lived assets. During 2022 a specific engine in inventory was sold at a loss, resulting
in a charge of $0.1 million.
Accrued Liabilities
Accrued liabilities are detailed as follows:
Accrued interest
Operating lease liabilities, current portion
Compensation and employee benefits
Equipment finance agreements, current portion
Accrued taxes
Accrued capital expenditures
Other accrued liabilities
Total accrued liabilities and other
Revenue Recognition
December 31,
2023
2022
(In Thousands)
$
$
12,147 $
8,762
8,542
7,450
5,037
1,056
2,857
45,851 $
12,093
7,620
7,867
5,394
6,069
6,360
1,673
47,076
Performance Obligations. Revenue is recognized when performance obligations under the terms of a contract with our customer are
satisfied. Revenue is generally recognized when we transfer control of our products or services to our customers. Revenue is measured as the
amount of consideration we expect to receive in exchange for transferring products or providing services to our customers. We receive cash equal
to the invoice price for most product sales and services and payment terms typically range from 30 to 60 days from the date we invoice our
customer. With the exception of the initial terms of our compression services contracts of our medium-
F-11
and high-horsepower compressor packages, our customer contracts are generally for terms of one year or less. Since the period between when we
deliver products or services and when the customer pays for products or services is not to exceed one year, we have elected not to calculate or
disclose a financing component for our customer contracts.
Depending on the terms of the arrangement, we may also defer the recognition of revenue for a portion of the consideration received because we
have to satisfy a future performance obligation.
For revenue associated with mobilization of service equipment as part of a service contract arrangement, such revenue, if significant, is deferred
and amortized over the estimated service period.
Contract services. For compression services revenues recognized over time, our customer contracts typically provide agreed upon monthly
service rates and we recognize service revenue based upon the number of days that services have been performed. The majority of our
compression services are provided pursuant to contract terms ranging from one month to twenty-four months. Monthly agreements are generally
cancellable with 30 days written notice by the customer.
Sales taxes, value added taxes, and other taxes we collect concurrent with revenue-producing activities are excluded from revenue. We
recognize the cost for freight and shipping costs when control over our products (i.e., delivery) has transferred to the customer as part of cost of
product sales.
Use of Estimates. Our revenues do not include material amounts of variable consideration, as our revenues typically do not require significant
estimates or judgments. The transaction prices on a majority of our arrangements are fixed and product returns are immaterial. Additionally, our
arrangements typically do not include multiple performance obligations that require estimates of the stand-alone purchase price for each
performance obligation. Revenue on certain aftermarket service arrangements that include time as a component of the transaction price is not
recognized until the performance obligation is complete.
Contract Assets and Liabilities. We consider contract assets to be trade accounts receivable when we have an unconditional right to
consideration and only the passage of time is required before payment is due. In certain instances, particularly those requiring customer specific
documentation prior to invoicing, our invoicing of the customer is delayed until certain documentation requirements are met. In those cases, we
recognize a contract asset rather than a billed trade accounts receivable until we are able to invoice the customer. Contract assets, along with billed
trade accounts receivable, are included in trade accounts receivable in our consolidated balance sheets.
We classify contract liabilities as unearned income in our consolidated balance sheets.
Equity-Based Compensation
We have an equity incentive compensation plan which provides for the granting of phantom units and performance phantom units to the
executive officers, key employees, non-executive officers, and directors of our general partner. Total equity-based compensation expense for the
years ended December 31, 2023 and 2022, was $1.8 million and $1.6 million, respectively. For further discussion of equity-based compensation,
see Note 9 - “Equity-Based Compensation.”
Income Taxes
Our operations are not subject to U.S. federal income tax other than the operations that are conducted through taxable subsidiaries. We
incur state and local income taxes in certain areas of the U.S. in which we conduct business. We incur income taxes and are subject to withholding
requirements related to certain of our operations in Latin America, Canada, and other foreign countries in which we operate. Furthermore, we also
incur Texas Margin Tax, which, in accordance with Financial Accounting Standards Board (“FASB”) Accounting Standards Codification (“ASC”) 740,
is classified as an income tax for reporting purposes. A portion of the carrying value of certain deferred tax assets is subject to a valuation
allowance. See Note 11 - “Income Taxes” for further discussion.
Accumulated Other Comprehensive Income (Loss)
Certain of our international operations maintain their accounting records in the local currencies that are their functional currencies. For these
operations, the functional currency financial statements are converted to U.S. dollar
F-12
equivalents, with the effect of the foreign currency translation adjustment reflected as a component of accumulated other comprehensive income
(loss). Accumulated other comprehensive income (loss) is included in partners’ capital in the accompanying audited consolidated balance sheets
and consists of the cumulative currency translation adjustments associated with such international operations. Activity within our accumulated other
comprehensive income (loss) is not subject to reclassifications to net income.
Allocation of Net Income (Loss)
Our net income (loss) is allocated to partners’ capital accounts in accordance with the provisions of the Partnership Agreement.
Earnings Per Common Unit
Our computations of earnings per common unit are based on the weighted average number of common units outstanding during the
applicable period. Basic earnings per common unit are determined by dividing net income (loss) allocated to the common units after deducting the
amount allocated to our general partner by the weighted average number of outstanding common units during the period.
When computing earnings per common unit under the two-class method in periods when distributions are greater than earnings, the
amount of the distribution is deducted from net income (loss) and the excess of distributions over earnings is allocated between the general partner
and common units based on how our Partnership Agreement allocates net losses.
Diluted earnings per common unit are computed using the treasury stock method, which considers the potential future issuance of limited
partner common units. Unvested phantom units are not included in basic earnings per common unit, as they are not considered to be participating
securities, but are included in the calculation of diluted earnings per common unit. For the years ended December 31, 2023 and 2022, all unvested
phantom units were excluded from the calculation of diluted common units because the impact was anti-dilutive.
Fair Value Measurements
We utilize fair value measurements to account for certain items and account balances within our consolidated financial statements. We utilize fair
value measurements on a recurring basis in the accounting for our foreign currency forward purchase and sale derivative contracts. For these fair
value measurements, we utilize the quoted value (a Level 2 fair value measurement). Refer to Note 10 - “Fair Value Measurements” for further
discussion.
Fair value measurements are also utilized on a nonrecurring basis, such as in the allocation of purchase consideration for acquisition
transactions to the assets and liabilities acquired, including intangible assets (a Level 3 fair value measurement) and for the impairment of long-lived
assets (a Level 3 fair value measurement).
Distributions
On January 19, 2023, April 17, 2023, July 17, 2023 and October 19, 2023, our general partner declared a cash distribution attributable to the
respective quarter end of $0.01 per common unit. These distributions each equate to a distribution of $0.04 per outstanding common unit on an
annualized basis. These distributions were paid on February 14, 2023, May 15, 2023, August 14, 2023 and November 14, 2023, respectively, to the
holders of common units of record as of the close of business on January 31, 2023, April 30, 2023, July 28, 2023 and October 30, 2023,
respectively. See Note 15 – Subsequent Events for information regarding the distribution with respect to the quarter ended December 31, 2023.
F-13
Discontinued Operations
On July 2, 2020, we completed the sale of our Midland manufacturing facility. The Midland facility was used to design, fabricate and
assemble new standard and customized compressor packages for our new unit sales business. In connection with the Midland manufacturing
facility sale, we entered into an agreement with the buyer to continue to operate a portion of the facility, which allowed us to close out the remaining
backlog for the new unit sales business and to continue to operate our aftermarket services business at that location for an interim period. Following
completion of the last unit in October 2020, we ceased fabricating new compressor packages for sales to third parties or for our own service fleet.
The operations associated with the new unit sales business were previously reported in equipment sales revenues and are now reflected as
discontinued operations in our financial statements for all periods presented. Used equipment sales revenue continues to be included in equipment
sales revenue. Income from discontinued operations, net of tax for the year ended December 31, 2022, was $0.2 million related to the warranty
reserve not being utilized.
New Accounting Pronouncements
Standards adopted
In June 2016, the FASB issued ASU 2016-13, “Financial Instruments - Credit Losses (Topic 326): Measurement of Credit Losses on
Financial Instruments.” ASU 2016-13 amends the impairment model to utilize an expected loss methodology in place of the currently used incurred
loss methodology, which will result in the more timely recognition of losses on financial instruments not accounted for at fair value through net
income. The provisions require credit impairments to be measured over the contractual life of an asset and developed with consideration for past
events, current conditions, and forecasts of future economic information. Credit impairments will be accounted for as an allowance for credit losses
deducted from the amortized cost basis at each reporting date. Updates at each reporting date after initial adoption will be recorded through selling,
general, and administrative expense. We adopted this new standard on January 1, 2023 and our adoption of this standard did not have a material
impact on our consolidated financial statements.
Standards Not Yet Adopted
In November 2023, the Financial Accounting Standards Board (“FASB”) issued ASU 2023-07, Segment Reporting (Topic 280):
Improvements to Reportable Segment Disclosures.” ASU 2023-07 provides accounting guidance to improve the disclosures about a public entity’s
reportable segments and address requests from investors for additional, more detailed information about a reportable segment’s expenses. This
guidance is effective for fiscal years beginning after December 15, 2023, and interim periods after December 15, 2024. The Partnership will adopt
this guidance in its Form 10-K for the year ended December 31, 2024. This guidance is expected to impact the disclosures only with no impact to
the results of operations, financial position or cash flows.
In December 2023, the FASB issued ASU 2023-09, “Income Taxes (Topic 740): Improvements to Income Tax Disclosures.” ASU 2023-09
provides accounting guidance to enhance the transparency and decision usefulness of income tax disclosures. The guidance includes
improvements to income tax disclosures primarily related to the rate reconciliation and income taxes paid. This guidance is effective for annual
periods beginning after December 15, 2024, with early adoption permitted. The Partnership is in the process of evaluating this guidance and the
potential effects this guidance will have on its disclosures.
NOTE 3 — REVENUE FROM CONTRACTS WITH CUSTOMERS
As of December 31, 2023, we had $313.2 million of remaining contractual performance obligations for contract services. As a practical expedient,
this amount does not include revenue for contract services contracts whose original expected duration is less than twelve months and does not
consider the effects of the time value of money. Expected revenue to be recognized in the future as of December 31, 2023 for completion of
performance obligations of contract service are as follows:
Contract services contracts remaining performance
obligations
$
176,227
$
91,063 $
41,104 $
4,732 $
70 $
313,196
2024
2025
2026
2027
2028
Total
(In Thousands)
F-14
Our contract asset balances included in trade accounts receivable in our consolidated balance sheets, primarily associated with revenue accruals
prior to invoicing, were $2.9 million and $4.2 million as of December 31, 2023 and December 31, 2022, respectively.
The following table reflects the changes in unearned income in our consolidated balance sheets for the periods indicated:
December 31, 2023
December 31, 2022
Unearned income, beginning of period
Additional unearned income
Revenue recognized
Unearned income, end of period
$
$
$
(In Thousands)
2,590
11,584
(11,649)
2,525
$
2,187
10,725
(10,322)
2,590
Unearned income is included in accrued liabilities and other on the consolidated balance sheets. As of December 31, 2023 and 2022, contract
costs were immaterial.
Disaggregated revenue from contracts with customers by geography is as follows:
Contract services
U.S.
International
Aftermarket services
U.S.
International
Equipment Rentals
U.S.
International
Equipment sales
U.S.
International
Total Revenue
U.S.
International
Year Ended December 31,
2023
2022
(In Thousands)
$
260,397 $
23,652
284,049
80,773
2,848
83,621
13,267
3,942
17,209
676
573
1,249
355,113
31,015
$
386,128 $
F-15
227,542
35,699
263,241
71,445
1,483
72,928
9,380
5,485
14,865
1,945
419
2,364
310,312
43,086
353,398
NOTE 4 — INVENTORIES
Components of inventories as of December 31, 2023 and December 31, 2022 are as follows:
Parts and supplies
Work in progress
Total inventories
$
$
December 31, 2023
December 31, 2022
(In Thousands)
42,736 $
2,196
44,932 $
44,042
1,860
45,902
Inventories consist primarily of compressor package spare parts and supplies. Work in progress inventories consist of work in progress for our
aftermarket business that has not been invoiced.
NOTE 5 — LEASES
Lessee Accounting
We have operating leases for some of our office space, warehouse space, operating locations, and machinery and equipment. Our leases
have remaining lease terms up to ten years. Some of our leases have options to extend for various periods, while some have termination options
upon prior notice of typically 30 days or six months. Our leases generally require us to pay all maintenance and insurance costs. Our lease
agreements do not contain any material residual value guarantees or material restrictive covenants.
Lease costs are included in either cost of revenues or selling, general, and administrative expense depending on the use of the underlying
asset. Total lease expense (inclusive of lease expense for leases not included on our consolidated balance sheet based on our accounting policy
election to exclude leases with a term of twelve months or less), was $16.1 million for the year ended December 31, 2023, of which $2.3 million
related to short-term leases. Total lease expense was $14.0 million for the year ended December 31, 2022, of which $2.8 million related to short-
term leases. Variable rent expense was not material.
Operating lease supplemental cash flow information:
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows - operating leases
Right-of-use assets obtained in exchange for lease obligations:
Operating leases
Supplemental balance sheet information:
Operating leases:
Operating right-of-use asset
Accrued liabilities and other
Operating lease liabilities
Total operating lease liabilities
F-16
Year Ended December 31,
2023
2022
(In Thousands)
13,796 $
10,930
11,975 $
8,777
December 31, 2023
December 31, 2021
(In Thousands)
28,244 $
8,762 $
19,526
28,288 $
27,205
7,620
19,419
27,039
$
$
$
$
$
Additional operating lease information:
Weighted average remaining lease term:
Operating leases
Weighted average discount rate:
Operating leases
December 31, 2023
December 31, 2022
4.60 years
4.39 years
9.94 %
10.05 %
Future minimum lease payments by year and in the aggregate, under non-cancelable operating leases with terms in excess of one year
consist of the following at December 31, 2023:
2024
2025
2026
2027
2028
Thereafter
Total lease payments
Less imputed interest
Total lease liabilities
Lessor Accounting
Operating Leases
(In Thousands)
11,270
7,356
6,298
3,189
1,512
5,102
34,727
(6,439)
28,288
$
$
Our leased equipment primarily consists of amine plants, gas coolers and other production equipment. Certain of our agreements with our
customers for rental equipment contain an operating lease component under ASC 842 because (i) there are identified assets, (ii) the customer has
the right to obtain substantially all of the economic benefits from the use of the identified asset throughout the period of use and (iii) the customer
directs the use of the identified assets throughout the period of use. We have elected to apply the practical expedient provided to lessors to combine
the lease and non-lease component of a contract where the revenue recognition pattern is the same and where the lease component, when
accounted for separately, would be considered an operating lease. The practical expedient also allows a lessor to account for the combined lease
and non-lease components under ASC 606, Revenue from Contracts with Customers, when the non-lease component is the predominant element
of the combined component.
Our lease agreements generally have contract terms based on monthly rates. Lease revenue is recognized straight-line based on these
monthly rates. We do not provide an option for the lessee to purchase the rented assets at the end of the lease and the lessees do not provide
residual value guarantees on the rented assets.
We recognized operating lease revenue, which is included in “Equipment rentals” on the consolidated statements of operations as follows:
Equipment rentals
$
December 31, 2023
December 31, 2022
(In Thousands)
17,209
$
14,865
The following table presents the maturity of lease payments for operating lease agreements in effect as of December 31, 2023. This
presentation includes minimum fixed lease payments and does not include an estimate of variable lease consideration. These agreements have
remaining lease terms ranging from one month to five years. The following table presents the undiscounted cash flows expected to be received
related to these agreements:
Future minimum lease revenue
$
9,064 $
1,598 $
(In Thousands)
1,576 $
1,576 $
1,576 $
263
2024
2025
2026
2027
2028
Thereafter
F-17
NOTE 6 — LONG-TERM DEBT AND OTHER BORROWINGS
Long-term debt consists of the following:
(1)
(2)
Credit Agreement
Spartan Credit Agreement
7.5% First Lien Notes due 2025
10.000%/10.750% Second Lien Notes due 2026
Total long-term debt
(5)
Other borrowings
(3)
(4)
Total long-term debt and other borrowings
Scheduled Maturity
June 29, 2025
October 17, 2025
April 1, 2025
April 1, 2026
Various
$
$
December 31, 2023
December 31, 2022
(In Thousands)
9,419 $
46,501
400,086
172,581
628,587
13,092
641,679 $
6,312
54,912
400,293
172,499
634,016
14,129
648,145
(1) Net of unamortized deferred financing costs of $0.3 million as of December 31, 2023 and $0.4 million as of December 31, 2022.
(2) Net of unamortized deferred financing costs of $0.5 million as of December 31, 2023 and $0.6 million as of December 31, 2022.
(3) Net of unamortized deferred financing costs of $1.3 million and $2.3 million as of December 31, 2023 and 2022, respectively, unamortized discount of $0.1 million and $0.1 million as
of December 31, 2023 and 2022, respectively, and deferred restructuring gain of $1.4 million and $2.7 million as of December 31, 2023 and 2022, respectively.
(4) Net of unamortized deferred financing costs of $1.3 million and $1.9 million, unamortized discount of $0.5 million and $0.7 million, and deferred restructuring gain of $1.7 million and
$2.4 million as of December 31, 2023 and 2022, respectively.
(5) Includes $7.5 million of current liability classified as Accrued liabilities and other and $5.6 million classified as Other long-term liabilities as of December 31, 2023 and $5.4 million of
current liability classified as Accrued liabilities and other and $8.7 million classified as Other long-term liabilities as of December 31, 2022 on the accompanying consolidated
balance sheet.
Scheduled maturities for the next five years and thereafter are as follows:
2024
2025
2026
2027
2028
Thereafter
Total maturities
December 31, 2023
(In Thousands)
7,443
462,109
173,112
—
—
—
642,664
$
$
Our Credit Agreement, the Spartan Credit Agreement and the indentures governing the Notes contain certain affirmative and negative
covenants, including covenants that restrict the ability to pay dividends or other restricted payments. We are in compliance with all covenants of our
credit agreements and indentures as of December 31, 2023.
Refer to Note 7 - “Related Party Transactions,” for a discussion of our amounts payable to affiliates.
Credit Agreement
On June 30, 2022, the Partnership, CSI Compressco Sub Inc. and CSI Compressco Operating LLC (collectively with the Partnership and
CSI Compressco Sub Inc., the “Borrowers”), and certain subsidiaries of the Partnership named therein as guarantors (the “Guarantors”), entered
into that certain Fifth Amendment to Loan and Security Agreement (the “Fifth Amendment”) with the Lenders (as defined below) party thereto, and
Bank of America, N.A., in its capacity as administrative agent (in such capacity, “Administrative Agent”), collateral agent, letter of credit issuer and
swing line lender.
The Fifth Amendment amends and modifies that certain Loan and Security Agreement among the Borrowers, the Guarantors, the financial
institutions from time to time party thereto as lenders (the “Lenders”) and the Administrative Agent dated as of June 29, 2018 (as amended,
restated, amended and restated, supplemented or otherwise modified from time to time, the “Credit Agreement”). The Fifth Amendment provided for
changes and modifications to the Credit Agreement as set forth therein, which include, among other things, the reduction of the
F-18
reserve to $3.5 million and the extension of the Termination Date (as defined in the Credit Agreement) from June 29, 2023 to June 29, 2025.
As of December 31, 2023, and subject to compliance with the covenants, borrowing base, and other provisions of the agreements that may
limit borrowings under the Credit Agreement, we had availability of $17.7 million.
The maturity date of the Credit Agreement is June 29, 2025. As of December 31, 2023, we had $9.8 million outstanding balance and had
$1.3 million in letters of credit against our Credit Agreement.
Spartan Credit Agreement
On October 19, 2022, Spartan Energy Services LLC and Treating Holdco LLC entered into that certain Second Amendment to Loan,
Security and Guaranty Agreement (the “Second Amendment”) with the lenders party thereto and Bank of America, N.A., in its capacity as agent.
The Second Amendment amends and modifies that certain Loan, Security and Guaranty Agreement dated January 29, 2021 (as amended,
restated, amended and restated, supplemented or otherwise modified from time to time, the “Spartan Credit Agreement”) among Spartan Energy
Services, LLC, as borrower, Treating Holdco LLC, as guarantor, the financial institutions from time to time party thereto as lenders and Bank of
America, N.A., as agent. The Second Amendment provided for changes and modifications to the Spartan Credit Agreement as set forth therein,
which include, among other things, the extension of the Termination Date from January 29, 2024 to October 17, 2025.
As of December 31, 2023, and subject to compliance with the covenants, borrowing base, and other provisions of the agreements that may
limit borrowings under the Spartan Credit Agreement, we had availability of $22.8 million.
The maturity date of the Spartan Credit Agreement is October 17, 2025. As of December 31, 2023, we had $47.0 million outstanding and no
letters of credit against the Spartan Credit Agreement.
7.50% First Lien Notes due 2025
As of December 31, 2023, our 7.50% First Lien Notes due 2025 (the “First Lien Notes”) had $400.1 million outstanding net of unamortized
discounts, unamortized deferred financing costs and deferred restructuring gains. Interest on these notes is payable on April 1 and October 1 of
each year. The First Lien Notes are secured by a first-priority security interest in substantially all of the Partnership’s and its subsidiaries assets,
subject to certain permitted encumbrances and exceptions, and are guaranteed on a senior secured basis by each of the Partnership’s U.S.
restricted subsidiaries (other than Finance Corp, certain immaterial subsidiaries and certain other excluded U.S. subsidiaries).
10.000%/10.750% Second Lien Notes due 2026
As of December 31, 2023, our 10.000%/10.750% Second Lien Notes due 2026 (the “Second Lien Notes”) had $172.6 million outstanding,
net of unamortized discounts, unamortized deferred financing costs and deferred restructuring gains. Interest on the Second Lien Notes is payable
on April 1 and October 1 of each year. The Second Lien Notes are secured by a second-priority security interest in substantially all of the
Partnership’s and its subsidiaries assets, subject to certain permitted encumbrances and exceptions, and are guaranteed on a senior secured basis
by each of the Partnership’s U.S. restricted subsidiaries (other than Finance Corp and certain other excluded U.S. subsidiaries). In connection with
the payment of PIK Interest (as defined below), if any, in respect of the Second Lien Notes, the issuers will be entitled, to increase the outstanding
aggregate principal amount of the Second Lien Notes or issue additional notes (“PIK notes”) under the Second Lien Notes indenture on the same
terms and conditions as the already outstanding Second Lien Notes. Interest will accrue at (1) the annual rate of 7.250% payable in cash, plus (2) at
the election of the Issuers (made by delivering a notice to the Second Lien Trustee not less than five business days prior to the record date), the
annual rate of (i) 2.750% payable in cash (together with the annual rate set forth in clause (1), the “Cash Interest Rate”) or (ii) 3.500% payable by
increasing the principal amount of the outstanding Second Lien Notes or by issuing additional PIK notes, in each case rounding up to the nearest
$1.00 (such increased principal amount or additional PIK notes, the “PIK Interest”).
F-19
As of December 31, 2023, our principal amount outstanding included $7.2 million of PIK notes.
Finance Agreements
During 2022, CSI Compressco Leasing LLC and CSI Compressco Operating LLC (individually and collectively as Debtor), with CSI
Compressco LP (as Guarantor), entered into a Master Equipment Finance Agreement with a third party in the amount of $16.6 million to finance
certain compression equipment. The note is payable in monthly installments of $0.5 million for thirty-six months. The current portion of this amount
is classified in accrued liabilities and other and the long-term portion is classified in other long-term liabilities on the accompanying consolidated
balance sheet.
During the first quarter of 2023, CSI Compressco Leasing LLC and CSI Compressco Operating LLC (individually and collectively as
Debtor), with CSI Compressco LP (as Guarantor), entered into a Master Equipment Finance Agreements with a third party totaling $5.1 million to
finance certain compression equipment. The notes are payable in monthly installments totaling $0.2 million for thirty-six months. The current portion
of these amounts are classified in accrued liabilities and other and the long-term portion is classified in other long-term liabilities on the
accompanying consolidated balance sheet.
NOTE 7 — RELATED PARTY TRANSACTIONS
Transition Services Agreement
TETRA provided back-office support to the Partnership under a Transition Services Agreement for a period of time until the Partnership
completed a full separation from TETRA’s back-office support functions. The Transition Services Agreement with TETRA expired on January 31,
2022. For the year ended December 31, 2022 we were charged $0.2 million. There were no such charges in for the year ended December 31,
2023.
Spartan and General Partner Ownership
As of December 31, 2023, Spartan’s ownership interest in us was approximately 45.4%, with the common units held by the public
representing an approximate 55% interest in us. As of December 31, 2023, Spartan’s ownership was through various wholly owned subsidiaries
and consisted of approximately 44.9% of the limited partner interests plus the approximate 0.5% general partner interest. As a result of its
ownership of common units and its general partner interest in us, Spartan received distributions of $2.6 million during the year ended December 31,
2023.
Indemnification Agreement
We have entered into indemnification agreements with each of our current directors and officers with regard to their services as a director or
officer, in order to enhance the indemnification rights provided under Delaware law and our Partnership Agreement. The individual indemnification
agreements provide each such director or officer with the right to receive his or her costs of defense if he or she is made a party or witness to any
proceeding other than a proceeding brought by or in the right of us, provided that such director or officer has not acted in bad faith or engaged in
fraud with respect to the action that gave rise to his or her participation in the proceeding.
NOTE 8 — COMMITMENTS AND CONTINGENCIES
From time to time, we are involved in litigation relating to claims arising out of our operations in the normal course of business. While the
outcome of any lawsuits or other proceedings against us cannot be predicted with certainty, management does not consider it reasonably possible
that a loss resulting from such lawsuits or proceedings in excess of any amounts accrued has been incurred that is expected to have a material
adverse effect on our financial condition, results of operations, or cash flows.
F-20
NOTE 9 — EQUITY-BASED COMPENSATION
2011 Long Term Incentive Plan
We have granted phantom unit and performance phantom unit awards to certain employees, officers, and directors of our general partner
pursuant to the CSI Compressco LP Third Amended and Restated 2011 Long Term Incentive Plan. Awards of phantom units generally vest over a
three-year period. Awards of performance phantom units cliff vest at the end of a performance period and are settled based on achievement of
related performance measures over the performance period. Each of the phantom unit and performance phantom unit awards includes distribution
equivalent rights that enable the recipient to receive additional units equal in value to the accumulated cash distributions made on the units subject
to the award from the date of grant. Accumulated distributions associated with each underlying unit are payable upon settlement of the related
phantom unit award (and are forfeited if the related award is forfeited). Phantom units are notional units that entitle the grantee to receive a common
unit upon the vesting of the award.
During the year ended December 31, 2023, we granted to certain officers and employees an aggregate of 978,917 phantom unit and
performance phantom unit awards, having an average market value (equal to the closing price of the common units on the dates of grant) of $1.36
per unit, or an aggregate market value of $1.3 million. During the year ended December 31, 2022, we granted to certain officers and employees
676,335 phantom unit and performance phantom unit awards, having an average market value (equal to the closing price of the common units on
the dates of grant) of $1.39 per unit, or an aggregate market value of $0.9 million. The fair value of awards vesting during 2023 and 2022 was
approximately $1.6 million and $2.0 million, respectively. The fair value of awards is amortized straight-line over the vesting period. Adjustments to
the amortized expense related to performance phantom units may be recognized prior to vesting depending on the expected achievement of the
performance target.
The following is a summary of unit activity for the year ended December 31, 2023:
Nonvested units outstanding at December 31, 2022
Units granted
Cancelled/forfeited
Exercised/released
Nonvested units outstanding at December 31, 2023
Units
(In Thousands)
Weighted Average
Grant Date Fair
Value Per Unit
1,813 $
979
(104)
(924)
1,764 $
1.78
1.36
1.91
1.78
1.54
Total estimated unrecognized equity-based compensation expense from unvested units as of December 31, 2023, was approximately $1.1
million and is expected to be recognized over a weighted average period of approximately 1.6 years. The amount recognized in 2023 and 2022 was
approximately $1.8 million and $1.6 million, respectively, and is included in selling, general, and administrative expense in our consolidated
statements of operations.
NOTE 10 — FAIR VALUE MEASUREMENTS
Fair value is defined by ASC Topic 820 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” within an entity’s principal market, if any. The principal market is the market in
which the reporting entity would sell the asset or transfer the liability with the greatest volume and level of activity, regardless of whether it is the
market in which the entity will ultimately transact for a particular asset or liability or if a different market is potentially more advantageous.
Accordingly, this exit price concept may result in a fair value that may differ from the transaction price or market price of the asset or liability.
F-21
Under U.S. GAAP, the fair value hierarchy prioritizes inputs to valuation techniques used to measure fair value. Fair value measurements
should maximize the use of observable inputs and minimize the use of unobservable inputs, where possible. Observable inputs are developed
based on market data obtained from sources independent of the reporting entity. Unobservable inputs may be needed to measure fair value in
situations where there is little or no market activity for the asset or liability at the measurement date and are developed based on the best
information available in the circumstances, which could include the reporting entity’s own judgments about the assumptions market participants
would utilize in pricing the asset or liability.
Financial Instruments
Derivative Contracts
We have currency exchange rate risk exposure related to transactions denominated in a foreign currency as well as to investments in
certain of our international operations. We enter into 30-day foreign currency forward derivative contracts as part of a program designed to mitigate
the currency exchange rate risk exposure on selected transactions of certain foreign subsidiaries. As of December 31, 2023 and 2022, we had the
following foreign currency derivative contracts outstanding relating to a portion of our foreign operations:
Forward sale Mexican peso
$
2,296 $
17.42
1/16/2024
US Dollar Notional Amount
(In Thousands)
December 31, 2023
Traded Exchange Rate
Settlement Date
Forward sale Mexican peso
$
2,071 $
19.31
1/3/2023
US Dollar Notional Amount
(In Thousands)
December 31, 2022
Traded Exchange Rate
Settlement Date
Under a program designed to mitigate the currency exchange rate risk exposure on selected transactions of certain foreign subsidiaries, we
may enter into similar derivative contracts from time to time. Although contracts pursuant to this program will serve as economic hedges of the cash
flow of our currency exchange risk exposure, they will not be formally designated as hedge contracts or qualify for hedge accounting treatment.
Accordingly, any change in the fair value of these derivative instruments during a period will be included in the determination of earnings for that
period.
The fair values of our foreign currency derivative contracts are based on quoted market values (a Level 2 fair value measurement). None of our
foreign currency derivative instruments contains credit risk related contingent features that would require us to post assets or collateral for contracts
that are classified as liabilities. During the years ended December 31, 2023 and 2022, we recognized approximately $0.5 million and $1.6 million of
net losses, respectively, associated with our foreign currency derivatives programs. These amounts are included in other (income) expense, net, in
the accompanying consolidated statement of operations.
Fair Value of Debt
The fair value of our debt has been estimated in accordance with the accounting standard regarding fair value. The fair value of our fixed
rate long-term debt is estimated based on recent trades for these notes. The carrying and fair value of our debt, excluding unamortized debt
issuance costs, are as follows (in thousands):
F-22
7.50% First Lien Notes
10.000%/10.750% Second Lien Notes
Other
December 31, 2023
December 31, 2022
Carrying Value
Fair Value
Carrying Value
Fair Value
$
$
400,000 $
172,717
572,717 $
(In Thousands)
399,000 $
178,330
577,330 $
400,000 $
172,717
572,717 $
373,0
136,4
509,4
The fair values of cash, accounts receivable, accounts payable, accrued liabilities, and variable-rate long-term debt pursuant to our Credit
Agreement and the Spartan Credit Agreement approximate their carrying amounts due to the short-term nature of these items.
NOTE 11 — INCOME TAXES
As a partnership, we are generally not subject to income taxes at the entity level, and our partners are separately taxed on their share of our
taxable income. However, a portion of our business is conducted through taxable U.S. corporate subsidiaries. Accordingly, a U.S. federal and state
income tax provision has been reflected in the accompanying statements of operations. State tax expense relating to the Texas franchise tax liability
is included in the provision for income taxes. Certain of our operations are located outside of the United States, and the Partnership, through its
foreign subsidiaries, is responsible for income taxes in these countries.
The income tax provision (benefit) attributable to our operations for the years ended December 31, 2023 and 2022, consists of the
following:
Current
Federal
State
Foreign
Deferred
Federal
State
Foreign
Total tax provision
Year Ended December 31,
2022
2023
(In Thousands)
— $
630
2,800
3,430
—
1,176
(833)
343
3,773 $
—
827
3,583
4,410
(5)
2
379
376
4,786
$
$
A reconciliation of the provision for income taxes computed by applying the federal statutory rate to income (loss) before income taxes and
the reported income taxes is as follows:
Income (loss) tax provision computed at statutory federal income tax rates
Partnership (earnings) losses
Corporate subsidiary earnings (loss) subject to federal tax
Valuation allowances
Income tax expense attributable to foreign earnings
State income taxes (net of federal benefit)
Other
Total tax provision
F-23
Year Ended December 31,
2022
2023
(In Thousands)
(1,199) $
1,199
(1,470)
4,094
(621)
1,515
255
3,773 $
(3,671)
3,671
(1,141)
896
3,277
1,681
73
4,786
$
$
Income (loss) before income tax provision includes the following components:
United States
International
Total
Year Ended December 31,
2022
2023
$
$
(In Thousands)
(2,922) $
(2,785)
(5,707) $
(26,788)
9,306
(17,482)
We file U.S. federal, state, and foreign income tax returns on behalf of all of our consolidated subsidiaries. With few exceptions, we are not subject
to U.S. federal, state, local, or non-U.S. income tax examinations by tax authorities for years prior to 2016. We file tax returns in the U.S. and in
various state, local and non-U.S. jurisdictions. The following table summarizes the earliest tax years that remain subject to examination by taxing
authorities in any major jurisdiction in which we operate:
Jurisdiction
United States – Federal
United States – State and Local
Non-U.S. jurisdictions
Earliest Open Tax Period
2017
2017
2016
We use the liability method for reporting income taxes, under which current and deferred tax assets and liabilities are recorded in
accordance with enacted tax laws and rates. Under this method, at the end of each period, the amounts of deferred tax assets and liabilities are
determined using the tax rate expected to be in effect when the taxes are actually paid or recovered. We establish a valuation allowance to reduce
the deferred tax assets when it is more likely than not that some portion or all of the deferred tax assets will not be realized. While we consider
taxable income in prior carryback years, future reversals of existing taxable temporary differences, future taxable income, and tax planning
strategies in assessing the need for the valuation allowance, there can be no guarantee that we will be able to realize all of our deferred tax assets.
Significant components of our deferred tax assets and liabilities are as follows:
Deferred Tax Assets
Other - Reserves
Amortization for book in excess of tax expense
Accruals
Net operating losses
Accruals - Right of use liability
Other - Plant, property, and equipment
Other
Total deferred tax assets
Valuation allowance
Net deferred tax assets
December 31, 2023
December 31, 2022
(In Thousands)
13 $
13,482
1,016
36,323
3,948
1,283
4,273
60,338
(34,074)
26,264 $
54
15,802
1,197
29,867
3,264
1,251
3,515
54,950
(30,273)
24,677
$
$
F-24
Deferred Tax Liabilities
Accruals
Depreciation for tax in excess of book expense
Right-of-use Asset
Other - Intangibles
Other - Reserves
Other
Total deferred tax liability
Net deferred tax liability
December 31, 2023
December 31, 2022
$
$
(In Thousands)
504 $
23,016
3,855
78
194
368
28,015
1,751 $
1,476
20,604
3,213
87
217
329
25,926
1,249
At December 31, 2023, we have federal, state, and foreign net operating loss carryforwards/carrybacks equal to approximately $28.4
million, $2.9 million, and $5.0 million, respectively. In those foreign jurisdictions and states in which net operating losses are subject to an expiration
period, our loss carryforwards, if not utilized, will expire from 2023 to 2042. Utilization of the net operating loss and credit carryforwards may be
subject to a significant annual limitation due to ownership changes that have occurred previously or could occur in the future provided by Section
382 of the Internal Revenue Code of 1986, as amended.
The valuation allowance increased $3.8 million and $2.5 million during the year ended December 31, 2023 and December 31, 2022, respectively,
primarily due to the increase in deferred tax assets as a result of losses generated by our U.S. corporate subsidiaries.
ASC 740, “Income Taxes” provides guidance on measurement and recognition in accounting for income tax uncertainties and provides related
guidance on derecognition, classification, disclosure, interest, and penalties. As of December 31, 2023 and 2022, the Partnership had no material
unrecognized tax benefits (as defined in ASC 740-10). We do not expect to incur interest charges or penalties related to our tax positions, but if
such charges or penalties are incurred, our policy is to account for interest charges as interest expense and penalties as tax expense in the
consolidated statements of operations.
NOTE 12 — EARNINGS PER COMMON UNIT
The computations of earnings per common unit are based on the weighted average number of common units outstanding during the
applicable full-year period. Basic earnings per common unit is determined by dividing net income (loss) allocated to the common units after
deducting the amount allocated to our general partner by the weighted average number of outstanding common units during the period.
When computing earnings per common unit under the two-class method in periods when distributions are greater than earnings, the
amount of the distributions is deducted from net income (loss) and the excess of distributions over earnings is allocated between the general partner
and common units based on how our partnership agreement allocates net losses.
When earnings are greater than distributions, we determine cash distributions based on available cash. The amount of net income is
allocated between the general partner and common units based on how our partnership agreement allocates net earnings.
The following is the number of the weighted average basic and diluted common units outstanding:
Weighted average basic and diluted common units outstanding
Year Ended December 31,
2023
141,900,481
2022
141,109,230
Diluted earnings per unit are computed using the treasury stock method which considers the potential future issuance of limited partner common
units. Unvested phantom units are not included in basic earnings per common unit, as they are not considered to be participating securities, but are
included in the calculation of diluted earnings per common unit. As of December 31, 2023 and 2022 there were no units excluded from the dilution
calculation.
F-25
NOTE 13 — SEGMENTS
ASC 280, “Segment Reporting”, defines the characteristics of an operating segment as (i) being engaged in business activity from which it may
earn revenues and incur expenses, (ii) being reviewed by the company’s chief operating decision maker (“CODM”) to make decisions about
resources to be allocated and to assess its performance, and (iii) having discrete financial information. The Partnership (excluding Spartan Treating)
and Spartan Treating operating segments are both individually material, however, because they have similar economic characteristics and are
similar in the nature of products and services, the type or class of customers, methods used to distribute their products or provides services, and
production process and regulatory environment, management has determined that they should be aggregated. Based on this, our general partner
has concluded that we operate in one reportable segment.
NOTE 14 — GEOGRAPHIC INFORMATION
Our headquarters are in the United States of America and we also have operations in Latin America, Canada, and to a lesser extent, in
other countries located in Europe and the Asia-Pacific region. As of June 30, 2023, we no longer have operations in Egypt. We attribute revenue to
the countries based on the location of customers. Long-lived assets consist primarily of compressor packages and are attributed to the countries
based on the physical location of the compressor packages at a given year-end. Information by geographic area is as follows:
Revenues from external customers:
U.S.
Latin America
Canada
Egypt
Other
Total
Identifiable assets:
U.S.
Latin America
Egypt
Canada
Total identifiable assets
Year Ended December 31,
2022
2023
(In Thousands)
355,113 $
23,022
5,118
2,400
475
310,312
32,040
4,755
4,045
2,246
386,128 $
353,398
629,567 $
51,901
—
5,568
687,036 $
654,515
57,683
6,341
3,864
722,403
$
$
$
$
NOTE 15 — SUBSEQUENT EVENTS
The Partnership has evaluated subsequent events through the filing of this Annual Report on Form 10-K and determined that there have
been no events that have occurred that would require adjustments to our disclosures in the consolidated financial statements except for the
transactions described below.
On January 18, 2024, the board of directors of our general partner declared a cash distribution attributable to the quarter ended
December 31, 2023, of $0.01 per common unit. This distribution equates to a distribution of $0.04 per outstanding common unit on an annualized
basis. This distribution was paid on February 14, 2024, to the holders of common units of record as of the close of business January 31, 2024.
F-26
CHANGE IN CONTROL SEVERANCE AGREEMENT
This Change in Control Severance Agreement (“Agreement”) is made and entered into by and between CSI Compressco LP, a
Delaware limited partnership (the “Company”), and [ ● ] (“Executive”), effective as of December [ ● ], 2023 (the “Effective Date”).
Executive and the Company are each referred to herein as a “Party” and together as the “Parties.”
W I T N E S S E T H:
WHEREAS, the Company acknowledges that Executive possesses skills and knowledge that are valuable to the Company and
the Company wishes to enter this Agreement in order to better ensure itself of access to the continued services of Executive, to provide
further incentive for Executive to build and preserve the goodwill of the Company, and in order to protect its legitimate business
interests, including the preservation of its goodwill and Confidential Information (as defined below); and
WHEREAS, Executive wishes to continue in employment with the Company, advance the business interests of the Company,
and be eligible for the benefits set forth herein.
NOW, THEREFORE, for and in consideration of the mutual promises, covenants and obligations contained herein, the
Company and Executive agree as follows:
1.
Definitions.
In addition to the terms defined in the body of this Agreement, for purposes of this Agreement, the following capitalized words
shall have the meanings indicated below:
(a)
“Accrued Obligations” means (i) accrued but unpaid base salary through the Date of Termination, which shall be
paid within the time required by applicable law, but no later than 30 days following the Date of Termination; (ii) accrued but unpaid
annual bonus amount for any year prior to the year in which the Date of Termination occurs; (iii) reimbursement for all incurred but
unreimbursed expenses for which an Executive is entitled to reimbursement in accordance with the expense reimbursement policies of
the Company in effect as of the Date of Termination; and (iv) benefits to which an Executive may be entitled pursuant to the terms of
any plan or policy sponsored by a member of the Company Group as in effect from time to time.
(b)
“Affiliate” means a corporation or other entity controlled by, controlling, or under common control with the
Company. The term “control” (including, with correlative meaning, the terms “controlled by” and “under common control with”), as
applied to any Person (as defined in Sections 13(d) and 14(d) of the Securities Exchange Act of 1934, as amended from time to time),
means the possession, directly or indirectly, of the power to direct or cause the direction of management and policies of such Person,
whether through the ownership of voting or other securities, by contract or otherwise.
(c)
“Board” means the Board of Directors of the General Partner.
with respect to natural gas compression, treating and cooling.
(d)
“Business” means the business of equipment rental, contract services, and after-market services, in each case
(e)
“Business Opportunity” shall mean any commercial, investment or other business opportunity relating to the
Business.
1
(f)
“Cause” shall mean the following (as determined by the Company in its reasonable discretion): (i) willful neglect
in the performance of Executive’s duties to the Company or an Affiliate or willful or repeated failure or refusal to perform such duties;
(ii) engagement in conduct in connection with Executive’s employment or services for the Company, which results, or could reasonably
be expected to result in, material harm to the business or reputation of the Company or an Affiliate; (iii) conviction, or plea of guilty or
no contest to, any felony or any other crime that results, ; (iv) material violation of the policies of the Company, including but not
limited to those relating to sexual harassment or the disclosure or misuse of confidential information, or those set forth in the manuals
or statements of policy of the Company; (v) fraud or misappropriation, embezzlement, or misuse of funds or property belonging to the
Company or an Affiliate; (vi) act of personal dishonesty that involves personal profit ; or (vii) any breach of any non-competition, non-
solicitation, no- hire, or confidentiality covenant between Executive and the Company or an Affiliate.
Restated 2011 Long Term Incentive Plan, as amended.
(g)
“Change of Control” shall have the meaning given such term in the CSI Compressco LP Second Amended and
(h)
(i)
thereunder.
“COBRA” means the Consolidated Omnibus Budget Reconciliation Act of 1985, as amended.
“Code” means the Internal Revenue Code of 1986, as amended, and applicable administrative guidance issued
(j)
“Company Group” means the Company and its Affiliates.
(k)
“Date of Termination” means the effective date of the termination of Executive’s employment with the Company
Group, as applicable, such that Executive is no longer employed by any member of the Company Group in accordance with Section 2;
provided, however, that in all events, a “Date of Termination” shall only occur upon the Executive’s “separation from service” as
defined within Section 409A (as defined below).
(l)
“General Partner” means CSI Compressco GP LLC.
(m)
“Good Reason” means with respect to Executive’s termination of employment from the Company Group, the
occurrence of any of the following events without the written consent of Executive: (i) a material diminution in Executive’s base salary,
target bonus or long-term incentive compensation opportunities, (ii) a material diminution in Executive’s authority, duties,
responsibilities or reporting relationship with the Company or any applicable member of the Company Group, (iii) Executive’s being
required to be based at any other office or location of employment more than 50 miles from Executive’s primary office or location of
employment immediately prior to the Change of Control, (iv) a failure of the Company to require a successor to expressly assume and
perform this Plan, or (v) a material diminution in the aggregate benefits offered under the Company Group’s benefit programs,
including but not limited to employer health, vision, or dental employee paid premiums, or 401(k) plan, other than as a result of, or
response to, changes in applicable law.
Executive cannot terminate their employment for Good Reason unless they have provided written notice to the Company of the
existence of the circumstances providing grounds for termination for Good Reason within 30 days of the initial existence of such
grounds and the Company has had at least 30 days from the date on which such notice is provided to cure such circumstances, if
curable. If Executive does not terminate their employment for Good Reason within 90 days after the first occurrence of the applicable
grounds, then the Participant will be deemed to have waived their right to terminate for Good Reason with respect to such grounds.
2
(n)
(o)
“Market Area” shall mean the State of Texas and the State of New Mexico.
“Prohibited Period” means the period during which Executive is employed by any member of the Company
Group and continuing for a period of twenty-four (24) months following the Date of Termination.
“Protected Customer or Supplier” means any customer or supplier of the Company for whom or which
Executive had direct or indirect responsibilities or about whom or which Executive obtained Confidential Information, in each case
within the twelve months prior to the Date of Termination.
(p)
(q)
“Release Conditions” means Executive’s (or, following Executive’s death, Executive’s estate’s) execution and
delivery to the Company on or prior to the Release Expiration Date of a release of claims agreement in a form acceptable to the
Company (the “Release”), which Release shall be in a form substantially similar to that contained at Exhibit A (as may be revised to
reflect any changes in applicable law, the circumstances of Executive’s separation, and the timing of payments), and which Release
shall be provided by the Company to Executive within seven (7) days of the Date of Termination), and, where applicable, Executive’s
(or Executive’s estate’s) non-revocation of such Release in the time set forth within the Release to do so.
(r)
“Release Expiration Date” is that date that is twenty-one (21) days following the date upon which the Company
delivers the Release to Executive or, in the event that such termination of employment is “in connection with an exit incentive or other
employment termination program” (as such phrase is defined in the Age Discrimination in Employment Act of 1967) and Executive is
age forty (40) or over on the Date of Termination, the date that is forty- five (45) days following such delivery date.
2.
Severance Benefits.
(a)
Termination Without Cause or Termination For Good Reason Following a Change of Control. If Executive’s
employment is terminated (such that, as a result of such termination, Executive is no longer employed by any member of the Company
Group), and such termination is (x) by the Company (or, if applicable, another member of the Company Group) without Cause or (y) by
Executive for Good Reason, in each case, on or within twelve (12) months following a Change of Control, then Executive shall be
entitled to receive the Accrued Obligations, and so long as (and only if) Executive satisfies the Release Conditions and abides by the
terms of Section 4, then the Company shall provide Executive with the following:
(i)
1
A severance payment in an amount equal to [2.5/ 2] times the sum of (1) Executive’s annualized base
salary immediately prior to the Date of Termination plus (2) the target value of Executive’s annual cash bonus opportunity, if
any, for the calendar year during which the Date of Termination occurs (such payment, the “CIC Severance Payment”), payable
as described in Section 2(b);
(ii)
A pro-rated portion of Executive’s target annual bonus for the calendar year that includes Executive’s
Date of Termination, multiplied by a fraction, (A) the numerator of which equals the number of calendar days that Executive
was employed by any member of the Company during the calendar year in which the Date of Termination occurs and (B) the
denominator of which equals 365 or 366, as applicable (the “Pro-Rata Bonus”), payable as described in Section 2(b); and
1
3
COBRA premium payments for group health care coverage continuation, or other continuation coverage
payments, for or equal to a period of twenty-four (24) months following the Date of Termination, paid in accordance with
Section 2(d).
(iii)
(b)
Timing of Payments. Subject to Executive’s satisfaction of the Release Conditions and so long as (and only if)
Executive satisfies the Release Conditions and abides by the terms of Section 4, the CIC Severance Payment and the Pro-Rata Bonus
shall be paid to Executive in accordance with the election form attached hereto as Exhibit B; provided, however, that in the event
Executive fails to properly execute the Election Form for any reason, all such payments shall be made to Executive in a lump sum
within sixty (60) days following the Date of Termination.
Equity Incentive Awards. For clarity, in the event that an Executive’s employment with the Company is
terminated for any reason, all outstanding equity incentive awards then held by such Executive will be treated in accordance with the
award agreement applicable to such award or governing plan, as applicable.
(c)
(d)
COBRA. During the eighteen month period immediately following Executive’s date of termination pursuant to
Section 2(a), (the “Benefit Continuation Period”) provided that Executive elects to continue coverage for Executive and Executive’s
spouse and eligible dependents, if any, under the Company’s group health plans pursuant to COBRA, the Company shall pay, promptly
and directly, on a monthly basis the amount Executive would be required to pay to effect and continue such coverage (the “COBRA
Benefit”). Each payment of the COBRA Benefit shall be paid directly to the health plan providers. Notwithstanding the foregoing,
Executive shall only be eligible to receive such COBRA continuation coverage until the earliest of: (i) the last day of the Benefit
Continuation Period; (ii) the date Executive is no longer eligible to receive COBRA continuation coverage; and (iii) the date on which
Executive becomes eligible to receive coverage under a group health plan sponsored by another employer (and any such eligibility shall
be promptly reported to the Company by Executive). In the event that Executive is remains eligible to receive the COBRA Benefit for
the entirety of the Benefits Continuation Period, then following the end of the Benefits Continuation Period, the Company will pay to
the Executive a lump sum cash payment equal to the cost of an additional six (6) months of the COBRA Benefit, calculated using costs
applicable to Executive and any eligible spouse and dependents on the last day of the Benefits Continuation Period, with such lump
sum payment to be paid within ten (10) business days following the last day of the Benefits Continuation Period. Executive will
promptly notify the Company of any circumstances or events that would be necessary for the Company to fulfill (or cease) its payment
obligations pursuant to this Section 2(d). Notwithstanding the foregoing, if the provision of the benefits described in this paragraph
cannot be provided in the manner described above without penalty, tax or other adverse impact on Executive or the Company, then the
Company and Executive shall negotiate in good faith to determine an alternative manner in which the Company provides substantially
equivalent benefits to Executive.
3.
Certain Excise Taxes. Notwithstanding anything to the contrary in this Agreement, if Executive is a “disqualified
individual” (as defined in Section 280G(c) of the Code), and the payments and benefits provided for in this Agreement, together with
any other payments and benefits which Executive has the right to receive from the Company Group, would constitute a “parachute
payment” (as defined in Section 280G(b)(2) of the Code), then the payments and benefits provided for in this Agreement shall be either
(a) reduced (but not below zero) so that the present value of such total amounts and benefits received by Executive from the Company
Group shall be one dollar ($1.00) less than three times Executive’s “base amount” (as defined in Section 280G(b)(3) of the Code) and
so that no portion of such amounts and benefits received by Executive shall be subject to the excise tax imposed by Section 4999 of the
Code or
4
(b) paid in full, whichever produces the better net after-tax position to Executive (taking into account any applicable excise tax under
Section 4999 of the Code and any other applicable taxes). The reduction of payments and benefits hereunder, if applicable, shall be
made by reducing, first, payments or benefits to be paid in cash hereunder in the order in which such payment or benefit would be paid
or provided (beginning with such payment or benefit that would be made last in time and continuing, to the extent necessary, through to
such payment or benefit that would be made first in time) and, then, reducing any benefit to be provided in-kind hereunder in a similar
order. The determination as to whether any such reduction in the amount of the payments and benefits provided hereunder is necessary
shall be made by Company in good faith. If a reduced payment or benefit is made or provided and through error or otherwise that
payment or benefit, when aggregated with other payments and benefits from the Company Group used in determining if a “parachute
payment” exists, exceeds one dollar ($1.00) less than three times Executive’s base amount, then Executive shall immediately repay
such excess to Company upon notification that an overpayment has been made. Nothing in this Section 3 shall require the Company to
be responsible for, or have any liability or obligation with respect to, Executive’s excise tax liabilities under Section 4999 of the Code.
4.
Restrictive Covenants.
(a)
Confidentiality. In the course of Executive’s employment with the Company and the performance of Executive’s
duties on behalf of the Company Group following the Effective Date, Executive will be provided with, and will have access to,
Confidential Information (as defined below). In consideration of Executive’s receipt and access to such Confidential Information and,
and as an express inducement for the Company to enter into this Agreement, Executive shall comply with this Section 4.
(i)
Both during the term of Executive’s employment with the Company and thereafter, except as expressly
permitted by this Agreement or by an authorized representative of the Company in writing, Executive shall not disclose any
Confidential Information to any person or entity and shall not use any Confidential Information except for the benefit of the
Company Group. Executive shall follow all Company policies and protocols regarding the security of all documents and other
materials containing Confidential Information (regardless of the medium on which Confidential Information is stored). The
covenants of this Section 4(a) shall apply to all Confidential Information, whether now known or later to become known to
Executive during the period that Executive is employed by or affiliated with the Company or any other member of the Company
Group.
(ii)
Notwithstanding any provision of this Agreement to the contrary, Executive may make the following
disclosures and uses of Confidential Information (A) disclosures to other employees of the Company Group who have a need to
know the information in connection with the businesses of the Company Group; (B) disclosures to customers and suppliers
when, in the reasonable and good faith belief of Executive, such disclosure is in connection with Executive’s performance of
Executive’s duties and is in the best interests of the Company Group; (C) disclosures and uses that are approved in writing by
the Company; or (D) disclosures to a person or entity that has (1) been retained by a member of the Company Group to provide
services to one or more members of the Company Group and (2) agreed in writing to abide by the terms of a confidentiality
agreement in a form acceptable to the Company.
Upon the Date of Termination, and at any other time upon request of the Company, Executive shall
promptly surrender and deliver to the Company all documents (including electronically stored information) and all copies
thereof and all other materials of any nature containing or pertaining to all Confidential Information and
(iii)
5
any other Company Group property (including any Company Group-issued computer, mobile device or other equipment) in
Executive’s possession, custody or control and Executive shall not retain any such documents or other materials or property of
the Company Group. Within five (5) days of any such request, Executive shall certify to the Company in writing that all such
documents, materials and property have been returned to the Company.
(iv)
All trade secrets, non-public information, designs, ideas, concepts, improvements, product developments,
discoveries and inventions, whether patentable or not, that are or have been conceived, made, developed or acquired by or
disclosed to Executive, individually or in conjunction with others, during the period that Executive is or has been employed by
the Company or any other member of the Company Group (whether during business hours or otherwise and whether on the
Company’s premises or otherwise) that relate to any member of the Company Group’s businesses or properties, products or
services (including all such information relating to corporate opportunities, operations, future plans, methods of doing business,
business plans, strategies for developing business and market share, research, financial and sales data, pricing terms,
evaluations, opinions, interpretations, acquisition prospects, the identity of customers or acquisition targets or their
requirements, the identity of key contacts within customers’ organizations or within the organization of acquisition prospects, or
marketing and merchandising techniques, prospective names and marks) is defined as “Confidential Information.” For
purposes of this Agreement, Confidential Information shall not include any information that (A) is or becomes generally
available to the public other than as a result of a disclosure or wrongful act of Executive or any of Executive’s agents; (B) was
available to Executive on a non-confidential basis before its disclosure by a member of the Company Group; or (C) becomes
available to Executive on a non-confidential basis from a source other than a member of the Company Group; provided,
however, that such source is not bound by a confidentiality agreement with, or other obligation with respect to confidentiality to,
a member of the Company Group.
(v)
Notwithstanding the foregoing, nothing in this Agreement or in any other agreement between Executive
and the Company or any other member of the Company Group shall prohibit or restrict Executive from lawfully (A) initiating
communications directly with, cooperating with, providing information to, causing information to be provided to, or otherwise
assisting in an investigation by, any governmental agency (including the Securities and Exchange Commission) regarding a
possible violation of any law; (B) responding to any inquiry or legal process directed to Executive from any governmental
agency; (C) testifying, participating or otherwise assisting in any action or proceeding by any governmental agency relating to a
possible violation of law, or (D) making any other disclosures that are protected under the whistleblower provisions of any
applicable law. Additionally, pursuant to the federal Defend Trade Secrets Act of 2016, an individual shall not be held
criminally or civilly liable under any federal or state trade secret law for the disclosure of a trade secret that: (1) is made (a) in
confidence to a federal, state or local government official, either directly or indirectly, or to an attorney and (b) solely for the
purpose of reporting or investigating a suspected violation of law; or (2) is made to the individual’s attorney in relation to a law
suit for retaliation against the individual for reporting a suspected violation of law or (3) is made in a complaint or other
document filed in a law suit or proceeding, if such filing is made under seal. Nothing in this Agreement requires Executive to
obtain prior authorization before engaging in any conduct described in this paragraph, or to notify the Company or any other
member of the Company Group that Executive has engaged in any such conduct.
6
(b)
Non-Competition; Non-Solicitation.
(i)
As an express incentive for the Company to enter into this Agreement, Executive has voluntarily agreed
to the covenants set forth in this Section 4(b). Executive agrees and acknowledges that the limitations and restrictions set forth
herein, including geographical and temporal restrictions on certain competitive activities, are reasonable in all respects, will not
cause Executive undue hardship, and are material and substantial parts of this Agreement intended and necessary to prevent
unfair competition and to protect the Company Group’s Confidential Information, goodwill and legitimate business interests.
directly or indirectly, for Executive or on behalf of or in conjunction with any other person or entity of any nature:
(ii)
During the Prohibited Period, Executive shall not, without the prior written approval of the Board,
(A)
engage or carry on within the Market Area in competition with any member of the Company
Group in any aspect of the Business, which prohibition shall prevent Executive from directly or indirectly (A) owning,
managing, operating or being an officer or director of any business that competes with any member of the Company
Group in the Market Area, or (B) joining, becoming an employee or consultant of, or otherwise being affiliated with, any
person or entity engaged in, or planning to engage in, the Business in the Market Area in competition, or anticipated
competition, with any member of the Company Group in any capacity (with respect to this clause (B)) in which
Executive’s duties or responsibilities involve direct or indirect responsibilities with respect to the Business;
solicit, canvass, approach, encourage, entice or induce any Protected Customer or Supplier of any
member of the Company Group to cease or lessen such Protected Customer’s or Supplier’s business with any member of
the Company Group; or
(B)
(C)
solicit, canvass, approach, encourage, entice or induce any employee or contractor of any member
of the Company Group with respect to whom or which Executive had direct or indirect responsibilities or about whom
Executive obtained Confidential Information to terminate his, her or its employment or engagement with any member of
the Company Group. Notwithstanding the foregoing or anything contained in this Agreement to the contrary, nothing
shall prohibit Executive from purchasing or owning less than five percent (5%) of any corporation or entity, provided
that such ownership represents a passive investment and that Executive is not a controlling person of, or a member of a
group that controls, such corporation.
(iii)
Because of the difficulty of measuring economic losses to the Company Group as a result of a breach or
threatened breach of the covenants set forth in this Section 4(b), and because of the immediate and irreparable damage that
would be caused to the members of the Company Group for which they would have no other adequate remedy, the Company
and each other member of the Company Group shall be entitled to enforce the foregoing covenants, in the event of a breach or
threatened breach, by injunctions and restraining orders from any court of competent jurisdiction, without the necessity of
showing any actual damages or that money damages would not afford an adequate remedy, and without the necessity of posting
any bond or other security. The aforementioned equitable relief shall not be the Company’s or any other member of the
Company Group’s exclusive remedy for a breach, but instead shall be in addition to all
7
other rights and remedies available to the Company and each other member of the Company Group at law and equity.
(iv)
The covenants in this Section 4(b), and each provision and portion hereof, are severable and separate, and
the unenforceability of any specific covenant (or portion thereof) shall not affect the provisions of any other covenant (or
portion thereof). Moreover, in the event any court of competent jurisdiction shall determine that the scope, time or territorial
restrictions set forth are unreasonable, then it is the intention of the parties that such restrictions be enforced to the fullest extent
which such court deems reasonable, and this Agreement shall thereby be reformed.
5.
Withholdings; Deductions. The Company may withhold and deduct from any benefits and payments made or to be
made pursuant to this Agreement (a) all federal, state, local and other taxes as may be required pursuant to any law or governmental
regulation or ruling and (b) any deductions consented to in writing by Executive.
6.
Applicable Law; Submission to Jurisdiction; Attorneys’ Fees. This Agreement shall in all respects be construed
according to the laws of the State of Texas without regard to its conflict of laws principles that would result in the application of the
laws of another jurisdiction. With respect to any claim or dispute related to or arising under this Agreement, the parties hereby
recognize and agree that should any resort to a court be necessary and permitted under this Agreement, then they consent to the
exclusive jurisdiction, forum and venue of the state and federal courts (as applicable) located in Harris County, Texas. Following the
occurrence of a Change of Control, if a dispute between the Parties (or between Executive and any successor to a member of the
Company Group) arises: (i) by virtue of the Company’s or its applicable successor’s or Affiliate’s failure to provide the severance
payments or benefits set forth in Section 2(a) above, and (ii) following Executive’s good faith written demand for such payments or
benefits, then the Company shall be responsible for paying Executive’s reasonable legal fees incurred after such written demand is
provided. WITH RESPECT TO ANY CLAIM OR DISPUTE RELATED TO OR ARISING OUT OF THIS AGREEMENT, THE
PARTIES HEREBY KNOWINGLY, VOLUNTARILY AND INTENTIONALLY WAIVE THEIR RIGHTS TO A JURY TRIAL.
7.
Entire Agreement and Amendment. This Agreement contains the entire agreement of the parties with respect to the
matters covered herein and supersede all prior and contemporaneous agreements and understandings, oral or written, between the
parties hereto concerning the subject matter hereof; provided, however, this Agreement shall be in addition to and complement (and
shall not replace or supersede) any other non-competition, non-solicitation, non-disclosure or return of property obligation that
Executive may have to any member of the Company Group (whether such obligation arises from contract, statute, common law or
otherwise). This Agreement may be amended only by a written instrument executed by both parties hereto.
8.
Severability and Reformation. If a court of competent jurisdiction determines that any provision of this Agreement (or
portion thereof) is invalid or unenforceable, then the invalidity or unenforceability of that provision (or portion thereof) shall not affect
the validity or enforceability of any other provision of this Agreement, and all other provisions shall remain in full force and effect. In
the event a court of competent jurisdiction shall determine that the scope of restrictions set forth herein are unreasonable, then it is the
intention of Executive and the Company that such restrictions be enforced to the fullest extent which the court deems reasonable, and
this Agreement shall thereby be reformed.
9.
Successors. This Agreement will be binding upon any successor to the Company, its assets, its businesses or its interest
(whether as a result of the occurrence of a Change in
8
Control or otherwise), in the same manner and to the same extent that the Company would be obligated under the Agreement if no
succession had taken place, and the term “Company” shall then refer to that successor. All payments and benefits that become due to
the Executive under the Agreement will inure to the benefit of his or her heirs, assigns, designees or legal representatives.
10.
Counterparts. This Agreement may be executed in any number of counterparts, including by electronic mail or .pdf,
each of which when so executed and delivered shall be an original, but all such counterparts shall together constitute one and the same
instrument. Each counterpart may consist of a copy hereof containing multiple signature pages, each signed by one party, but together
signed by both parties hereto.
11.
Notice. All notices, consents, waivers, and other communications required under this Agreement must be in writing and
will be deemed to have been duly given when (i) delivered by hand (with written confirmation of receipt), (ii) sent by facsimile (with
confirmation of receipt), provided that a copy is mailed by certified mail, return receipt requested, or (iii) when received by the
addressee, if sent by a nationally recognized overnight delivery service, in each case to the appropriate addresses and facsimile numbers
set forth below (or to such other addresses and facsimile numbers as a party may designate by notice to the other parties):
If to the Company:
CSI Compressco LP
Attn: General Counsel
1735 Hughes Landing Blvd., Suite 200
The Woodlands, Texas 77380
Facsimile No.: 281-364-4398
If to Executive:
[●]
12.
Clawback. Notwithstanding any provision in this Agreement to the contrary, to the extent required by (a) applicable law,
including, without limitation, the requirements of the Dodd- Frank Wall Street Reform and Consumer Protection Act of 2010, any
Securities and Exchange Commission rule or any applicable securities exchange listing standards and/or (b) any policy that may be
adopted or amended by the Board from time to time, all payments hereunder shall be subject to forfeiture, repurchase, recoupment
and/or cancellation to the extent necessary to comply with such law(s) and/or policy.
13.
At-Will Employment. Nothing herein alters the at-will nature of Executive’s employment or provides a guarantee of
Executive’s employment with the Company or any other member of the Company Group for any particular time, as Executive and the
Company remain free to end the employment relationship at any time and for any reason or no reason at all.
14.
Section 409A.
(a)
Notwithstanding any provision of this Agreement to the contrary, all provisions of this Agreement are intended to
comply with Section 409A of the Code, and the applicable Treasury regulations and administrative guidance issued thereunder
(collectively, “Section 409A”) or an exemption therefrom and shall be construed and administered in accordance with such intent. Any
payments under this Agreement that may be excluded from
9
Section 409A either as separation pay due to an involuntary separation from service or as a short-term deferral shall be excluded from
Section 409A to the maximum extent possible. Any payments to be made under this Agreement upon a termination of Executive’s
employment shall only be made if such termination of employment constitutes a “separation from service” under Section 409A. For
purposes of Section 409A, each installment payment provided under this Agreement shall be treated as a separate payment.
(b)
To the extent that any right to reimbursement of expenses or payment of any benefit in-kind under this
Agreement constitutes nonqualified deferred compensation (within the meaning of Section 409A), (i) any such expense reimbursement
shall be made by the Company no later than the last day of Executive’s taxable year following the taxable year in which such expense
was incurred by Executive, (ii) the right to reimbursement or in-kind benefits shall not be subject to liquidation or exchange for another
benefit, and (iii) the amount of expenses eligible for reimbursement or in-kind benefits provided during any taxable year shall not affect
the expenses eligible for reimbursement or in-kind benefits to be provided in any other taxable year; provided, that the foregoing clause
shall not be violated with regard to expenses reimbursed under any arrangement covered by Section 105(b) of the Code solely because
such expenses are subject to a limit related to the period in which the arrangement is in effect.
(c)
Notwithstanding any provision in this Agreement to the contrary, if any payment or benefit provided for herein
would be subject to additional taxes and interest under Section 409A if Executive’s receipt of such payment or benefit is not delayed
until the earlier of (i) the date of Executive’s death or (ii)the date that is six (6) months after the Date of Termination (such date, the
“Section 409A Payment Date”), then such payment or benefit shall not be provided to Executive (or Executive’s estate, if applicable)
until the Section 409A Payment Date. Notwithstanding the foregoing, the Company makes no representations that the payments and
benefits provided under this Agreement are exempt from, or compliant with, Section 409A and in no event shall any member of the
Company Group be liable for all or any portion of any taxes, penalties, interest or other expenses that may be incurred by Executive on
account of non- compliance with Section 409A.
[Remainder of Page Intentionally Blank;
Signature Page Follows]
10
IN WITNESS WHEREOF, the Company and Executive have caused this Agreement to be executed and effective as of the
Effective Date.
CSI COMPRESSCO LP
By: CSI Compressco GP LLC,
it’s General Partner
By:
Name:
Title:
EXECUTIVE
Name:
Signature Page to
Severance Agreement
Exhibit A
[Form of Release]
A-1
SEPARATION AGREEMENT AND GENERAL RELEASE OF CLAIMS
This Separation Agreement and General Release of Claims (this “Release”) is entered into by [ ● ] (“Executive”) and CSI
Compressco LP, a Delaware limited partnership (the “Company”) and is the Release, as referenced (and defined) the Change in Control
Severance Agreement effective as of [●], 2023 by and between Executive and the Company (the “CIC Agreement”). Capitalized terms
not defined herein have the meanings given to them in the CIC Agreement.
1.
Executive’s Separation. Executive’s employment with the Company ended as of [●] (the “Termination Date”). As of
the Termination Date, Executive was no longer employed by the Company or any of its Affiliates.
2.
Severance Payment. Provided that Executive (x) executes this Release on or after the Termination Date and returns a
copy of this signed Release to the Company so that it is received by the Company, care of [NAME] [ADDRESS AND/OR E-MAIL
ADDRESS], no later than forty-five (45) days after the Termination Date (the “Release Expiration Date”); (y) does not revoke
Executive’s acceptance of this Release pursuant to Section 4(c) below; and (z) abides by the terms of Section 4 of the CIC Agreement,
then the Company shall provide Executive with the CIC Severance Payment, the Pro-Rata Bonus and the Continued Benefit Payment,
each as set forth in the CIC Agreement and, as applicable, the Election Form executed by Executive.
3.
Release of Claims.
(a)
As consideration for (and as a condition of) the payment to Executive of the consideration referenced in Section 2 (and
any portion thereof), Executive, on behalf of Executive and Executive’s successors and anyone purporting to claim through or on behalf
of Executive, hereby forever, fully and finally releases, acquits, and discharges the Company, CSI Compressco GP LLC, each of their
respective parents, subsidiaries, and other affiliates and each of the foregoing entities’ respective past, present and future affiliates and
subsidiaries and each of the foregoing entities’ respective predecessors, successors, shareholders, members, partners, officers,
managers, directors, fiduciaries, employees, representatives, agents, and benefit plans (and the fiduciaries of such plans), in their
personal and representative capacities (collectively, the “Released Parties” and each a “Released Party”), from liability for, and does
hereby covenant and agree never to institute or cause to be instituted any lawsuit, arbitration or similar proceeding against any of the
Released Parties based upon, claims, demands, losses, indebtedness, agreements, promises, causes of action, obligations, damages and
liabilities of any nature whatsoever, in law or in equity, whether or not known, suspected or claimed, that Executive has ever had, has
claimed to have, now has, or could have against any Released Party by reason of any act, event, occurrence, or thing existing or
occurring on or before the date that Executive signs this Release (the “Signing Date”), including any and all claims, demands, losses,
indebtedness, agreements, promises, causes of action, obligations, damages and liabilities relating to Executive’s ownership of any
interest in any Released Party, Executive’s employment with or engagement by any Released Party, Executive’s awards under any
compensation or bonus plan or arrangement sponsored or maintained by any Released Party, or any other acts or omissions related to
any matter existing or occurring on or prior to the Signing Date, including: (i) any alleged violation of any federal, state or local labor
or employment law, including those relating to anti-discrimination and anti-retaliation, or any other local, state or federal law,
regulation or ordinance, including, for the avoidance of doubt, the Age Discrimination in Employment Act (including as amended by
the Older Workers Benefit Protection Act); Title VII of the Civil Rights Act of 1964; the Civil Rights Act of 1991; Sections 1981
through 1988 of Title 42 of the United States Code; the Americans with Disabilities Act of 1990; the Employee Retirement Income
Security Act of 1974 (“ERISA”); the Family and Medical Leave Act of 1993; the Immigration Reform Control Act; the Americans
with Disabilities Act of 1990; the
A-2
Occupational Safety and Health Act; the Sarbanes-Oxley Act of 2002 and the Dodd-Frank Wall Street Reform and Consumer
Protection Act; any federal, state or local wage and hour law; the Texas Labor Code (including the Texas Payday Law, the Texas Anti-
Retaliation Act, Chapter 21 of the Texas Labor Code, and the Texas Whistleblower Act); (ii) any public policy, contract, tort, or
common law claim, including any claim for defamation, emotional distress, fraud or misrepresentation of any kind, promissory
estoppel, breach of any implied duty of good faith and fair dealing, breach of implied or express contract, breach of fiduciary duty or
wrongful discharge; (iii) any allegation for costs, fees, or other expenses including attorneys’ fees incurred in, or with respect to, any
Released Claims (as defined below); (iv) any claim, whether direct or derivative, arising from, or relating to, Executive’s status as a
holder of any shares or interests in any Released Party; (v) any and all rights, benefits or claims Executive may have under (x) any
employment agreement, the CIC Agreement, incentive plan, bonus agreement, or award agreement, or otherwise with respect to any
amount owed on or before the Signing Date or (y) any other agreement, plan or arrangement with, or sponsored or maintained by, any
Released Party; and (vii) any claim for compensation or benefits of any kind through the Signing Date (collectively, the “Released
Claims”). THIS RELEASE INCLUDES MATTERS ATTRIBUTABLE TO THE SOLE OR PARTIAL NEGLIGENCE
(WHETHER GROSS OR SIMPLE) OR OTHER FAULT, INCLUDING STRICT LIABILITY, OF ANY OF THE RELEASED
PARTIES.
(b)
The foregoing release does not release or impair (i) any rights to vested benefits under an employee benefit plan of any
Released Party that is subject to ERISA and that cannot be released pursuant to ERISA, (ii) any claims first arising after the Signing
Date, or (iii) Executive’s ability to file a claim for unemployment insurance or workers’ compensation benefits. Further, nothing in this
Release prevents Executive from filing any non-legally waivable claim, including a challenge to the validity of this Agreement, with the
Equal Employment Opportunity Commission, the Securities and Exchange Commission, or other federal, state or local governmental
agency or commission (collectively “Governmental Agencies”) or participating in (or cooperating with) any investigation or
proceeding conducted by any Governmental Agency; however, Executive understands and agrees that, to the extent permitted by law,
Executive is waiving any and all rights to recover any monetary or personal relief or recovery from the Released Parties as a result of
such Governmental Agency proceeding or subsequent legal actions. Nothing herein waives (and the Released Claims shall not include)
Executive’s right to receive an award for information provided to a Governmental Agency (including, for the avoidance of doubt, any
monetary award or bounty from any governmental agency or regulatory or law enforcement authority in connection with any protected
“whistleblower” activity), and nothing herein or in any other agreement between Executive and any Released Party shall prohibit or
restrict Executive from (w) initiating communications directly with, cooperating with, providing information or making statements to,
causing information to be provided to, or otherwise assisting in an investigation by, any Governmental Agency; (x) responding to any
inquiry or legal process directed to Executive from any Governmental Agency; (y) testifying, participating or otherwise assisting in any
action or proceeding by any Governmental Agency; or (z) making any disclosures that are protected under the whistleblower provisions
of any applicable law. Nothing in this Agreement requires Executive to obtain prior authorization before engaging in any conduct
described in the previous sentence or to notify any Released Party that Executive engaged in any such conduct.
(c)
Except as provided in (b) above, Executive promises that Executive will not file, instigate or participate in any
proceeding against any of the Released Parties relating to any of the Released Claims. In the event Executive breaches the covenant
contained in this Section 3(c), Executive agrees to indemnify the Released Parties for all damages and expenses, including attorneys’
fees, incurred by any Released Parties in defending, participating in or investigating any matter or proceeding covered by this Section 3.
A-3
4.
Executive Acknowledgments; Advice to Consult with Legal Counsel. This is an important legal document. Executive
is advised to consult with legal counsel of Executive’s choosing before signing this Release.
(a)
Executive acknowledges that Executive’s entry into this Release is a condition to Executive’s receipt of the consideration
set forth in Section 2, and that, in the absence of timely executing and returning this Release and complying with its terms, Executive
would not be entitled to receive such consideration (or any portion thereof).
(b)
Executive further acknowledges that: (i) Executive has had sufficient time (and at least forty-five (45) days) since this
Release was first provided to Executive to consider this Release before the execution and delivery hereof to the Company; and (ii)
Executive has been advised, and hereby is advised in writing, to discuss this Release with an attorney of Executive’s choice before
signing this Release, and Executive has had adequate opportunity to do so. Executive further agrees that no changes to this Release
after the time it was first provided to Executive, whether material or immaterial, will re-start the period for Executive to consider
whether to enter into this Release.
(c)
Executive has seven (7) days after signing this Release to revoke it (such seven-day period is referred to herein as the
“Release Revocation Period”). This Release will not become effective or enforceable unless the Release Revocation Period has expired
without Executive exercising Executive’s revocation right. To be effective, such revocation must be in writing received by the
Company, care of [NAME] at [ADDRESS AND/OR E-MAIL ADDRESS], so that it is received by [NAME] no later than 11:59 p.m.
Houston, Texas time, on the last day of the Release Revocation Period. If an effective revocation is delivered in the foregoing manner
and timeframe, then no consideration shall be provided to Executive pursuant to Section 2, and the release of claims set forth in Section
3. shall be of no force or effect, and this Release shall be null and void; provided, however, Section 1 shall remain in full force and
effect.
(d)
This Release and the releases and covenants contained herein shall be binding upon Executive, Executive’s heirs,
executors, administrators, assigns, agents, and anyone purporting to claim through or on behalf of Executive. This Release and the
releases and covenants contained herein shall inure to the benefit of all Released Parties.
(e)
Executive has been provided with, and attached to this Agreement is, a listing of: (i) the job titles and ages of all
employees selected for participation in the exit incentive program or other employment termination program pursuant to which
Executive is being offered this Release; (ii) the job titles and ages of all employees in the same job classification or organizational unit
who were not selected for participation in the program; and (iii) information about the unit affected by the program, including any
eligibility factors for such program and any time limits applicable to such program.
5.
Counterparts. This Release may be executed in one or more counterparts (including portable document format (.pdf)
and facsimile counterparts), each of which shall be deemed to be an original, but all of which together will constitute one and the same
Release.
6.
Severability. To the extent permitted by applicable law, the Company and Executive hereby agree that any term or
provision of this Release that renders such term or provision or any other term or provision hereof invalid or unenforceable in any
respect shall be severable and shall be modified or severed to the extent necessary to avoid rendering such term or provision invalid or
unenforceable, and such modification or severance shall be accomplished in the manner that most nearly preserves the benefit of the
parties’ bargain hereunder.
A-4
7.
Headings; References; Interpretations. Section headings have been inserted for purposes of convenience and shall not
be used for interpretive purposes. The words “hereof,” “herein” and “hereunder” and other compounds of the word “here” shall refer to
the entire Release and not to any particular provision hereof. The use herein of the word “including” following any general statement,
term or matter shall not be construed to limit such statement, term or matter to the specific items or matters set forth immediately
following such word or to similar items or matters, whether or not non-limiting language (such as “without limitation”, “but not limited
to”, or words of similar import) is used with reference thereto, but rather shall be deemed to refer to all other items or matters that could
reasonably fall within the broadest possible scope of such general statement, term or matter. The word “or” as used herein is not
exclusive and is deemed to have the meaning “and/or.” All references herein to a law, agreement, instrument or other document shall be
deemed to refer to such law, agreement, instrument or other document as amended, supplemented, modified and restated from time to
time to the extent permitted by the provisions thereof. Neither this Release nor any uncertainty or ambiguity herein shall be construed
against any party, whether under any rule of construction or otherwise. This Release has been reviewed by each of the parties and shall
be construed and interpreted according to the ordinary meaning of the words used so as to fairly accomplish the purposes and intentions
of the parties.
[Signature Page Follows]
A-5
IN WITNESS WHEREOF, the parties hereto have executed this Release with the intent to be legally bound.
[EXECUTIVE NAME]
[Executive Name]
Date
CSI COMPRESSCO LP
By:
Name:
Title:
A-6
Exhibit B
[Severance Payment Election Form]
B-1
***MUST BE COMPLETED AND RETURNED TO DEREK J. ANCHONDO,
GENERAL COUNSEL, BY DECEMBER 18, 2023***
CHANGE IN CONTROL SEVERANCE AGREEMENT
Severance Payment Election Form
Executive Last Name First Middle
This Severance Payment Election Form (the “Election Form”) has been made this _____ day of December, 2023, between the Executive and the Company. All capitalized
words shall have the meaning given to the same term under the Change in Control Severance Agreement dated December [•], 2023 (the “Agreement”). Please fill out only
Section A or Section B, as applicable.
Section A: Waiver of Election
I do not wish to elect an alternative payment date pursuant to Section 2(b) of the Agreement. If applicable, I will receive my CIC Severance Payment and the Pro-Rata
Bonus (together, the “Severance Payments”) at the default time or times set forth in Section 2(b) of the Agreement.
Section B: Payment Date Election
I elect that my Severance Payments (if any) be paid to me according to the schedule noted below. I understand that I may check the box for as few as one (1), and as
many as four (4), payment dates. If I choose more than one payment date, the amounts due will be split equally between the dates checked. Notwithstanding any elections
made below, in no event shall any portion of the payments be made to me following December 31, 2025, therefore if any portion of the Severance Payments remain unpaid
as of December 31, 2025, all remaining payments will be made to me in lump sum payment on December 31, 2025.
Sixty (60) days following my Date of Termination
Six (6) months following my Date of Termination
Twelve (12) months following my Date of Termination
Eighteen (18) months following my Date of Termination
I acknowledge that (i) certain events, as further described in the Agreement document, may supersede the payment election I have made pursuant to this Election Form,
including my compliance with the Release Conditions and any restrictive covenants contained within the Agreement; and (ii) I have been furnished with, and have carefully
read, the Agreement and have been given the opportunity to (a) ask questions of, and receive answers from, the Company concerning the terms and conditions of the
Agreement and other related matters, and (b) obtain any additional information necessary to evaluate the merits and risks of executing this Election Form, including
consulting with my own personal counsel or tax advisors. I further acknowledge that all payment elections pursuant to this Election Form and the Agreement are intended
to comply with Section 409A of the Code, and will be interpreted and administered in accordance with Section 409A of the Code to the fullest extent permissible under
law. This election shall become irrevocable following December 31, 2023. If any portion of this Election Form is found not to be compliant with Section 409A of the Code
or is not executed properly, all Severance Payments will be made in accordance with the default payment provisions of Section 2(b) of the Agreement.
In Witness Whereof, the parties hereto have entered into this Election Form on the day and year written above.
Company Group Representative Signature Executive Signature
Name Date
Title
Date
Severance Payment Election Form
B-2
CSI Compressco LP
List of Subsidiaries or Other Related Entities
December 31, 2023
EXHIBIT 21
Name
CSI Compressco LP
CSI Compressco Sub Inc.
CSI Compressco Finance Inc.
CSI Compression Holdings, LLC
Rotary Compressor Systems, Inc.
Compressor Systems de Mexico, S. de RL de CV
CSI Compressco Operating LLC
CSI Compressco Holdings LLC
CSI Compressco Field Services International LLC
Compressco de Argentina SRL
CSI Compressco International LLC
CSI Compressco Leasing LLC
Compressco Netherlands Cooperatief U.A.
Compressco Netherlands B.V.
Compressco Canada, Inc.
CSI Compressco Mexico Investment I LLC
CSI Compressco Mexico Investment II LLC
Providence Natural Gas, LLC
Production Enhancement Mexico, S. de RL de C.V.
Treating Holdco LLC
Spartan Energy Services LLC
Spartan International LLC
Gas Services Manpower, LLC
Spartan Terminals Operating, Inc.
Spartan Operating Company LLC
Jurisdiction
Delaware
Delaware
Delaware
Delaware
Delaware
Mexico
Delaware
Delaware
Delaware
Argentina
Delaware
Delaware
Netherlands
Netherlands
Canada
Delaware
Delaware
Oklahoma
Mexico
Delaware
Delaware
Delaware
Egyptian
Delaware
Delaware
Each of the following direct or indirect, wholly-owned subsidiaries of CSI Compressco LP, a Delaware limited partnership (the “Partnership”) is either
(i) a co-issuer of or (ii) guarantees, jointly and severally, on a senior unsecured basis, the registered debt securities of the Partnership listed below:
Subsidiary Guarantors and Co-Issuer
EXHIBIT 22
Co-Issuer
1. CSI Compressco Finance Inc., a Delaware corporation
Subsidiary Guarantors
1. CSI Compressco Field Services International LLC
2. CSI Compressco Holdings LLC
3. CSI Compressco International LLC
4. CSI Compressco Leasing LLC
5. CSI Compressco Operating LLC
6. CSI Compressco Sub Inc.
7. CSI Compression Holdings LLC
8. Rotary Compressor Systems, Inc.
1
Exhibit 23.1
CONSENT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
We have issued our reports dated March 1, 2024, with respect to the consolidated financial statements and internal control over financial reporting included in the
Annual Report of CSI Compressco, LP, on Form 10-K for the year ended December 31, 2022. We consent to the incorporation by reference of said reports in the
Registration Statements of CSI Compressco LP on Forms S-3 (File No. 333-228400 effective November 30, 2018, File No. 333- 256737, and File 333-261870) and
on Forms S-8 (File No. 333-175007, File No. 333-228675, and File No. 333-262527).
/s/ GRANT THORNTON LLP
Houston, Texas
March 1, 2024
Certification Pursuant to
Rule 13a-14(a) or 15d-14(a) of the Exchange Act
As Adopted Pursuant to
Section 302 of the Sarbanes-Oxley Act of 2002
EXHIBIT 31.1
I, John E. Jackson, certify that:
1.
2.
3.
4.
I have reviewed this annual report on Form 10-K for the fiscal year ended December 31, 2023, of CSI Compressco LP;
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to
make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the
period covered by this report;
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material
respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined
in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f)
and 15d-15(f)) for the registrant and have:
a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our
supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by
others within those entities, particularly during the period in which this report is being prepared;
b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our
supervision, 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;
c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the
effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most
recent fiscal quarter (the registrant’s fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to
materially affect, the registrant’s internal control over financial reporting; and
5.
The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting,
to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent function):
a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are
reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal
control over financial reporting.
Date:
March 1, 2024
/s/John E. Jackson
John E. Jackson
Chief Executive Officer of CSI Compressco GP LLC,
General Partner of CSI Compressco LP
(Principal Executive Officer)
Certification Pursuant to
Rule 13a-14(a) or 15d-14(a) of the Exchange Act
As Adopted Pursuant to
Section 302 of the Sarbanes-Oxley Act of 2002
EXHIBIT 31.2
I, Jonathan W. Byers, certify that:
1.
2.
3.
4.
I have reviewed this annual report on Form 10-K for the fiscal year ended December 31, 2023, of CSI Compressco LP;
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to
make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the
period covered by this report;
Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material
respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;
The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined
in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f)
and 15d-15(f)) for the registrant and have:
a) designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our
supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by
others within those entities, particularly during the period in which this report is being prepared;
b) designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our
supervision, 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;
c) evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the
effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and
d) disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most
recent fiscal quarter (the registrant’s fourth quarter in the case of an annual report) that has materially affected, or is reasonably likely to
materially affect, the registrant’s internal control over financial reporting; and
5.
The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting,
to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent function):
a) all significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are
reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
b) any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal
control over financial reporting.
Date:
March 1, 2024
/s/Jonathan W. Byers
Jonathan W. Byers
Chief Financial Officer of CSI Compressco GP LLC,
General Partner of CSI Compressco LP
(Principal Financial Officer)
Certification Pursuant to
18 U.S.C. Section 1350
As Adopted Pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002
EXHIBIT 32.1
In connection with the Annual Report of CSI Compressco LP (the “Partnership”) on Form 10-K for the year ending December 31, 2023, as
filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, John E. Jackson, Chief Executive Officer of CSI
Compressco GP LLC, the General Partner of the Partnership, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of
the Sarbanes-Oxley Act of 2002, that:
(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the
Partnership.
Dated:
March 1, 2024
/s/John E. Jackson
John E. Jackson
Chief Executive Officer of CSI Compressco GP LLC,
General Partner of CSI Compressco LP
(Principal Executive Officer)
A signed original of this written statement required by Section 906 has been provided to the Partnership and will be retained by the Partnership and furnished to the
Securities and Exchange Commission or its staff upon request.
Certification Pursuant to
18 U.S.C. Section 1350
As Adopted Pursuant to
Section 906 of the Sarbanes-Oxley Act of 2002
EXHIBIT 32.2
In connection with the Annual Report of CSI Compressco LP (the “Partnership”) on Form 10-K for the year ending December 31, 2023, as
filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Jonathan W. Byers, Chief Financial Officer of CSI
Compressco GP LLC, the General Partner of the Partnership, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of
the Sarbanes-Oxley Act of 2002, that:
(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the
Partnership.
Dated:
March 1, 2024
/s/Jonathan W. Byers
Jonathan W. Byers
Chief Financial Officer of CSI Compressco GP LLC,
General Partner of CSI Compressco LP
(Principal Financial Officer)
A signed original of this written statement required by Section 906 has been provided to the Partnership and will be retained by the Partnership and furnished to the
Securities and Exchange Commission or its staff upon request.