HELIX ENERGY SOLUTIONS GROUP INC - Annual Report: 2022 (Form 10-K)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-K

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For the fiscal year ended December 31, 2022

or

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For the transition period from__________ to__________

Commission file number 001-32936

HELIX ENERGY SOLUTIONS GROUP, INC.

(Exact name of registrant as specified in its charter)

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Registrant’s telephone number, including area code (281) 618-0400

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

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

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. ☑ Yes  ☐ 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.

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

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

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

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

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

The aggregate market value of the voting and non-voting common equity held by non-affiliates of the registrant as of June 30, 2022 was approximately $442.6 million based on the closing price of the registrant’s common stock as quoted on the New York Stock Exchange on June 30, 2022.

The number of shares of the registrant’s common stock outstanding as of February 17, 2023 was 152,153,912.

DOCUMENTS INCORPORATED BY REFERENCE

Portions of the definitive Proxy Statement for the Annual Meeting of Shareholders to be held on May 17, 2023 are incorporated by reference into Part III hereof.

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HELIX ENERGY SOLUTIONS GROUP, INC. INDEX — FORM 10-K

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Forward Looking Statements

This Annual Report on Form 10-K (“Annual Report”) contains or incorporates by reference various statements that contain forward-looking information regarding Helix Energy Solutions Group, Inc. and represent our current expectations or forecasts of future events. This forward-looking information is intended to be covered by the safe harbor for “forward-looking statements” provided by the Private Securities Litigation Reform Act of 1995 as set forth in Section 27A of the Securities Act of 1933, as amended (the “Securities Act”), and Section 21E of the Securities Exchange Act of 1934, as amended (the “Exchange Act”). All statements included herein or incorporated by reference herein that are predictive in nature, that depend upon or refer to future events or conditions, or that use terms and phrases such as “achieve,” “anticipate,” “believe,” “estimate,” “budget,” “expect,” “forecast,” “plan,” “project,” “propose,” “strategy,” “predict,” “envision,” “hope,” “intend,” “will,” “continue,” “may,” “potential,” “should,” “could” and similar terms and phrases are forward-looking statements although not all forward-looking statements contain such identifying words. Included in forward-looking statements are, among other things:

Although we believe that the expectations reflected in our forward-looking statements are reasonable and are based on reasonable assumptions, they do involve risks, uncertainties and other factors that could cause actual results to differ materially from those in the forward-looking statements. These factors include:

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Our actual results could also differ materially from those anticipated in any forward-looking statements as a result of a variety of factors, including those described in “Risk Factors” beginning on page 18 and “Management’s Discussion and Analysis of Financial Condition and Results of Operations” beginning on page 35 of this Annual Report. Should one or more of the risks or uncertainties described in this Annual Report occur, or should underlying assumptions prove incorrect, our actual results and plans could differ materially from those expressed in any forward-looking statements.

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We caution you not to place undue reliance on forward-looking statements. Forward-looking statements are only as of the date they are made, and other than as required under the securities laws, we assume no obligation to update or revise forward-looking statements, all of which are expressly qualified by the statements in this section, or provide reasons why actual results may differ. All forward-looking statements, express or implied, included in this Annual Report are expressly qualified in their entirety by this cautionary statement. This cautionary statement should also be considered in connection with any subsequent written or oral forward-looking statements that we or persons acting on our behalf may issue. We urge you to carefully review and consider the disclosures made in this Annual Report and our reports filed with the Securities and Exchange Commission (“SEC”) and incorporated by reference herein that attempt to advise interested parties of the risks and factors that may affect our business. Please see “Website and Other Available Information” for further details.

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PART I

Item 1. Business

OVERVIEW

Helix Energy Solutions Group, Inc. (together with its subsidiaries, unless context requires otherwise, “Helix,” the “Company,” “we,” “us” or “our”) was incorporated in 1979 and in 1983 was re-incorporated in the state of Minnesota. We are an international offshore energy services company that provides specialty services to the offshore energy industry, with a focus on well intervention, robotics and full-field decommissioning operations. Our services are centered on a three-legged business model well positioned to facilitate global energy transition by maximizing production of remaining oil and gas reserves, supporting renewable energy developments and decommissioning end-of-life oil and gas fields. For additional information regarding business operations, see sections titled “Our Operations” included within Item 1. Business of this Annual Report.

Our principal executive offices are located at 3505 West Sam Houston Parkway North, Suite 400, Houston, Texas 77043; our phone number is 281-618-0400. Our common stock trades on the New York Stock Exchange (“NYSE”) under the ticker symbol “HLX.” Our Chief Executive Officer submitted the annual CEO certification to the NYSE in June 2022 as required under its Listed Company Manual. Our principal executive officer and our principal financial officer have made the certifications required under Section 302 of the Sarbanes-Oxley Act, which are included as exhibits to this Annual Report.

Please refer to the subsection “Certain Definitions” on page 16 for definitions of additional terms commonly used in this Annual Report. Unless otherwise indicated, any reference to Notes herein refers to Notes to Consolidated Financial Statements in Item 8. Financial Statements and Supplementary Data located elsewhere in this Annual Report.

OUR OPERATIONS

We provide a range of services to the oil and gas and renewable energy markets primarily in the Gulf of Mexico, U.S. East Coast, Brazil, North Sea, Asia Pacific and West Africa regions. We have expanded our service capabilities to the Gulf of Mexico shelf with the acquisition of the Alliance group of companies (collectively “Alliance”) on July 1, 2022, which we have re-branded as Helix Alliance. Our services are segregated into four reportable business segments: Well Intervention, Robotics, Production Facilities and our new reporting segment, Shallow Water Abandonment, which was formed in the third quarter 2022 comprising the Helix Alliance business.

Our Well Intervention segment provides services enabling our customers to safely access offshore wells for the purpose of performing well production enhancement or decommissioning operations, thereby avoiding drilling new wells by extending the useful lives of existing wells and preserving the environment by safely decommissioning aged wells and restoring the seabed. Our well intervention vessels include the Q4000, the Q5000, the Q7000, the Seawell, the Well Enhancer, and the Siem Helix 1 and Siem Helix 2 chartered vessels. Our well intervention equipment includes intervention systems such as intervention riser systems (“IRSs”), subsea intervention lubricators (“SILs”) and the Riserless Open-water Abandonment Module (“ROAM”), some of which we provide on a stand-alone basis.

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Our Robotics segment provides trenching, seabed clearance, offshore construction and inspection, repair and maintenance (“IRM”) services to both the oil and gas and the renewable energy markets globally, thereby assisting the delivery of affordable and reliable energy and supporting the responsible transition away from a carbon-based economy. Additionally, our Robotics services are used in and complement our well intervention services. Our Robotics segment includes remotely operated vehicles (“ROVs”), trenchers, the IROV boulder grab and robotics support vessels under term charters as well as spot vessels as needed.

Our Shallow Water Abandonment segment provides services in support of the upstream and midstream ‎industries predominantly in the Gulf of Mexico shelf, through offshore oilfield decommissioning and ‎reclamation, project management, engineered solutions, intervention, maintenance, repair, heavy lift and commercial diving services. Our Shallow Water Abandonment segment includes a diversified fleet of marine assets including liftboats, offshore supply vessels (“OSVs”), dive support vessels (“DSVs”), a heavy lift derrick barge, a crew boat and plug and abandonment (“P&A”) and coiled tubing systems.

Our Production Facilities segment includes the Helix Producer I (the “HP I”), the Helix Fast Response System (the “HFRS”) and our ownership of oil and gas properties. All of our current Production Facilities activities are located in the Gulf of Mexico.

Services we currently offer to the offshore oil and gas market worldwide include:

Services we currently offer to the offshore renewable energy market worldwide include:

Well Intervention

We engineer, manage and conduct well intervention operations, which include production enhancement and abandonment, and construction operations in water depths ranging from 100 to 10,000 feet. As major and independent oil and gas companies develop deepwater reserves, we expect the number of subsea trees to increase, which can improve long-term demand for well intervention services. Historically, drilling rigs have been used in subsea well intervention to enhance production and decommission wells. Our purpose-built well intervention vessels serve as work platforms and derive competitive advantages from their lower operating costs, with an ability to mobilize quickly and to maximize operational time by performing a broad range of tasks related to intervention, construction and IRM services. Our services provide cost advantages in the development and management of subsea reservoirs. We believe we offer efficiency gains from our specialized intervention assets.

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Our well intervention business currently includes seven purpose-built well intervention vessels and 12 intervention systems (including two recently acquired deepwater IRSs) providing services primarily in the Gulf of Mexico, Brazil, the North Sea and West Africa, with expansion into Asia Pacific.

In the Gulf of Mexico, the Q4000, a riser-based semi-submersible well intervention vessel, has been serving customers in the spot market since 2002. In 2010, the Q4000 served as a key emergency response vessel in the Macondo well control and containment efforts. The Q5000 riser-based semi-submersible well intervention vessel commenced operations in the Gulf of Mexico in 2015.

In Brazil, we provide well intervention services with the Siem Helix 1 and Siem Helix 2 vessels under long-term charter from Siem Offshore AS (“Siem”). The Siem Helix 1, which commenced operations in April 2017, completed its four-year contract with Petróleo Brasileiro S.A. (“Petrobras”) in 2021 and worked on short-term accommodations and ROV projects prior to commencing a long-term P&A project for Trident Energy do Brasil Ltda. (“Trident”) starting December 2022. The Siem Helix 2 commenced operations for Petrobras in December 2017 and is under contract through at least December 2024.

In the North Sea, the Well Enhancer has performed well intervention, abandonment and coiled tubing services since it joined our fleet in 2009. The Seawell has provided well intervention and abandonment services since 1987, and the vessel underwent major capital upgrades in 2015 to extend its estimated useful economic life by approximately 15 years.

The Q7000, a semi-submersible well intervention vessel built to U.K. North Sea standards and capable of working globally, commenced operations in January 2020 performing various integrated well intervention operations offshore Nigeria. The Nigeria campaign completed in 2022 and the vessel is currently mobilizing for decommissioning campaigns in Asia Pacific and Brazil.

Our Subsea Services Alliance with SLB leverages the parties’ capabilities to provide a unique, fully integrated offering to clients, combining marine support with well access and control technologies. Through our alliance, we and SLB jointly developed a 15K IRS and the ROAM.

Robotics

We have been actively engaged in robotics for over three decades. We operate robotics assets to complement offshore construction, maintenance and well intervention services for the oil and gas market and to support offshore renewable energy projects for the renewable energy market. We often integrate our services with chartered vessels. Our robotics business operates globally, with primary operations in the North Sea, Gulf of Mexico, U.S. East Coast, Asia Pacific, Brazil and West Africa regions. As global marine construction activity levels increase and as the complexity and water depths of the facilities increase, the use and scope of robotics services has expanded. Our robotics assets and experience, coupled with our chartered vessel fleet and schedule flexibility, allow us to meet the technological challenges of our customers’ subsea activities worldwide. As of December 31, 2022, our robotics assets included 41 work class ROVs, seven trenchers (including three recently acquired trenchers) and the IROV boulder grab. We charter vessels on a long-term or a spot basis to support deployment of our robotics assets.

Over the last decade and especially in recent years there has been an increase in offshore activity associated with the growing renewable energy market. As the level of activity for offshore renewable energy projects, including wind farm projects, has increased, so has the need for reliable services and related equipment. Historically, this work was performed by barges and other similar vessels, but these types of services are increasingly being contracted to vessels more suitable for harsh offshore weather conditions, especially in the North Sea where offshore wind farming is currently concentrated. We provide cable burial services related to subsea power cable installations as well as seabed clearing and site preparation services around the world using our chartered vessels, trenchers and ROVs. In 2022, revenues derived from offshore renewable energy contracts accounted for 43% of our global Robotics segment revenues. We believe that over the long term our robotics business is positioned to continue providing services to a range of clients in the renewable energy market.

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Shallow Water Abandonment

In July 2022, we completed the acquisition of Alliance, a vertically integrated company specializing in comprehensive offshore oilfield decommissioning services predominantly in the Gulf of Mexico shelf. Helix Alliance’s decommissioning offerings include well plugging and abandonment, subsea infrastructure flushing and abandonments (or removals), platform decommissioning and structure removals, and subsea site clearance, and engineering, permitting and project management. In addition to its end-of-life decommissioning services, Helix Alliance offers services to support the full life cycle of offshore upstream and midstream industries, including oil and gas production through well intervention, coiled tubing and pumping; installations and construction; and IRM.

Production Facilities

We own and operate the HP I, a ship-shaped dynamically positioned floating production vessel capable of processing up to 45,000 barrels of oil and 80 million cubic feet of natural gas per day. The HP I has been under contract to the Phoenix field operator since February 2013 and is currently under an agreement through at least June 1, 2024.

We developed the HFRS in 2011 as a culmination of our experience as a responder in the 2010 Macondo well control and containment efforts. The HFRS combines the HP I, the Q4000 and the Q5000 with certain well control equipment that can be deployed to respond to a well control incident. We are under agreement through March 31, 2024 with various operators to provide access to the HFRS for well control purposes.

Our Production Facilities segment includes mature deepwater offshore wells, including two remaining wells acquired from Marathon Oil Corporation (“Marathon Oil”) in January 2019, for which Marathon Oil agreed to pay us certain amounts as we complete the related P&A work, and three wells and related subsea infrastructure acquired from MP Gulf of Mexico, LLC (“MP GOM”), a joint venture controlled by Murphy Exploration & Production Company – USA, in August 2022.

GEOGRAPHIC AREAS

We primarily operate in the Gulf of Mexico, U.S. East Coast, Brazil, North Sea, Asia Pacific and West Africa regions. Our North Sea operations and our Gulf of Mexico shelf operations related to Helix Alliance are usually subject to seasonal changes in demand, which generally peaks in the summer months and declines in the winter months. See Note 14 for revenues as well as property and equipment by geographic location.

CUSTOMERS

Our customers consist primarily of major and independent oil and gas producers and suppliers, pipeline transmission companies, renewable energy companies and offshore engineering and construction firms. The level of services required by any particular customer depends, in part, on the size of that customer’s budget in a particular year. Consequently, a customer that accounts for a significant portion of revenues in one fiscal year may represent an immaterial portion of revenues in subsequent fiscal years. The percentages of consolidated revenues from major customers (those representing 10% or more of our consolidated revenues) are as follows: 2022 — Shell (15%); 2021 — Petrobras (23%) and Shell (17%); and 2020 — Petrobras (28%) and BP (17%). We provided services to over 80 customers in 2022.

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COMPETITORS

The oilfield services and renewable energy services markets are highly competitive. Price and the ability to access specialized vessels, systems and other equipment, attract and retain skilled personnel, and operate safely are important factors to competing in these markets. Our principal competitors in well intervention include AKOFS Offshore, Baker Hughes, C-Innovation, Expro, FTAI, Oceaneering, TechnipFMC, Trendsetter and international drilling contractors. Our principal competitors in the robotics business include Atlantic Marine, Briggs Marine, C-Innovation, DeepOcean, DOF Subsea, Fugro, James Fisher, Oceaneering, ROVOP and UTROV. Our principal competitors in shallow water abandonment include Aries Marine, C-Dive, Cardinal Services, Chet Morrison, Crescent Energy Services, Laredo Offshore Services, Manson Gulf, Offshore Liftboats, Offshore Marine Contractors, Seacor, Shore Offshore, Supreme Energy, Turnkey Offshore Project Services and White Fleet. Our competitors may have more or differing financial, personnel, technological and other resources available to them.

ENVIRONMENTAL, SOCIAL AND GOVERNANCE

Safety, Sustainability and Value Creation – our core goals – support our vision as a preeminent offshore energy transition company. ESG initiatives and disclosures are embedded in these business values and priorities with a top-down approach led by management and our Board of Directors (our “Board”). Specifically, the Corporate Governance and Nominating Committee of our Board (the “Governance Committee”) oversees, assesses and reviews the disclosure and reporting of any ESG matters, including with respect to climate change, regarding the Company’s business and industry, and that committee’s charter formally incorporates oversight of ESG matters as a stated responsibility. Sustainability is reviewed on an ongoing basis in conjunction with environmental, health and safety, and social matters at each Governance Committee meeting.

While the Board oversees strategic ESG initiatives, our Climate Change Action Committee, comprised of key leaders from QHSE, legal, our business units and management, evaluates Helix’s impact on climate change, implements our go-forward strategies and assists in providing comprehensive disclosures. Our expectations and goals align with the underlying belief that fossil fuels will not be eliminated from consumption, but rather there will be a global transition from relying primarily on fossil fuels to a more balanced approach that includes renewable energy, such as wind farms and other alternative fuels.

We emphasize continual improvement by establishing goals to reduce our environmental impact, improve our safety record and increase transparency for our stakeholders. In 2022, we disclosed our GHG Emissions metrics for 2019, 2020 and 2021 and our reduction targets for GHG Emissions by 2024. We understand that establishing these targets provides value to us as a company and is valued by our stakeholders, and we are committed to providing transparency with respect to our GHG Emissions. In tandem with such disclosures and targets, we continued to support renewable energy through our three-legged business model well positioned to facilitate global energy transition by maximizing production of remaining oil and gas reserves, supporting renewable energy developments and decommissioning end-of-life oil and gas fields. Our services facilitate both the responsible transition from a carbon-based economy and extending the value and therefore the life cycle of underutilized wells, which in turn helps clients avoid drilling new wells. These efforts are published in greater detail in our most recent Corporate Sustainability Report, a copy of which is available on our website at www.helixesg.com/about-helix/our-company/corporate-sustainability.

HUMAN CAPITAL RESOURCES

Labor Practices

As of December 31, 2022, we had 2,280 employees. Of our total employees, we had 447 employees covered by collective bargaining agreements or similar arrangements. We consider our overall relationships with our employees, suppliers and vendors to be satisfactory. Further, we expect all employees to maintain a work environment free from harassment, discrimination and abuse, and one where employees treat each other with respect, dignity and courtesy. These tenets are further described in our Human Rights Policy and our Supplier and Vendor Expectations, both of which are available on our website at www.helixesg.com/about-helix/our-company/corporate-governance.

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Human Rights, Anti-Slavery and Anti-Human Trafficking

We are committed to respecting and protecting human rights everywhere we operate and expect similar standards of suppliers, vendors and partners, including requiring periodic assessments and audits to confirm there is no modern slavery or human trafficking in our supply chains or in any part of our business. Our workplace policies and procedures demonstrate our commitment to acting ethically and with integrity in all our business relationships, and to implementing and enforcing effective systems and controls to prevent slavery and human trafficking from taking place anywhere in our supply chains. We provide periodic Anti-Human Trafficking training for employees to further arm our workforce with the tools to identify and prevent human trafficking. Our Modern Slavery Statement is available on our website, located at www.helixesg.com/modern-slavery-statement.

Employee Health and Safety

Our corporate vision of a zero-incident workplace is based on the belief that all incidents are preventable and that we manage our working conditions to eliminate unsafe behavior. We have established a corporate culture in which QHSE takes priority over our other business objectives. Everyone at Helix has the authority and the duty to “STOP WORK” they believe is unsafe. Helix management actively encourages critical safety behaviors and employees to work in compliance with our goals to avoid injuries to people, environmental disturbances and damage to assets. We empower our employees to feel safe and confident that their safety and the safety of those around them are our primary concern. Our QHSE management systems and training programs were developed based on common industry work practices, and by employees with on-site experience who understand the risk and physical challenges of the offshore work environment. Certain management systems of our business units have been independently assessed and registered compliant with ISO 9000 (Quality Management Systems), ISO 14001 (Environmental Management Systems), and ISO 45001 (Occupational Health and Safety Management Systems).

Health and Safety during COVID-19

The nature of offshore operations requires our offshore crew members as well as our customers and vendors to periodically travel to and from vessels. In response to the COVID-19 pandemic, both Helix and Alliance implemented numerous health and safety protocols. In light of updated guidance pertaining to the COVID-19 pandemic, rates of community transmission, and widespread vaccination, we continue to evolve our protocols to align with what we understand to be best practices designed to protect our personnel, those partners with whom we work and their collective families.

Employee Engagement, Diversity and Inclusion

Employee Tenure and Turnover

We track tenure and voluntary employee turnover. We then use this data to develop our human capital management strategy. As of December 31, 2022, 57% of our workforce had been with Helix for five years or longer, and our global voluntary turnover rate was 12.5% (excluding employees added through our Alliance acquisition, which closed on July 1, 2022).

Training, Engagement and Improvement

Proper and recurring training is necessary so our staff can be as prepared as possible to perform our operations safely. Our staff receives up to date and relevant training required for their jobs, and Helix leadership actively engages staff so that behaviors reflect the training and critical safety approach we all desire. The initial vessel orientation for new hires is the first of many steps in shaping those behaviors. Each vessel and shore-based employee is assigned a Qualifications and Training Matrix that specifies the qualifications and training that the employee is required to have for the applicable position. Training is tracked annually and evaluated to confirm the quality of training. Ongoing and thoughtful employee participation is a vital element in the success of our QHSE processes. While we believe in the strength and effectiveness of our QHSE programs, we continuously review how we can improve our control of QHSE risks through the behavior and feedback of our employees.

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Diversity and Inclusion

We are committed to diversity and inclusion throughout our workforce. In 2022, our worldwide workforce represented 34 different nationalities. Our hiring managers and human resources departments in all regions partner to find the best candidates without regard to factors such as race, religion, color, national origin, age, sex, gender, sexual orientation, gender identity, disability, marital status, veteran status, genetic information or any other basis that would be in violation of any applicable federal, state, local or international law. Employing people with different backgrounds, experiences and perspectives makes Helix a stronger business. To reinforce this commitment in the U.S., our Houston office implemented a blind hiring initiative through which Human Resources can mask certain identifying characteristics of new hire candidates at the initial stages of the hiring process, including characteristics that may identify a person’s gender, race, disability, ethnicity or nationality. We are committed to attracting and retaining high-performing employees through this diverse talent base and evaluating and promoting throughout our organization based on skills and performance. The latest statistics showing the breakdown of how our employees (excluding employees added through our Alliance acquisition, which closed on July 1, 2022) self-identify their ethnicity is available in our most recent Corporate Sustainability Report, a copy of which is available on our website at www.helixesg.com/about-helix/our-company/corporate-sustainability.

Board Diversity

Our Board defines diversity expansively and has determined that it is desirable to have diverse viewpoints, professional experiences, backgrounds (including gender, race, ethnicity and educational backgrounds) and skills, with the principal qualification of a director being the ability to act effectively on behalf of Company shareholders. As part of a long-standing refreshment process, the Governance Committee of our Board remained engaged in a search for additional independent directors with the diverse characteristics sought by our Board and in September 2022, our Board added two new gender and ethnically diverse members.

GOVERNMENT REGULATION

Overview

We provide services primarily in the Gulf of Mexico, U.S. East Coast, Brazil, North Sea, Asia Pacific and West Africa regions, and as such we are subject to numerous laws and regulations, including international treaties, flag state requirements, environmental laws and regulations, requirements for obtaining operating and navigation licenses, local content requirements, and other national, state and local laws and regulations in force in the jurisdictions in which our vessels and other assets operate or are registered, all of which can significantly affect the ownership and operation of our vessels and other assets. Beginning in 2019 we operate mature offshore oil and gas wells, some of which are producing and which ultimately we plan to decommission. Being an owner and operator of wells subjects us to additional regulatory oversight from the Bureau of Ocean Energy Management (“BOEM”) and the Bureau of Safety and Environmental Enforcement (“BSEE”).

International Conventions

Our vessels are subject to applicable international maritime convention requirements, which include, but are not limited to, the International Convention for the Prevention of Pollution from Ships (“MARPOL”), the International Convention on Civil Liability for Oil Pollution Damage of 1969, the International Convention on Civil Liability for Bunker Oil Pollution Damage of 2001 (ratified in 2008), the International Convention for the Safety of Life at Sea of 1974 (“SOLAS”), the International Safety Management Code for the Safe Operation of Ships and for Pollution Prevention (the “ISM Code”), the Code for the Construction and Equipment of Mobile Offshore Drilling Units (the “MODU Code”), and the International Convention for the Control and Management of Ships’ Ballast Water and Sediments (the “BWM Convention”). These regimes are applicable in most countries where we operate; however, the vessel’s flag state and the country where we operate may impose additional requirements, as described below. In addition, these conventions impose liability for certain environmental discharges, including strict liability in some cases.

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U.S. Overview

In the U.S., we are subject to the jurisdiction of the U.S. Coast Guard (the “Coast Guard”), the U.S. Environmental Protection Agency (the “EPA”) as well as state environmental protection agencies for those jurisdictions in which we operate, three divisions of the U.S. Department of the Interior (BOEM, BSEE and the Office of Natural Resources Revenue), and the U.S. Customs and Border Protection (the “CBP”), as well as classification societies such as the American Bureau of Shipping (the “ABS”). We are also subject to the requirements of the federal Occupational Safety and Health Act and comparable state laws that regulate the protection of employee health and safety for our land-based operations.

International Overview

We provide services globally and generally can be subject to local laws and regulations wherever we operate. Those laws and regulations generally govern environmental, labor, health and safety and other matters. The regulatory regimes of the U.K. and Brazil are of particular importance given the locations of our current operations. The U.K. Continental Shelf in the North Sea is regulated by the Oil and Gas Authority (the “OGA”) in accordance with the Petroleum Act 1998. The OGA controls the Petroleum Operations Notices with which we comply for various well intervention and subsea construction projects, as required. The OGA also regulates the environmental requirements for our operations in the North Sea. We comply with the Oil Pollution Prevention and Control Regulations 2005 as required. In the North Sea, international regulations govern working hours and the working environment, as well as standards for diving procedures, equipment and diver health. We also note that the U.K.’s exit from the European Union (the “EU”) may result in the imposition of new laws, rules or regulations affecting operations inside U.K. territorial waters.

Our operations in Brazil are predominantly regulated by the Brazilian National Agency of Petroleum, Natural Gas and Biofuels, the federal government agency responsible for the regulation of the oil sector. Additional regulatory oversight is provided, among others, by the Brazilian Institute of the Environment and Renewable Natural Resources, which oversees Brazilian environmental legislation, implements the National Environmental Policy and exercises control and supervision of the use of natural resources, the Brazilian Health Regulatory Agency, which regulates products and services subject to health regulations, the Ministry of Labor, which regulates a variety of subjects including work-related accident prevention and the use of machinery and equipment, and the Brazilian Navy, which regulates maritime operations.

Operating Certification

Each of our vessels is subject to regulatory requirements of the country in which the vessel is registered, also known as the flag state. In addition, the country in which a vessel is operating may have its own requirements with respect to safety and environmental protections. These requirements must be satisfied in order for the vessel to operate. Flag state requirements are largely established by international treaties such as MARPOL, SOLAS, the ISM Code and the MODU Code, and in some instances, specific requirements of the flag state. These include engineering, safety, safe manning and other requirements related to the maritime industry. Each of our vessels must also maintain its “in-class” status with a classification society, evidencing that the vessel has been built and maintained in accordance with the rules of the classification society and complies with applicable flag state rules and international conventions. Our vessels generally must undergo a class survey once every five years. In the U.S., the Coast Guard sets safety standards and is authorized to investigate marine incidents, recommend safety standards, and inspect vessels at will. We also adhere to manning requirements implemented by the Coast Guard for operations on the U.S. Outer Continental Shelf (“OCS”).

Local Content Requirements and Cabotage Rules

We are subject to local content requirements with respect to vessels, equipment and crews utilized in certain of our operations. Governments in some countries, notably in Australia, Brazil and in the West Africa region, remain active in establishing and enforcing such requirements along with other aspects of the energy industries in their respective countries.

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A number of jurisdictions where we operate require that certain work may only be performed by vessels built and/or registered in that jurisdiction. In some instances, an exemption may be available, or we may be subject to an additional tax to use a non-local vessel. In the U.S., we are subject to the Coastwise Merchandise Statute (commonly known as the “Jones Act”), which generally provides that only vessels built in the U.S., owned 75% by U.S. citizens, and crewed by U.S. citizen seafarers may transport merchandise between points in the U.S. The Jones Act has been applied to offshore oil and gas and wind farm work in the U.S. through interpretations by the CBP.

BOEM and BSEE

Our business is affected by laws and regulations as well as changing tax laws and policies relating to the offshore energy industry in general. The operation of oil and gas properties located on the OCS is regulated primarily by BOEM and BSEE. Among other requirements, BOEM requires lessees of OCS properties to post bonds or provide other adequate financial assurance in connection with the P&A of wells located offshore and the removal of production facilities. Following the Deepwater Horizon incident in April 2010, BSEE implemented enhanced standards for companies engaged in the development of offshore oil and gas wells. As an owner and operator of wells located on the OCS, we are required to have a BSEE-approved Oil Spill Response Plan. BSEE also oversees requirements relating to well control equipment utilized during intervention and decommissioning operations. As a provider of well control equipment, we are subject to these regulations for operation, maintenance and surface and subsea testing of our equipment during intervention and decommissioning operations.

Other Regulatory Impact

Additional proposals and proceedings before various international, federal and state regulatory agencies and courts could affect the energy industry, including curtailing production and demand for fossil fuels. We cannot predict when or whether any such proposals may become effective, or how they will be interpreted or enforced.

ENVIRONMENTAL REGULATION

Overview

Our operations are subject to a variety of national (including federal, state and local) and international laws and regulations governing the discharge of materials into the environment or otherwise relating to environmental protection. Numerous governmental departments issue rules and regulations to implement and enforce these laws that are often complex, costly to comply with, and carry substantial administrative, civil and possibly criminal penalties for compliance failure. Under these laws and regulations, we may be liable for remediation or removal costs, damages, civil, criminal and administrative penalties and other costs associated with releases of hazardous materials (including oil) into the environment, and that liability may be imposed on us even if the acts that resulted in the releases were in compliance with all applicable laws at the time those acts were performed. Some of the environmental laws and regulations applicable to our business operations are discussed below, but this discussion does not cover all environmental laws and regulations that govern or otherwise affect our operations.

MARPOL

The U.S. is one of approximately 175 member countries party to the International Maritime Organization (“IMO”), an agency of the United Nations responsible for developing measures to improve the safety and security of international shipping and to prevent marine pollution from ships. The IMO has negotiated MARPOL, which imposes on the shipping industry environmental standards relating to oil spills, management of garbage, the handling and disposal of noxious liquids, harmful substances in packaged forms, sewage, and air emissions.

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OPA

The Oil Pollution Act of 1990, as amended (“OPA”), imposes a variety of requirements on offshore facility owners or operators in the U.S., and the lessee or permittee of the U.S. area in which an offshore facility is located, as well as owners and operators of vessels. Any of these entities or persons can be “responsible parties” and are strictly liable for removal costs and damages arising from facility and vessel oil spills or threatened spills. Failure to comply with OPA may result in the assessment of civil, administrative and criminal penalties. In addition, OPA requires owners and operators of vessels over 300 gross tons to provide the Coast Guard with evidence of financial responsibility to cover the cost of cleaning up oil spills from those vessels. A number of foreign jurisdictions also require us to present satisfactory evidence of financial responsibility. We satisfy these requirements through appropriate insurance coverage.

Water Pollution

For operations in the U.S., the Clean Water Act imposes controls on the discharge of pollutants into the navigable waters of the U.S. and imposes potential liability for the costs of remediating releases of petroleum and other substances. Permits must be obtained to discharge pollutants into state and federal waters. The EPA issues Vessel General Permits (“VGPs”) covering discharges incidental to normal vessel operations, including ballast water, and implements various training, inspection, monitoring, recordkeeping and reporting requirements, as well as corrective actions upon identification of each deficiency. Additionally, certain state regulations and VGPs prohibit the discharge of produced waters and sand, drilling fluids, drill cuttings and certain other substances related to the exploration for, and production of, oil and natural gas into certain coastal and offshore waters. Many states have laws analogous to the Clean Water Act and also require remediation of releases of hazardous substances in state waters. Internationally, the BWM Convention covers mandatory ballast water exchange requirements.

Air Pollution and Emissions

A variety of regulatory developments, proposals and requirements and legislative initiatives focused on restricting the emissions of carbon dioxide, methane and other greenhouse gases apply to the jurisdictions in which we operate. Annex VI of MARPOL addresses air emissions, including emissions of sulfur and nitrous oxide, and requires the use of low sulfur fuels worldwide in both auxiliary and main propulsion diesel engines on vessels. The IMO designates the waters off North America as an Emission Control Area, meaning that vessels operating in the U.S. must use fuel with a sulfur content no greater than 0.1%. Directives have been issued designed to reduce the emission of nitrogen oxides and sulfur oxides. These can impact both the fuel and the engines that may be used onboard vessels.

CERCLA

The Comprehensive Environmental Response, Compensation, and Liability Act (“CERCLA”) requires the remediation of releases of hazardous substances into the environment in the U.S. and imposes liability, without regard to fault or the legality of the original conduct, on certain classes of persons, including owners and operators of contaminated sites where the release occurred and those companies that transport, dispose of or arrange for the disposal of, hazardous substances released at the sites.

OCSLA

The Outer Continental Shelf Lands Act, as amended (“OCSLA”), provides the U.S. government with broad authority to impose environmental protection requirements applicable to lessees and permittees operating in the OCS. Specific design and operational standards may apply to OCS vessels, rigs, platforms, vehicles and structures. Violations can result in substantial civil and criminal penalties, as well as potential court injunctions that could curtail operations and cancel leases.

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Current Compliance and Potential Impact

We believe that we are in compliance in all material respects with the applicable environmental laws and regulations to which we are subject. We maintain a robust operational compliance program, and we maintain and update our programs to meet or exceed applicable regulatory requirements. We do not anticipate that compliance with existing environmental laws and regulations will have a material effect upon our capital expenditures, earnings or competitive position. However, changes in environmental laws and regulations, changes in the ways such laws and regulations are interpreted or enforced, or claims for damages to persons, property, natural resources or the environment, could result in substantial costs and liabilities, and thus there can be no assurance that we will not incur significant environmental compliance costs or liabilities in the future.

INSURANCE MATTERS

Our businesses involve a high degree of operational risk. Hazards such as vessels sinking, grounding, colliding and sustaining damage from severe weather conditions and operational hazards such as rigging failures, human error, or accidents are inherent in marine operations. These hazards can cause marine and subsea operational equipment failures resulting in personal injury or loss of life, severe damage to and destruction of property and equipment, pollution or environmental damage and the suspension of operations. Damages arising from such occurrences may result in claims that could be significant.

As discussed below, we maintain insurance policies to cover some of our risk of loss associated with our operations. We maintain the amount of insurance we believe is prudent based on our estimated loss potential. However, not all of our business activities can be insured at the levels we desire because of either limited market availability or unfavorable economics.

Our current insurance program generally covers a 12-month period beginning July 1 each year.

We maintain Hull and Increased Value insurance, which provides coverage for physical damage up to an agreed amount for each vessel. We also carry Protection and Indemnity (“P&I”) insurance, which covers liabilities arising from the operation of vessels, and General Liability insurance, which covers liabilities arising from construction operations. Onshore employees are covered by Workers’ Compensation. Offshore employees and marine crews are covered by a Maritime Employers Liability (“MEL”) insurance policy, which covers Jones Act exposures. We maintain Operator Extra Expense coverage that provides certain coverage per each loss occurrence for a well control issue on oil and gas properties where we are the operator. In addition to the liability policies described above, we currently carry various layers of Umbrella Liability in excess of primary limits as well as OPA insurance for our offshore oil and gas properties with coverage as required by BOEM.

In addition, we maintain a separate insurance program for Helix Alliance, which provides physical damage coverage up to an agreed amount for each vessel. Helix Alliance onshore employees are covered by Workers’ Compensation, and Helix Alliance offshore employees and marine crews are covered by MEL insurance policy, which covers Jones Act exposures. We also carry a General Liability policy which covers liability arising from operations. In addition to the liability policies described above, we currently carry various layers of Umbrella Liability.

We customarily have agreements with our customers and vendors in which each contracting party is responsible for its respective personnel. Under these agreements we are indemnified against third-party claims related to the injury or death of our customers’ or vendors’ personnel, and vice versa. With respect to well work contracted to us, the customer is typically contractually responsible for pollution emanating from the well. We separately maintain additional coverage that would cover us under certain circumstances against any such third-party claims associated with well control events.

We receive workers’ compensation, MEL and other insurance claims in the normal course of business. We analyze each claim for its validity, potential exposure and estimated ultimate liability. Our services are provided in hazardous environments where events involving catastrophic damage or loss of life could occur, and claims arising from such an event may result in our being named as a responsible party. Although there can be no assurance the amount of insurance we carry is sufficient to protect us fully in all events, or that such insurance will continue to be available at current levels of cost or coverage, we believe that our insurance protection is adequate for our business operations.

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WEBSITE AND OTHER AVAILABLE INFORMATION

We maintain a website on the Internet with the address of www.helixesg.com. Copies of this Annual Report for the year ended December 31, 2022, previous and subsequent copies of our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q and Current Reports on Form 8-K, and any amendments thereto, are or will be available free of charge at our website as soon as reasonably practicable after they are filed with, or furnished to, the SEC. In addition, the “For the Investor” section of our website contains copies of our Code of Business Conduct and Ethics and our Code of Ethics for Chief Executive Officer and Senior Financial Officers and our Corporate Sustainability Report. We make our website content available for informational purposes only. Information contained on our website is not part of this report and should not be relied upon for investment purposes. Please note that prior to March 6, 2006, the name of the Company was Cal Dive International, Inc.

The SEC maintains an Internet website that contains reports, proxy and information statements, and other information regarding issuers that file electronically with the SEC, including us. The Internet address of the SEC’s website is www.sec.gov.

We satisfy the requirement under Item 5.05 of Form 8-K to disclose any amendments to our Code of Business Conduct and Ethics and our Code of Ethics for Chief Executive Officer and Senior Financial Officers and any waiver from any provision of those codes by posting that information in the “For the Investor” section of our website at www.helixesg.com.

CERTAIN DEFINITIONS

Defined below are certain terms helpful to understanding our business that are located throughout this Annual Report:

Bureau of Ocean Energy Management (BOEM):  BOEM is responsible for managing environmentally and economically responsible development of U.S. offshore resources. Its functions include offshore leasing, resource evaluation, review and administration of oil and gas exploration and development plans, renewable energy development, National Environmental Policy Act analysis and environmental studies.

Bureau of Safety and Environmental Enforcement (BSEE):  BSEE is responsible for safety and environmental oversight of U.S. offshore oil and gas operations, including permitting and inspections of offshore oil and gas operations. Its functions include the development and enforcement of safety and environmental regulations, permitting offshore exploration, development and production, inspections, offshore regulatory programs, oil spill response and newly formed training and environmental compliance programs.

Coiled tubing system:  A continuous length of steel tubing (coiled tubing), typically between 1” and 3.25” in diameter, wound onto a large reel together with an injector head, control console, power supply and well control stack. The coiled tubing is run inside a well’s production tubing primarily for debris cleanout, pumping fluids or fishing operations though there are numerous other applications.

Decommissioning:  The process of plugging and abandoning oil and gas wells and removing all associated infrastructure (pipelines, platforms, etc.). This is the final stage of oil and gas operations and typically occurs when all of the associated wells have reached the end of their useful production lives.

Deepwater:  Water depths exceeding 1,000 feet.

Dynamic Positioning (DP):  Computer directed thruster systems that use satellite-based positioning and other positioning technologies to provide the proper counteraction to wind, current and wave forces enabling a vessel to maintain its position without the use of anchors.

DP2:  Two DP systems on a single vessel providing the redundancy that allows the vessel to maintain position even in the absence of one DP system.

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DP3:  DP control system comprising a triple-redundant controller unit and three identical operator stations. The system is designed to withstand fire or flood in any one compartment. Loss of position should not occur from any single failure.

Dive support vessel (DSV):  A vessel used as a floating base for commercial diving projects, with the basic requirements to keep station accurately and reliably throughout the diving operation.

Heavy lift derrick barge:  A vessel with a crane capacity to lift large, heavy objects, primarily used for installation or removal of large offshore structures. Lifting capacities typically range from 500 to over 2,000 tons, compared to construction vessels which generally have less than 250 ton lifting capacity.

Intervention Riser System (IRS):  A subsea system that establishes a direct connection from a well intervention vessel, through a rigid riser, to a conventional or horizontal subsea tree in depths up to 10,000 feet. An IRS can be utilized for wireline intervention, production logging, coiled tubing operations, well stimulation, and full plug and abandonment operations, and provides well control in order to safely access the well bore for these activities.

Intervention system:  A subsea system that establishes a direct connection from a well intervention vessel to a subsea well in order to provide well control to safely access the well bore for well intervention activities. Intervention systems include Intervention Riser Systems (IRSs), Subsea Intervention Lubricators (SILs) and the Riserless Open-water Abandonment Module (ROAM).

Liftboat:  A self-propelled offshore vessel with moveable legs capable of elevating its hull above the surface of the sea to create a stable working platform as opposed to a floating vessel. These vessels are equipped with living quarters, open deck space and at least one crane for lifting operations.

Offshore support vessel (OSV):  A specially designed vessel for the logistical servicing of offshore platforms and subsea installations.

Plug and Abandonment (P&A):  P&A operations usually consist of placing several cement plugs in the well bore to isolate the reservoir and other fluid-bearing formations when a well reaches the end of its lifetime.

P&A system:  A set of surface equipment, typically consisting of wireline, pumps, cement blenders and tanks, that is used for placement of mechanical and/or cement plugs in the well bore to P&A a well.

QHSE:  Quality, Health, Safety and Environmental programs designed to protect the environment, safeguard employee health and avoid injuries.

Riserless Open-water Abandonment Module (ROAM):  A subsea system designed to act as a barrier to the environment during upper abandonment operations and during production tubing removal in open water, when run as a complement to an IRS. ROAM provides the ability to capture contaminants or gas within the system and circulate them back to the safe handling systems on board the vessel, such that no well contaminants are released into the environment.

Remotely Operated Vehicle (ROV):  A robotic vehicle used to complement, support and increase the efficiency of diving and subsea operations and for tasks beyond the capability of manned diving operations. ROV also includes ROVDrill, a seabed-based geotechnical investigation system deployed with an ROV system capable of taking cores from the seafloor in water depths up to 6,500 feet.

Saturation diving:  Divers working from special chambers for extended periods at a pressure equivalent to the pressure at the work site, generally required for work in water depths between 200 and 1,000 feet.

Shallow water:  Generally, water depths less than 1,000 feet, including the Gulf of Mexico shelf.

Site clearance:  Activities utilizing ROVs for the safe removal of obstructions, such as boulders, unexploded ordnance (UXOs) and debris, that would inhibit the construction of an offshore wind farm.

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Spot vessels:  Vessels not owned or under term charters but contracted on a short-term basis typically to perform specific projects.

Subsea Intervention Lubricator (SIL):  A riserless subsea system designed to provide access to the well bore while providing well control safety for activities that do not require a riser conduit. A SIL can be utilized for wireline, logging, light perforating, zone isolation, plug setting and removal, and decommissioning, and it facilitates access to subsea wells from a monohull vessel to provide safe, efficient and cost effective riserless well intervention and abandonment solutions.

Trencher or trencher system:  A subsea robotics system capable of providing post-lay trenching, inspection, burial and maintenance of submarine cables, flowlines and umbilicals in water depths of 30 to 7,200 feet across a range of seabed and environmental conditions.

Well intervention services:  Activities related to well maintenance and production management and enhancement services. Our well intervention operations include the utilization of slickline and electric line services, pumping services, specialized tooling and coiled tubing services.

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Item 1A. Risk Factors

Shareholders should carefully consider the following risk factors in addition to the other information contained herein. We operate globally in challenging and highly competitive markets and thus our business is subject to a variety of risks. The risks and uncertainties described below are not the only ones facing Helix. We are subject to a variety of risks that affect many other companies generally, as well as additional risks and uncertainties not known to us or that, as of the date of this Annual Report, we believe are not as significant as the risks described below. You should be aware that the occurrence of the events described in these risk factors and elsewhere in this Annual Report could have a material adverse effect on our business, financial position, results of operations and cash flows.

Market and Industry Risks

Our business is adversely affected by low oil and gas prices, which occur in a cyclical oil and gas market that continues to experience volatility.

Our services are substantially dependent upon the condition of the oil and gas market, and in particular, the willingness of oil and gas companies to make capital and other expenditures for offshore exploration, development, drilling and production operations. Although our services are used for other operations during the entire life cycle of a well, when industry conditions are unfavorable, oil and gas companies typically reduce their budgets for expenditures on all types of operations and defer certain activities to the extent possible.

The levels of both capital and operating expenditures largely depend on the prevailing view of future oil and gas prices, which is influenced by numerous factors, including:

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A period of low levels of activity by offshore oil and gas operators may adversely affect demand for our services, the utilization and/or rates we can achieve for our assets and services, and the outlook for our industry in general, all of which could lead to lower utilization of available vessels or similar assets and correspondingly downward pressure on the rates we can charge for our services. Given that our business is adversely affected by low oil prices, such conditions would negatively impact oil and gas companies’ willingness and ability to make capital and other expenditures. Additionally, our customers, in reaction to negative market conditions, may seek to negotiate contracts at lower rates, both during and at the expiration of the term of our contracts, to cancel earlier work and shift it to later periods, or to cancel their contracts with us even if cancellation involves their paying a cancellation fee. The extent of the impact of these conditions on our results of operations and cash flows depends on the strength of our industry environment and the demand for our services.

We continue to actively monitor ongoing military hostilities in Ukraine and applicable laws, sanctions and trade control restrictions resulting from the conflict. Any sanctions measures and increased governmental oversight and enforcement activities could adversely affect the global economy and supply chains as well as the oil and gas sector generally. The extent to which our operations and financial results may be affected by the ongoing conflict in Ukraine will depend on various factors, including the extent and duration of the conflict and its related effects on operating and capital spending by our oil and gas production customers.

We are subject to the effects of changing prices.

Inflation rates have been relatively low and stable over the previous three decades; however, inflation rates have risen significantly since 2021 due in part to supply chain disruptions and the effects of the COVID-19 pandemic. We bear the costs of operating and maintaining our assets, including labor and material costs as well as recertification and dry dock costs. Although we may be able to reduce some of our exposure to price increases through the rates we charge, competitive market pressures may affect our ability to pass along price adjustments, which may result in reductions in our operating margins and cash flows in the future.

The COVID-19 pandemic could continue to disrupt our operations and adversely impact our business and financial results.

In March 2020, the World Health Organization classified the outbreak of COVID-19 as a pandemic. The nature of COVID-19 led to worldwide shutdowns and halting of commercial and interpersonal activity, as governments around the world imposed regulations such as shelter-in-place orders, quarantines, travel bans and similar restrictions in efforts to control its spread. As of December 31, 2022, despite the rollout of vaccines and the successes of mitigation efforts, new strains of coronavirus have arisen and may continue to be identified that may be more contagious, more severe, and for which vaccinations may not be effective. Furthermore, although vaccines have been identified, their efficacy and rollout pose logistical and other challenges. The pandemic resulted in the global economy experiencing a significant slowdown and uncertainty in 2020, which led to a precipitous decline in oil prices in response to demand concerns, as further discussed herein. These events resulted in reduced operating and capital spending by oil and gas producers. Although the oil and gas market has recovered since 2020, we expect that the uncertainty surrounding the spread of COVID-19 will continue to create market disruption that may undermine the confidence in overall industry viability. We are currently unable to predict the duration or severity of the ongoing pandemic or the responses thereto, and these events may continue to adversely impact our financial condition and results of operations.

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The spread of COVID-19 to one or more of our locations, including our vessels, could significantly impact our operations. We have implemented various protocols for both onshore and offshore personnel in efforts to limit the impact of COVID-19, however those may not prove fully successful. The spread of COVID-19 to our onshore workforce could prevent us from supporting our offshore operations, we may experience reduced productivity as our onshore personnel work remotely, and any spread to our key management personnel may disrupt our business. Any outbreak on our vessels may result in the vessel, or some or all of a vessel crew (including customer crew), being quarantined and therefore impede the vessel’s ability to generate revenue. We have experienced several instances of COVID-19 among our offshore crew, and although to date we have managed to avoid major operational disruptions, there can be no guarantee that will remain the case. We have experienced challenges in connection with our offshore crew changes due to health and travel restrictions related to COVID-19, and those challenges and/or restrictions may continue or worsen. Further, we have been and may continue to be impacted by a decline in the available offshore workforce, whether due to the spread of COVID-19, considerations related to our protocols, attrition from our industry, or a combination of the foregoing.

Business and Operational Risks

Our backlog may not be ultimately realized for various reasons, our contracts may be terminated early, and our call-off work may be terminated earlier than expected.

As of December 31, 2022, backlog for our services supported by written agreements or contracts totaled $847 million, of which $533 million is expected to be performed in 2023.

We may not be able to perform under our contracts for various reasons giving our customers certain contractual rights under their contracts with us, which ultimately could include termination of a contract. In addition, our customers may seek to cancel, terminate, suspend or renegotiate our contracts, or our projects in Helix Alliance subject to call-off orders may be able to be terminated earlier than expected, in the event of our customers’ diminished demand for our services due to global or industry conditions affecting our customers and their own revenues. Some of these contracts provide for no cancellation fee or a cancellation fee that is substantially less than the expected rates from the contracts. In addition, some of our customers could experience liquidity issues or could otherwise be unable or unwilling to perform under a contract, in which case a customer may repudiate or seek to cancel or renegotiate the contract. The repudiation, early cancellation, termination or renegotiation of our contracts by our customers, or the termination of call-off work, could have a material adverse effect on our financial position, results of operations and cash flows. Furthermore, we may incur capital costs, we may charter vessels for the purpose of performing these contracts, and/or we may forgo or not seek other contracting opportunities in light of these contracts.

A large portion of our current backlog is concentrated in a small number of long-term contracts that we may fail to renew or replace.

Although historically our service contracts were of relatively short duration, over the past few years we performed a number of long-term contracts. We currently have contracts with four customers that represent approximately 69% of our total backlog as of December 31, 2022. Any cancellation, termination or breach of those contracts would have a larger impact on our operating results and financial condition than of our shorter-term contracts. Furthermore, our ability to extend, renew or replace our long-term contracts when they expire or obtain new contracts as alternatives, and the terms of any such contracts, will continue to depend on various factors, including market conditions and the specific needs of our customers. Given the historically cyclical nature of the oil and gas market, as we have experienced, we may not be able to extend, renew or replace the contracts or we may be required to extend, renew or replace expiring contracts or obtain new contracts at rates that are below our existing contract rates, or that have other terms that are less favorable to us than our existing contracts. Failure to extend, renew or replace expiring contracts or secure new contracts at comparable rates and with favorable terms could have a material adverse effect on our financial position, results of operations and cash flows.

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Our operations involve numerous risks, which could result in our inability or failure to perform operationally under our contracts and result in reduced revenues, contractual penalties and/or contract termination.

Our equipment and services are very technical and the offshore environment poses its own challenges. Performing the work we do pursuant to the terms of our contracts can be difficult for various reasons, including equipment failure or reduced performance, human error, third-party failure or other fault, design flaws, weather, water currents or soil conditions. In particular, our assets may experience challenges operating in new locations, presenting incremental complications; any of these factors could lead to performance concerns. The nature of offshore operations requires our offshore crew members as well as our customers and vendors to periodically travel to and from the vessels. The occurrence or threat of an epidemic or pandemic disease, including the COVID-19 pandemic and any related governmental regulations or other travel restrictions or safety measures, may impede our ability to execute such crewing or crew changes, which could lead to vessel downtime or suspension of operations, which may be beyond our control. Failure to perform in accordance with contract specifications can result in reduced rates (or zero rates), contractual penalties, and ultimately, termination in the event of sustained non-performance. Reduced revenues and/or contract termination due to our inability or failure to perform operationally could have a material adverse effect on our financial position, results of operations and cash flows.

Our customers and other counterparties may be unable to perform their obligations.

Continued industry uncertainty and domestic and global economic conditions, including the financial condition of our customers, lenders, insurers and other financial institutions generally, could jeopardize the ability of such parties to perform their obligations to us, including obligations to pay amounts owed to us. In the event one or more of our customers is adversely affected by the COVID-19 pandemic or otherwise, our business with them may be affected. We may face an increased risk of customers deferring work, declining to commit to new work, asserting claims of force majeure and/or terminating contracts, or our customers’, subcontractors’ or partners’ inability to make payments or remain solvent.

Although we assess the creditworthiness of our counterparties, a variety of conditions and factors could lead to changes in a counterparty’s liquidity and increase our exposure to credit risk and bad debts. In particular, our Robotics and Helix Alliance businesses tend to do business with smaller customers that may not be capitalized to the same extent as larger operators and/or that may be more exposed to financial loss in an uncertain economic environment. In addition, we may offer favorable payment or other contractual terms to customers in order to secure contracts. These circumstances may lead to more frequent collection issues. Our financial results and liquidity could be adversely affected and we could incur losses.

Our forward-looking statements assume that our customers, lenders, insurers and other financial institutions will be able to fulfill their obligations under our various contracts, credit agreements and insurance policies. The inability of our customers and other counterparties to perform under these agreements may materially adversely affect our business, financial position, results of operations and cash flows.

We may own assets with ongoing costs that cannot be recouped if the assets are not under contract, and time chartering vessels requires us to make ongoing payments regardless of utilization of and revenue generation from those vessels.

We own vessels, systems and other equipment for which there are ongoing costs, including maintenance, manning, insurance and depreciation. We may also construct assets without first obtaining service contracts covering the cost of those assets. Our failure to secure contracts for vessels or other assets could materially adversely affect our financial position, results of operations and cash flows.

Further, we charter our robotics support vessels under time charter agreements. We also have entered into long-term charter agreements for the Siem Helix 1 and Siem Helix 2 vessels. Should our contracts with customers be canceled, terminated or breached and/or if we do not secure work for the chartered vessels, we are still required to make charter payments. Making those payments absent revenue generation could have a material adverse effect on our financial position, results of operations and cash flows.

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Asset upgrade, modification, refurbishment, repair, dry dock and construction projects, and customer contractual acceptance of vessels, systems and other equipment, are subject to risks, including delays, cost overruns, loss of revenue and failure to commence or maintain contracts.

We incur significant upgrade, modification, refurbishment, repair and dry dock expenditures on our fleet from time to time. We also construct or make capital improvements to other assets. While some of these capital projects are planned, some are unplanned. Additionally, as assets age, they are more likely to be subject to higher maintenance and repair activities. These projects are subject to the many risks, including delay and cost overruns, inherent in any large capital project.

Actual capital expenditures could materially exceed our estimated or planned capital expenditures. Moreover, assets undergoing upgrades, modifications, refurbishments, repairs or dry docks may not earn revenue during the period they are out of service. Any significant period of such unplanned activity for our assets could have a material adverse effect on our financial position, results of operations and cash flows.

In addition, delays in the delivery of vessels and other assets being constructed or undergoing upgrades, modifications, refurbishments, repairs, or dry docks may result in delay in customer acceptance and/or contract commencement, resulting in a loss of revenue and cash flow to us, and may cause our customers to seek to terminate or shorten the terms of their contracts with us and/or seek damages under applicable contract terms. In the event of termination or modification of a contract due to late delivery, we may not be able to secure a replacement contract on favorable terms, if at all, which could have a material adverse effect on our business, financial position, results of operations and cash flows.

We may not be able to compete successfully against current and future competitors.

The industries in which we operate are highly competitive. An oversupply of offshore drilling rigs coupled with a significant slowdown in industry activities results in increased competition from drilling rigs as well as substantially lower rates on work that is being performed. Several of our competitors are larger and have greater financial and other resources to better withstand a prolonged period of difficult industry conditions. In order to compete for customers, these larger competitors may undercut us by reducing rates to levels we are unable to withstand. Further, certain other companies may seek to compete with us by hiring vessels of opportunity from which to deploy modular systems and/or be willing to take on additional risks. If other companies relocate or acquire assets for operations in the regions in which we operate, levels of competition may increase further and our business could be adversely affected.

Climate change might adversely impact our business operations and/or our supply chain.

Scientific consensus shows that carbon dioxide and other greenhouse gases in the atmosphere have caused and will in the future cause changes in weather patterns around the globe. Climatologists predict these changes will result in the increased frequency of extreme weather events and natural disasters which could disrupt our business operations or those of our customers or suppliers. In addition, concern about climate change and greenhouse gases may result in new or additional legal, legislative, and/or regulatory requirements to reduce or mitigate the effects of climate change on the environment. Any such new requirements could increase our operating costs and impede our ability to provide services to our customers.

The actual or perceived lack of sustainability of the oil and gas sector, or our failure to adequately implement and communicate ESG initiatives that demonstrate our own sustainability, may adversely affect our business.

Sustainability and ESG initiatives remain increasingly important factors in assessing a company’s outlook, as investors look to identify factors that they believe inform a company’s ability to create long-term value. We understand we have an important role to play as a steward of the people, communities and environments we serve, and we regularly look for ways to emphasize and improve our own ESG record. However the nature of the oil and gas sector in which we predominantly operate may impact in the near or long term sustainability sentiment of investors, lenders, other industry participants and individuals, as the global markets shift towards green energy and environmental conservation. This sentiment may in turn lead to a lack of investment, investability or borrowing capital, or a more negative overall perception related to the fossil fuel industry. Further, we may not succeed in implementing or communicating an ESG message that is well understood or received. As a result we may experience diminished reputation or sentiment, reduced access to capital markets and/or increased cost of capital, an inability to attract and retain talent, and loss of customers or vendors.

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Our North Sea and Helix Alliance businesses typically decline in the winter, and weather can adversely affect our operations.

Marine operations conducted in the North Sea and the Gulf of Mexico shelf are seasonal and depend, in part, on weather conditions. Historically, we have enjoyed our highest North Sea vessel utilization rates during the summer and fall when weather conditions are more favorable for offshore operations, and we typically have experienced our lowest North Sea utilization rates in the first quarter. Helix Alliance experiences slower winter season in its diving and certain vessel operations. As is common in our industry, where we do have utilization in these seasonal markets, we may bear the risk of delays caused by adverse weather conditions. Our results in any one quarter are not necessarily indicative of annual results or continuing trends.

Certain areas in which we operate experience unfavorable weather conditions including hurricanes and extreme storms on a relatively frequent basis. Substantially all of our facilities and assets offshore and along the Gulf of Mexico and the North Sea are susceptible to damage and/or total loss by these weather conditions. Damage caused by high winds and turbulent seas could potentially cause us to adjust service operations or curtail operations for significant periods of time until damage can be assessed and repaired. Moreover, even if we do not experience direct damage from any of these weather conditions, we may experience disruptions in our operations if our personnel is adversely impacted, or because customers may adjust their offshore activities due to damage to their assets, platforms, pipelines and other related facilities.

The operation of marine vessels is risky, and we do not have insurance coverage for all risks.

Vessel-based offshore services involve a high degree of operational risk. Hazards, such as vessels sinking, grounding, colliding and sustaining damage from severe weather conditions, are inherent in marine operations. These hazards can cause personal injury or loss of life, severe damage to and destruction of property and equipment, pollution or environmental damage, and suspension of operations. Damage arising from such occurrences may result in assertions of our liability. Insurance may not be sufficient or effective under all circumstances or against all hazards to which we may be subject. A successful liability claim for which we are not fully insured could have a material adverse effect on our financial position, results of operations and cash flows. Moreover, we can provide no assurance that we will be able to maintain adequate insurance in the future at rates that we consider reasonable. In some instances, certain insurance could become unavailable or available only for reduced amounts of coverage. For example, insurance carriers require broad exclusions for losses due to war risk and terrorist acts, and limitations for wind storm damage. The current insurance on our assets is in amounts approximating replacement value. In the event of property loss due to a catastrophic disaster, mechanical failure, collision or other event, insurance may not cover a substantial loss of revenue, increased costs and other liabilities, and therefore the loss of any of our assets could have a material adverse effect on us.

Our oil and gas operations involve a high degree of operational, contractual and financial risk, particularly risk of personal injury, damage, loss of equipment and environmental incidents.

In January 2019 we began owning oil and gas properties as part of our strategy to secure utilization for our vessels, systems and other equipment. Engaging in oil and gas production and transportation operations subjects us to certain risks inherent in the ownership and operation of oil and gas wells, including but not limited to uncontrolled flows of oil, gas, brine or well fluids into the environment; blowouts; cratering; pipeline or other facility ruptures; mechanical difficulties or other equipment malfunction; fires, explosions or other physical damage; hurricanes, storms and other natural disasters and weather conditions; and pollution and other environmental damage; any of which could result in substantial losses to us. Although we maintain insurance against some of these risks we cannot insure against all possible losses. Furthermore, such operations necessarily involve some degree of contractual counterparty risk, including for the transportation, marketing and sale of such production, and to the extent we have partners in any of the properties we own or operate. As a result, any damage or loss not covered by our insurance could have a material adverse effect on our financial condition, results of operations and cash flows.

Our customers may be unable or unwilling to indemnify us.

Consistent with standard industry practice, we typically obtain contractual indemnification from our customers whereby they agree to protect and indemnify us for liabilities resulting from various hazards associated with offshore operations. We can provide no assurance, however, that we will obtain such contractual indemnification or that our customers will be willing or financially able to meet their indemnification obligations.

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Our operations outside of the U.S. subject us to additional risks.

Our operations outside of the U.S. are subject to risks inherent in foreign operations, including:

Certain countries have in place or are in the process of developing complex laws for foreign companies doing business in these countries. Some of these laws are difficult to interpret, making compliance uncertain, and others increase the cost of doing business, which may make it difficult for us in some cases to be competitive. The combination of such laws with the local requirements and logistics necessitated by the COVID-19 pandemic have further increased the challenges of doing business in these countries. In addition, laws and policies of the U.S. affecting foreign trade, taxation and other commercial activity may adversely affect our international operations.

Failure to protect our intellectual property or other technology may adversely affect our business.

Our industry is highly technical. We utilize and rely on a variety of advanced assets and other tools, such as our vessels, DP systems, intervention systems, ROVs and trenchers, to provide customers with services designed to meet the technological challenges of their subsea activities worldwide. In some instances we hold intellectual property (“IP”) rights related to our business. We rely significantly on proprietary technology, processes and other information that are not subject to IP protection, as well as IP licensed from third parties. We employ confidentiality agreements to protect our IP and other proprietary information, and we have management systems in place designed to protect our legal and contractual rights. We may be subject to, among other things, theft or other misappropriation of our IP and other proprietary information, challenges to the validity or enforceability of our or our licensors’ IP rights, and breaches of confidentiality obligations. These risks are heightened by the global nature of our business, as effective protections may be limited in certain jurisdictions. Although we endeavor to identify and protect our IP and other confidential or proprietary information as appropriate, there can be no assurance that these measures will succeed. Such a failure could result in an interruption in our operations, increased competition, unplanned capital expenditures, and exposure to claims. Any such failure could have a material adverse effect on our business, competitive position, financial position, results of operations and cash flows.

Financial and Liquidity Risks

Our indebtedness and the terms of our indebtedness could impair our financial condition and our ability to fulfill our debt obligations or otherwise limit our business and financial activities.

As of December 31, 2022, we had consolidated indebtedness of $264 million. The level of indebtedness may have an adverse effect on our future operations, including:

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A prolonged period of weak economic or industry conditions and other events beyond our control may make it difficult to comply with our covenants and other restrictions in agreements governing our debt. If we fail to comply with these covenants and other restrictions, it could lead to reduced liquidity, an event of default, the possible acceleration of our repayment of outstanding debt and the exercise of certain remedies by our lenders, including foreclosure against our collateral. These conditions and events may limit our access to the credit markets if we need to replace our existing debt, which could lead to increased costs and less favorable terms, including shorter repayment schedules and higher fees and interest rates.

Because we have certain debt and other obligations, a prolonged period of low demand and rates for our services could lead to a material adverse effect on our liquidity.

A prolonged period of difficult industry conditions, the failure of our customers to expend funds on our services or a longer period of lower rates for our services, coupled with certain fixed obligations that we have related to debt repayment, long-term vessel time charter contracts and certain other commitments related to ongoing operational activities, could lead to a material adverse effect on our liquidity and financial position.

Lack of access to the financial markets could negatively impact our ability to operate our business.

Access to financing may be limited and uncertain, especially in times of economic weakness, or declining sentiment towards industries we service. If capital and credit markets are limited, we may be unable to refinance or we may incur increased costs and obtain less favorable terms associated with refinancing of our maturing debt. Also, we may incur increased costs and obtain less favorable terms associated with any additional financing that we may require for future operations. Limited access to the financial markets could adversely impact our ability to take advantage of business opportunities or react to changing economic and business conditions. Additionally, if capital and credit markets are limited, this could potentially result in our customers curtailing their capital and operating expenditure programs, which could result in a decrease in demand for our assets and a reduction in revenues and/or utilization. Certain of our customers could experience an inability to pay suppliers, including us, in the event they are unable to access financial markets as needed to fund their operations. Likewise, our other counterparties may be unable to sustain their current level of operations, fulfill their commitments and/or fund future operations and obligations, each of which could adversely affect our operations. Continued lower levels of economic activity and weakness in the financial markets could also adversely affect our ability to implement our strategic objectives.

A further decline in the offshore energy services market could result in impairment charges.

Prolonged periods of low utilization and low rates for our services could result in the recognition of impairment charges for our assets if future cash flow estimates, based on information available to us at the time, indicate that their carrying value may not be recoverable.

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Our international operations are exposed to currency devaluation and fluctuation risk.

Because we are a global company, our international operations are exposed to foreign currency exchange rate risks on all contracts denominated in foreign currencies. For some of our international contracts, a portion of the revenue and local expenses is incurred in local currencies and we may be at risk of changes in the exchange rates between the U.S. dollar and such currencies. We may receive payments in a currency that is not easily traded and may be illiquid, unable to be hedged, or subject to exchange controls that limit the currency’s ability to be converted into a more liquid currency, and we may be at risk of devaluation until such time as the currency may be able to be converted or spent. As of December 31, 2022, we had approximately $28.9 million in Nigerian Naira, which is subject to currency exchange controls established by the Central Bank of Nigeria. Those exchange controls limit our ability to convert our Nigerian Naira into U.S. dollars.

The reporting currency for our consolidated financial statements is the U.S. dollar. Certain of our assets, liabilities, revenues and expenses are denominated in other countries’ currencies. Those assets, liabilities, revenues and expenses are translated into U.S. dollars at the applicable exchange rates to prepare our consolidated financial statements. Therefore, changes in exchange rates between the U.S. dollar and those other currencies affect the value of those items as reflected in our consolidated financial statements, even if their value remains unchanged in their original currency.

Legal and Regulatory Compliance Risks

Government regulations may affect our business operations, including impeding our operations and making our operations more difficult and/or costly.

Our business is affected by changes in public policy and by federal, state, local and international laws and regulations relating to the offshore oil and gas operations. Offshore oil and gas operations are affected by tax, environmental, safety, labor, cabotage and other laws, by changes in those laws, application or interpretation of existing laws, and changes in related administrative regulations or enforcement priorities. It is also possible that these laws and regulations in the future may add significantly to our capital and operating costs or those of our customers or otherwise directly or indirectly affect our operations.

On December 20, 2019, CBP finalized a new set of rulings (the “2019 CBP Rulings”) that (i) restrict the scope of items that may be transported aboard non-coastwise qualified vessels on the OCS and (ii) establish rules regarding incidental vessel movements related to offshore lifting operations. The 2019 CBP Rulings constitute a significant step towards establishing a predictable regime of regulation for offshore operations. We are aware, however, that certain organizations are seeking to overturn the 2019 CBP Rulings, particularly with respect to offshore lifting operations. CBP, its parent agency, the Department of Homeland Security, the federal courts or the U.S. Congress could revisit the issue and, if a challenge to the 2019 CBP Rulings were successful along the lines sought by those organizations, the resulting interpretation of the Jones Act could adversely impact the operations of non-coastwise qualified vessels working in the Gulf of Mexico, and could potentially make it more difficult and/or costly to perform our offshore services in the area.

On January 1, 2021, the National Defense Authorization Act for fiscal year 2021 came into force which, among other things, extended federal law, including the Jones Act, to U.S. offshore wind farm projects, making it more difficult and/or costly to provide for U.S. renewables customers the services that we currently provide for renewables customers in the North Sea and Asia Pacific.

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Risks of substantial costs and liabilities related to environmental compliance issues are inherent in our operations. Our operations are subject to extensive federal, state, local and international laws and regulations relating to the generation, storage, handling, emission, transportation and discharge of materials into the environment. Permits are required for the operations of various facilities, including vessels, and those permits are subject to revocation, modification and renewal. Governmental authorities have the power to enforce compliance with their regulations, and violations are subject to fines, injunctions or both. In some cases, those governmental requirements can impose liability for the entire cost of cleanup on any responsible party without regard to negligence or fault and impose liability on us for the conduct of others or conditions others have caused, or for our acts that complied with all applicable requirements when we performed them. It is possible that other developments, such as stricter environmental laws and regulations, and claims for damages to property or persons resulting from our operations, would result in substantial costs and liabilities. Our insurance policies and the contractual indemnity protections we seek to obtain from our counterparties, assuming they are obtained, may not be sufficient or effective to protect us under all circumstances or against all risk involving compliance with environmental laws and regulations.

As a multi-national organization, we are subject to taxation in multiple jurisdictions. The Organization for Economic Co-operation and Development, the EU and individual taxing jurisdictions are focused on tax base erosion and profit shifting as well as minimum tax directives. These initiatives and directives continue to evolve with country specific implementation legislation forthcoming. Additionally, we anticipate increased disclosure and information reporting to facilitate compliance with these rules and initiatives when enacted. While the impact of these proposed and future rules cannot be determined, they may have adverse effects on us, including increased administrative and compliance costs.

Our business would be adversely affected if we failed to comply with the Jones Act foreign ownership provisions or if these provisions were modified or repealed.

We are subject to the Jones Act and other federal laws that restrict maritime cargo transportation between points in the U.S. As a result of the Alliance acquisition, we acquired 21 vessels registered under the U.S. flag which operate in the U.S. Gulf of Mexico coastwise trade. In order to operate vessels in the Jones Act trade and to be qualified to document vessels for coastwise trade, we must maintain U.S. citizen status for Jones Act purposes. We could cease being a U.S. citizen if certain events were to occur, including if non-U.S. citizens were to own 25% or more of our common stock. We are responsible for monitoring our ownership to ensure compliance with the Jones Act. The consequences of our failure to comply with the Jones Act provisions on coastwise trade, including failing to qualify as a U.S. citizen, would have an adverse effect on our results of operations as we may be prohibited from operating certain of our vessels in the U.S. coastwise trade or, under certain circumstances, permanently lose U.S. coastwise trading rights or be subject to fines or forfeiture of certain our vessels. There have been attempts to repeal or amend restrictions contained in the Jones Act, and such attempts are expected to continue in the future. Our business could be adversely affected if the Jones Act were to be modified or repealed so as to permit foreign competition that is not subject to the same U.S. government imposed burdens.

Enhanced regulations for deepwater offshore drilling may reduce the need for our services.

Exploration and development activities and the production and sale of oil and natural gas are subject to extensive federal, state, local and international regulations. To conduct deepwater drilling in the Gulf of Mexico, an operator is required to comply with existing and newly developed regulations and enhanced safety standards. Before drilling may commence, BSEE conducts many inspections of deepwater drilling operations for compliance with its regulations. Operators also are required to comply with Safety and Environmental Management System (“SEMS”) regulations within the deadlines specified by the regulations and confirm that their contractors have SEMS-compliant safety and environmental policies and procedures in place. Additionally, each operator must demonstrate that it has containment resources that are available promptly in the event of a loss of well control. It is expected that government authorities, including BOEM and BSEE, will continue to issue further regulations regarding deepwater offshore drilling. Our business, a significant portion of which is in the Gulf of Mexico, provides development services to newly drilled wells, and therefore relies heavily on the industry’s drilling of new oil and gas wells. If the issuance of drilling or other permits is significantly delayed, or if other oil and gas operations are delayed or reduced due to increased costs of complying with regulations, demand for our services may also decline. Moreover, if our assets are not redeployed such that we can provide our services at profitable rates, our business, financial condition, results of operations and cash flows would be materially adversely affected.

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In January 2021, the U.S. Department of the Interior issued Order No. 3395, “Temporary Suspension of Delegated Authority” (“Order 3395”), suspending the authority of the Department of Interior’s Bureaus and Offices to, among other things, issue any fossil fuel authorization including a lease, contract, or other agreement or drilling permit, and thereafter President Biden signed Executive Order 14008 (“EO 14008” and together with Order 3395, the “Orders”) which, among other things, established a moratorium on new oil and gas leasing of public lands and offshore waters pending the completion of a comprehensive review and reconsideration of federal oil and gas permitting and lease practices. While certain portions of the Orders have subsequently been challenged in the court system and the ultimate interpretation and enforcement of the Orders remains uncertain at this time, they appear reflective of a broader regulatory agenda that may pose additional challenges for the industries we serve. The Orders and other similar regulation may directly impede our operations or ability to service our customers’ needs. Such regulations could also result in offshore drilling rigs being diverted to well intervention work, which may create more competition for the services we offer. Such regulations may also affect oil and gas prices, which could impact the demand for our services. Such impediments, competition or reduction in activity could have a material adverse effect on our operations, competitive position, results of operations and cash flows.

We cannot predict with any certainty the substance or effect of any new or additional regulations in the U.S. or in other areas around the world. If the U.S. or other countries where our customers operate enact stricter restrictions on offshore drilling or further regulate offshore drilling, and this results in decreased demand for or profitability of our services, our business, financial position, results of operations and cash flows could be materially adversely affected.

Failure to comply with anti-bribery laws could have a material adverse impact on our business.

The U.S. Foreign Corrupt Practices Act and similar anti-bribery laws in other jurisdictions, including the United Kingdom Bribery Act 2010 and Brazil’s Clean Company Act, generally prohibit companies and their intermediaries from making improper payments to foreign officials for the purpose of obtaining or retaining business. We operate in many parts of the world that have experienced corruption to some degree. We have a robust ethics and compliance program that is designed to deter or detect violations of applicable laws and regulations through the application of our anti-corruption policies and procedures, Code of Business Conduct and Ethics, training, internal controls, investigation and remediation activities, and other measures. However, our ethics and compliance program may not be fully effective in preventing all employees, contractors or intermediaries from violating or circumventing our compliance requirements or applicable laws and regulations. Failure to comply with anti-bribery laws could subject us to civil and criminal penalties, and such failure, and in some instances even the mere allegation of such a failure, could create termination or other rights in connection with our existing contracts, negatively impact our ability to obtain future work, or lead to other sanctions, all of which could have a material adverse effect on our business, financial position, results of operations and cash flows, and cause reputational damage. We could also face fines, sanctions and other penalties from authorities, including prohibition of our participating in or curtailment of business operations in certain jurisdictions and the seizure of vessels or other assets. Further, we may have competitors who are not subject to the same laws, which may provide them with a competitive advantage over us in securing business or gaining other preferential treatment.

General Risks

The loss of the services of one or more of our key employees, or our failure to attract and retain other highly qualified personnel and other skilled workers in the future, could disrupt our operations and adversely affect our financial results.

Our industry has lost a significant number of experienced professionals over the years due to its cyclical nature, including recently in connection with industry downturn, the effects of the COVID-19 pandemic, and a decline in sentiment towards fossil fuels. Our success depends on the active participation of our key employees. The loss of our key people could adversely affect our operations. The delivery of our services also requires personnel with specialized skills, qualifications and experience. The demand for skilled workers can be high and the supply may be limited. A significant increase in the wages paid by competing employers could result in a reduction of our skilled labor force, increases to our cost structures, or both. As a result, our ability to remain productive and profitable will depend upon our ability to employ and retain skilled, qualified and experienced workers, and we may have competition for personnel with the requisite skill set.

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Cybersecurity breaches or business system disruptions may adversely affect our business.

We rely on our information technology infrastructure and management information systems to operate and record almost every aspect of our business. This may include confidential or personal information belonging to us, our employees, customers, suppliers, or others. Similar to other companies, our systems and networks, and those of third parties with whom we do business, may be subject to cybersecurity breaches caused by, among other things, illegal hacking, insider threats, computer viruses, phishing, malware, ransomware, or acts of vandalism or terrorism, or those perpetrated by criminals or nation-state actors. Furthermore, we may also experience increased cybersecurity risk as some of our onshore personnel may periodically work remotely.

In addition to our own systems and networks, we use third-party service providers to process certain data or information on our behalf. Due to applicable laws and regulations, we may be held responsible for cybersecurity incidents attributed to our service providers to the extent it relates to information we share with them. Although we seek to require that these service providers implement and maintain reasonable security measures, we cannot control third parties and cannot guarantee that a security breach will not occur in their systems or networks.

Despite our efforts to continually refine our procedures, educate our employees, and implement tools and security measures to protect against such cybersecurity risks, there can be no assurance that these measures will prevent unauthorized access or detect every type of attempt or attack. Our potential future upgrades, refinements, tools and measures may not be completely effective or result in the anticipated improvements, if at all, and may cause disruptions in our business operations. In addition, a cyberattack or security breach could go undetected for an extended period of time, and the ensuing investigation of the incident would take time to complete. During that period, we would not necessarily know the impact to our systems or networks, costs and actions required to fully remediate and our initial remediation efforts may not be successful, and the errors or actions could be repeated before they are fully contained and remediated. A breach or failure of our systems or networks, critical third-party systems on which we rely, or those of our customers or vendors, could result in an interruption in our operations, disruption to certain systems that are used to operate our vessels or other assets, unplanned capital expenditures, unauthorized publication of our confidential business or proprietary information, unauthorized release of customer, employee or third party data, theft or misappropriation of funds, violation of privacy or other laws, and exposure to litigation or indemnity claims including resulting from customer-imposed cybersecurity controls or other related contractual obligations. There could also be increased costs to detect, prevent, respond, or recover from cybersecurity incidents. Any such breach, or our delay or failure to make adequate or timely disclosures to the public, regulatory or law enforcement agencies or affected individuals following such an event, could have a material adverse effect on our business, reputation, financial position, results of operations and cash flows, and cause reputational damage.

We may execute a strategic transaction that may not achieve intended results, could increase our debt or the number of our shares outstanding, or result in a change of control.

We have executed acquisitions and divestitures in the past, and in the future we may evaluate and potentially enter into additional strategic transactions. Any such transaction could be material to our business, could occur at any time and could take any number of forms, including, for example, an acquisition, merger, joint venture, strategic alliance, equity investment, divestiture or an asset sale.

The success of any transaction may depend on, in part, our ability to integrate an acquired business and realize the financial growth or synergies expected from the transaction. Any such transaction may not be successful, may not be accretive to shareholders or may not achieve expected benefits within an expected timeframe. Acquired businesses may also have unanticipated liabilities, contingencies or negative tax consequences. In addition, acquisitions are accompanied by the risk that the obligations of an acquired business may not be adequately reflected in the historical financial statements of that company and the risk that those historical financial statements may be based on assumptions which are incorrect or inconsistent with our assumptions or approach to accounting policies. Any of these material obligations, unanticipated liabilities or incorrect or inconsistent assumptions could have a material adverse effect on our growth strategy, business, financial condition, prospects and results of operations. Furthermore, evaluating potential transactions and integrating completed transactions could be time-consuming, involve significant transaction related expenses, create unexpected costs, involve difficulties assimilating the operations and personnel of an acquired business, make evaluating our business and future financial prospects difficult and may divert the attention of our management from ordinary operating matters.

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Any such transaction may require additional financing that could result in an increase in the number of our outstanding shares or the aggregate amount of our debt, and the number of shares of our common stock or the aggregate principal amount of our debt that we may issue may be significant. Certain transactions may not be permitted under our existing asset-based credit facility, requiring either waivers, amendments, or terminating such facility. Furthermore, a strategic transaction may result in a change in control of our company or otherwise materially and adversely affect our business.

Our ability to repurchase shares through any share repurchase program is subject to certain considerations, including availability of free cash flow, and any repurchases could affect the price of our common stock and increase volatility, which may result in a decrease in the trading price of our common stock.

Our Board has in the past and may from time to time in the future authorize share repurchase programs. On February 20, 2023, we announced that our Board approved a new share repurchase program authorizing the repurchase of up to $200 million issued and outstanding shares of our common stock. The timing and amount of repurchases, if any, under such program would depend upon several factors. Our ability to successfully effect a share repurchase program requires us to generate consistent Free Cash Flow and have available capital in the years ahead in amounts sufficient to enable us to also continue to fund our working capital requirements, capital expenditures, acquisitions, investments, debt service requirements and other general corporate requirements. Our cash flow typically fluctuates seasonally and the amount of Free Cash Flow returned in any quarter during the year may vary. We may not have available Free Cash Flow to repurchase shares if we use our available cash to satisfy other priorities such as strategic opportunities and acquisitions, or if our Board determines to change or discontinue the repurchase program. There is no guarantee that we would carry out repurchases in the same manner as they may have been announced. Furthermore, a share repurchase program could diminish our cash reserves, which may impact our ability to finance future growth or engage in alternative activities that could generate greater shareholder value. In addition, repurchases of our common stock pursuant to a share repurchase program could cause our stock price to be higher than it would be in the absence of such a program and could potentially reduce the market liquidity for our stock. Although share repurchase programs are intended to enhance long-term shareholder value, there is no assurance that it will do so. Any failure to repurchase our common stock after we have announced our intention to do so may negatively impact our stock price and short-term stock price fluctuations could reduce the program’s effectiveness.

Certain provisions of our corporate documents, financial arrangements and Minnesota law may discourage a third party from making a takeover proposal.

We are authorized to establish, without any action by our shareholders, the rights and preferences on up to 5,000,000 shares of preferred stock, including dividend, liquidation and voting rights. In addition, our by-laws divide our Board into three classes. We are also subject to certain anti-takeover provisions of the Minnesota Business Corporation Act. We have employment arrangements with all of our executive officers that could require cash payments, terms in our convertible senior notes that could increase the applicable conversion rate and covenants in our asset-based credit agreement (the “ABL Facility”) that could put us in breach, in the event of a “change of control.” Any or all of these provisions or factors may discourage a takeover proposal or tender offer not approved by management and our Board and could result in shareholders who may wish to participate in such a proposal or tender offer receiving less in return for their shares than otherwise might be available in the event of a takeover attempt.

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Item 1B. Unresolved Staff Comments

None.

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Item 2. Properties

VESSELS AND OTHER OPERATING ASSETS

As of December 31, 2022, our fleet included 27 owned vessels, eight IRSs, three SILs, the ROAM, 15 marketable P&A systems (with the ability to scale up to 20 systems), six coiled tubing systems, 41 ROVs, seven trenchers and the IROV boulder grab. We also had six vessels under time charter agreements. All of our chartered vessels and 11 of our owned vessels have DP capabilities specifically designed to meet the needs of our customers’ offshore activities. Our Seawell and Well Enhancer vessels also have built-in saturation diving systems.

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Listing of Vessels and Other Assets Related to Operations as of December 31, 2022 ⁽¹⁾

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We incur routine dry dock, inspection, maintenance and repair costs pursuant to applicable statutory regulations in order to maintain our vessels in accordance with the rules of the applicable class society. In addition to complying with these requirements, we have our own asset maintenance programs that we believe permit us to continue to provide our customers with well-maintained, reliable assets.

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FACILITIES

Our corporate headquarters are located at 3505 West Sam Houston Parkway North, Suite 400, Houston, Texas 77043. Except for one owned property related to Helix Alliance, we currently lease all of our facilities, which are primarily located in Texas, Louisiana, Scotland, Singapore and Brazil.

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Item 3. Legal Proceedings

The information required to be set forth under this heading is incorporated by reference from Note 16 to our consolidated financial statements included in Item 8. Financial Statements and Supplementary Data of this Annual Report.

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Item 4. Mine Safety Disclosures

Not applicable.

Information about our Executive Officers

Our executive officers are as follows:

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Owen Kratz is President and Chief Executive Officer of Helix. He was named Executive Chairman in October 2006 and served in that capacity until February 2008 when he resumed the position of President and Chief Executive Officer. He served as Helix’s Chief Executive Officer from April 1997 until October 2006. Mr. Kratz served as President from 1993 until February 1999, and has served as a Director since 1990 (including as Chairman of our Board from May 1998 to July 2017). He served as Chief Operating Officer from 1990 through 1997. Mr. Kratz joined Cal Dive International, Inc. (now known as Helix) in 1984 and held various offshore positions, including saturation diving supervisor, and management responsibility for client relations, marketing and estimating. From 1982 to 1983, Mr. Kratz was the owner of an independent marine construction company operating in the Bay of Campeche. Prior to 1982, he was a superintendent for Santa Fe and various international diving companies, and a diver in the North Sea. From February 2006 to December 2011, Mr. Kratz was a member of the Board of Directors of Cal Dive International, Inc., a once publicly traded company, which was formerly a subsidiary of Helix. Mr. Kratz has a Bachelor of Science degree from State University of New York.

Erik Staffeldt is Executive Vice President and Chief Financial Officer of Helix. Prior thereto he was Senior Vice President and Chief Financial Officer beginning in June 2017 until February 2019. Mr. Staffeldt oversees Helix’s finance, treasury, accounting, tax, information technology and corporate planning functions. Since joining Helix in July 2009 as Assistant Corporate Controller, Mr. Staffeldt has served as Director — Corporate Accounting from August 2011 until March 2013, Director of Finance from March 2013 until February 2014, Finance and Treasury Director from February 2014 until July 2015, and Vice President — Finance and Accounting from July 2015 until June 2017. Mr. Staffeldt was also designated as Helix’s “principal accounting officer” for purposes of the Securities Act, the Exchange Act and the rules and regulations promulgated thereunder in July 2015 until December 2021. Mr. Staffeldt served in various financial and accounting capacities prior to joining Helix and has over 27 years of experience in the energy industry. Mr. Staffeldt is a graduate of the University of Notre Dame with a BBA in Accounting and Loyola University in New Orleans with an MBA, and is a Certified Public Accountant.

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Scott A. (“Scotty”) Sparks is Executive Vice President and Chief Operating Officer of Helix, having joined Helix in 2001. He served as Executive Vice President — Operations of Helix from May 2015 until February 2016. From October 2012 until May 2015, he was Vice President — Commercial and Strategic Development of Helix. He has also served in various positions within Helix Robotics Solutions, Inc. (formerly known as Canyon Offshore, Inc.), including as Senior Vice President from 2007 to September 2012. Mr. Sparks has over 32 years of experience in the subsea industry, including as Operations Manager and Vessel Superintendent at Global Marine Systems and BT Marine Systems.

Kenneth E. (“Ken”) Neikirk is Executive Vice President, General Counsel and Corporate Secretary of Helix. Mr. Neikirk has over 22 years of experience practicing law in the corporate and energy sectors, and has been a member of Helix’s legal department since 2007, previously serving as Helix’s Senior Vice President, General Counsel and Corporate Secretary from May 2019 to December 2022, and prior to that as Corporate Counsel, Compliance Officer and Assistant Secretary from February 2016 until April 2019. Mr. Neikirk oversees Helix’s legal, human resources, and contracts and insurance functions. Prior to joining Helix Mr. Neikirk was in private practice in New York and Houston. Mr. Neikirk holds a Bachelor of Arts degree from Duke University and a Juris Doctor from the University of Houston Law Center.

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PART II

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

Our common stock is traded on the New York Stock Exchange (“NYSE”) under the symbol “HLX.” On February 17, 2023, the closing sale price of our common stock on the NYSE was $7.62 per share. As of February 17, 2023, there were 280 registered shareholders and approximately 75,590 beneficial shareholders of our common stock.

We have not declared or paid cash dividends on our common stock in the past nor do we intend to pay cash dividends in the foreseeable future. In addition, our financing arrangements may place certain limitations on the payment of cash dividends on our common stock. We currently intend to reinvest any retained earnings, if any, for the future operation and growth of our business, or to use for potential acquisition opportunities or share repurchases. Our Board will review this matter on a regular basis in light of our earnings, financial position and market opportunities. See Management’s Discussion and Analysis of Financial Condition and Results of Operations “— Liquidity and Capital Resources.”

Shareholder Return Performance Graph

The following graph compares the cumulative total shareholder return on our common stock for the period since December 31, 2017 to the cumulative total shareholder return for (i) the stocks of 500 large-cap corporations maintained by Standard & Poor’s (“S&P 500”), assuming the reinvestment of dividends; (ii) the Philadelphia Oil Service Sector index (the “OSX”), a price-weighted index of leading oil service companies, assuming the reinvestment of dividends; and (iii) a peer group selected by us as of January 2022 (the “2022 Performance Peer Group”) including the following companies: Archrock, Inc., ChampionX Corporation, Core Laboratories N.V., Dril-Quip, Inc., Forum Energy Technologies, Inc., Helmerich & Payne, Inc., Nabors Industries Ltd., Newpark Resources, Inc., NexTier Oilfield Solutions Inc., Oceaneering International, Inc., Oil States International, Inc., Patterson-UTI Energy, Inc., ProPetro Holding Corp., RPC, Inc., Select Energy Services, Inc., TETRA Technologies, Inc., Tidewater Inc., Transocean Ltd. and USA Compression Partners, LP. The returns of each member of the 2022 Performance Peer Group have been weighted according to each individual company’s equity market capitalization as of December 31, 2022 and have been adjusted for the reinvestment of any dividends. We believe that in 2022 the members of the 2022 Performance Peer Group provided services and products more comparable to us than those companies included in the OSX. The graph assumes $100 was invested on December 31, 2017 in our common stock at the closing price on that date price and on December 31, 2017 in the three indices presented. We paid no cash dividends during the period presented. The cumulative total percentage returns for the period presented are as follows: our stock — (2.1)%; the 2022 Performance Peer Group — (41.4)%; the OSX — (38.5)%; and S&P 500 — 56.9%. These results are not necessarily indicative of future performance.

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Comparison of Five Year Cumulative Total Return among Helix, S&P 500,

OSX and Peer Group

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Source: Bloomberg

Issuer Purchases of Equity Securities

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Item 6. [Reserved]

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

The following management’s discussion and analysis should be read in conjunction with our historical consolidated financial statements located in Item 8. Financial Statements and Supplementary Data of this Annual Report. Any reference to Notes in the following management’s discussion and analysis refers to the Notes to Consolidated Financial Statements located in Item 8. Financial Statements and Supplementary Data of this Annual Report. The results of operations reported and summarized below are not necessarily indicative of future operating results. This discussion also contains forward-looking statements that reflect our current views with respect to future events and financial performance. Our actual results may differ materially from those anticipated in these forward-looking statements as a result of certain factors, such as those set forth under Item 1A. Risk Factors and located earlier in this Annual Report.

EXECUTIVE SUMMARY

Our Business

We are an international offshore energy services company that provides specialty services to the offshore energy industry, with a focus on well intervention, robotics and full-field decommissioning operations. Our services are centered on a three-legged business model well positioned for a global energy transition by maximizing production of remaining oil and gas reserves, supporting renewable energy developments and decommissioning end-of-life oil and gas fields. Our well intervention fleet includes seven purpose-built well intervention vessels and 12 intervention systems. Our robotics equipment includes 41 work-class ROVs, seven trenchers and the IROV boulder grab. We charter robotics support vessels on long-term, short-term, flexible and spot bases to facilitate our ROV and trenching operations. Our Production Facilities segment includes the HP I, the HFRS and our ownership of oil and gas properties including the recently acquired interest in the Thunder Hawk Field. On July 1, 2022, we completed our acquisition of Alliance and formed a new reporting segment in the third quarter 2022 comprised of the Helix Alliance business. Our new Shallow Water Abandonment segment includes 10 liftboats, six OSVs, three DSVs, one 1760T heavy lift derrick barge, one crew boat, 15 marketable P&A systems (with the ability to scale up to 20 systems) and six coiled tubing systems.

Economic Outlook and Industry Influences

Demand for our services is primarily influenced by the condition of the oil and gas and the renewable energy markets and, in particular, the willingness of offshore energy companies to spend on operational activities and capital projects. The performance of our business is largely affected by the prevailing market prices for oil and natural gas, which are impacted by domestic and global economic conditions, hydrocarbon production and capacity, geopolitical issues, weather, global health, and various other factors, including:

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Oil and gas prices reached ten-year highs during the middle of 2022 and experienced moderate declines and volatility during the remainder of 2022. Global demand for oil and gas continues to recover as supply has been disrupted by regional conflicts. We expect oil and gas prices will remain robust for the near term, which should lead to higher customer spending for the industry. However, despite the current strong commodity price environment, there remain headwinds to commodity price stability, including those regional conflicts, high inflation and in particular governments’ and central banks’ efforts to taper economic growth, COVID-related uncertainties, various governmental and customer ESG initiatives and continued shifting of resource allocation to renewable energy. We expect these factors will continue to contribute to commodity price volatility and may temper customer spending for oil and gas projects.

We maximize production of remaining oil and gas reserves for our customers primarily in our Well Intervention segment. Historically, drilling rigs have been the asset class used for offshore well intervention work, and rig day rates are a pricing indicator for our services. Our customers have used drilling rigs on existing long-term contracts (rig overhang) to perform well intervention work instead of new drilling activities. Current volumes of work, rig utilization rates, the day rates quoted by drilling rig contractors and existing rig overhang affect the utilization and/or rates we can achieve for our assets and services.

Over the near-term, with the current high commodity price environment we expect oil and gas companies to invest in new long-cycle exploration projects in addition to maintaining and/or increasing production from their remaining reserves. As historically production enhancement through well intervention is less expensive per incremental barrel of oil than exploration, we continue to expect oil and gas companies to increasingly focus on optimizing production of their existing subsea wells. We expect the fundamentals for our business will remain favorable over the longer term as the need to prolong well life in oil and gas production is the primary driver of demand for our production enhancement services. This expectation is based on multiple factors, including (1) maintaining the optimal production of a well through enhancement is fundamental to maximizing the overall economics of well production; (2) our services offer commercially viable alternatives for reducing the finding and development costs of reserves as compared to new drilling; and (3) extending the production of offshore wells not only maximizes a well’s production economics but also enables the financial benefit of delaying P&A costs, which can be substantial.

We support the energy transition to renewables through our services in offshore wind farm developments, primarily including subsea cable trenching and burial as well as seabed clearance and preparation services. Demand for our services in the renewable energy market is affected by various factors, including the pace of consumer shift towards renewable energy sources, global electricity demand, technological advancements that increase the production and/or reduce the cost of renewable energy, expansion of offshore renewable energy projects to deeper water, and government subsidies for renewable energy projects. We expect growth in our renewables services as the energy market transitions to continued renewable energy developments.

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Once end-of-life oil and gas wells have depleted their production, we decommission wells and infrastructure in our Well Intervention and Shallow Water Abandonment segments. As the subsea tree base expands and ages and customers shift resources to renewable energy, the demand for P&A services should persist. Our operations service the life cycle of an oil and gas field and provide P&A services at the end of the life of a field as required by governmental regulations, and we believe that we have a competitive advantage in performing these services efficiently.

We are subject to the effects of changing prices. Inflation rates have been relatively low and stable over the previous three decades; however, inflation rates have risen significantly since 2021 due in part to supply chain disruptions and the effects of the COVID-19 pandemic. Although we may be able to mitigate our exposure to price increases through the rates we charge, we bear the costs of operating and maintaining our assets, including labor and material costs as well as recertification and dry dock costs. While the cost outlook is not certain, we believe that we can manage these inflationary pressures by introducing appropriate sales price adjustments and by actively pursuing internal cost management efforts. However, competitive market pressures may affect our ability to recoup these price increases through the rates we charge, which may result in reductions in our operating margins and cash flows in the future. The recent high inflation rates seen in various major economies have caused concerns for central banks’ tightening of monetary policies. These concerns have contributed to stock market volatility as well as higher interest rates, which, combined with ongoing regional conflicts and unrest and continued COVID-related disruptions throughout the globe, could provide a strained macroeconomic outlook and in turn affect energy markets.

The COVID-19 pandemic resulted in new market dynamics and challenges to us, including contributing significantly to oil and gas price volatility and increased costs related to our supply chain, logistics and human capital resources. While the COVID-19 pandemic has significantly receded since its peak, the full impact of the COVID-19 pandemic, including the duration of its impact on economic activity, remains unknown, we expect such impact could escalate in the future, including affecting our customers’ willingness to commit to future spending, limiting access to and use of capital, disrupting supply chains and increasing costs, and negatively affecting human capital resources.

Business Activity Summary

As the oil and gas market has improved due to the post-COVID-19 recovery and the impact of sovereign energy security and independence, and as the energy market continues its migration of energy transition towards renewables, we executed a number of transactions during 2022 that demonstrate our commitment to our strategy and outlook for the markets we serve.

In February 2022, we entered into a two-year P&A contract with Trident for the Siem Helix 1, which commenced in December 2022. In September 2022, our contract with Petrobras for the Siem Helix 2 was extended for two years until December 2024. In October 2022, we entered into an intervention and decommissioning contract with Shell Brasil Petroleo LTDA for the Q7000, which is scheduled to commence in 2024. In November 2022, we extended the agreement for the HP 1 for one year until at least June 1, 2024.

In January 2022, we executed a time charter agreement for the Horizon Enabler in the North Sea with minimum firm periods in 2022 and 2023. In February 2022, we executed a time charter agreement for the Shelia Bordelon in the Gulf of Mexico until June 2024. In February 2022, the charter agreements for the Siem Helix 1 and the Siem Helix 2 were extended to February 2025 and February 2027, respectively. In August 2022, the time charter agreements for the Grand Canyon II and Grand Canyon III vessels were extended to December 2027 and May 2028, respectively.

In July 2022, we completed the acquisition of Alliance, expanding our services to the shallow waters predominantly in the Gulf of Mexico shelf.

In August 2022, we acquired from MP GOM a 62.5% interest in the Thunder Hawk Field, which is comprised of mature wells located in the Gulf of Mexico.

In December 2022, we acquired a 50% interest in two deepwater IRSs that can be used on our vessels, serve as backups, or be deployed on a stand-alone basis to our customers around the world.

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We have continued to expand our services and offerings into the offshore renewable energy sector. During 2022, we performed site clearance and/or ROV support work on multiple renewable energy projects in the Asia Pacific and North Sea regions and offshore U.S. East Coast. In November 2022, we acquired two jet trenchers and one plough trencher, which will enable us to expand our renewables trenching services into new markets.

Backlog

We define backlog as firm commitments represented by signed contracts. As of December 31, 2022, our consolidated backlog totaled $847 million, of which $533 million is expected to be performed in 2023. As of December 31, 2022, our contracts with Shell in the Gulf of Mexico, U.K. and Brazil, our contracts with Trident and Petrobras in Brazil and our agreement for the HP I in the Gulf of Mexico represented approximately 69% of our total backlog. As of December 31, 2021, our consolidated backlog totaled $348 million. Backlog is not necessarily a reliable indicator of revenues derived from our contracts as services are often added but may sometimes be subtracted; contracts may be renegotiated, deferred, canceled and in many cases modified while in progress; and reduced rates, fines and penalties may be imposed by our customers. Furthermore, our contracts are in certain cases cancelable without penalty. If there are cancellation fees, the amount of those fees can be substantially less than amounts reflected in backlog.

RESULTS OF OPERATIONS

Non-GAAP Financial Measures

A non-GAAP financial measure is generally defined by the SEC as a numerical measure of a company’s historical or future performance, financial position or cash flows that includes or excludes amounts from the most directly comparable measure under U.S. generally accepted accounting principles (“GAAP”). Non-GAAP financial measures should be viewed in addition to, and not as an alternative to, our reported results prepared in accordance with GAAP. Users of this financial information should consider the types of events and transactions that are excluded from these measures.

We measure our operating performance based on EBITDA, Adjusted EBITDA, Free Cash Flow and Net Debt. EBITDA, Adjusted EBITDA, Free Cash Flow and Net Debt are non-GAAP financial measures that are commonly used but are not recognized accounting terms under GAAP. We use EBITDA, Adjusted EBITDA, Free Cash Flow and Net Debt to monitor and facilitate internal evaluation of the performance of our business operations, to facilitate external comparison of our business results to those of others in our industry, to analyze and evaluate financial and strategic planning decisions regarding future investments and acquisitions, to plan and evaluate operating budgets, and in certain cases, to report our results to the holders of our debt as required by our debt covenants. We believe that our measures of EBITDA, Adjusted EBITDA, Free Cash Flow and Net Debt provide useful information to the public regarding our operating performance and ability to service debt and fund capital expenditures and may help our investors understand and compare our results to other companies that have different financing, capital and tax structures. Other companies may calculate their measures of EBITDA, Adjusted EBITDA, Free Cash Flow and Net Debt differently from the way we do, which may limit their usefulness as comparative measures. EBITDA, Adjusted EBITDA, Free Cash Flow and Net Debt should not be considered in isolation or as a substitute for, but instead are supplemental to, income from operations, net income, cash flows from operating activities, or other income or cash flow data prepared in accordance with GAAP.

We define EBITDA as earnings before income taxes, net interest expense, gain or loss on extinguishment of long-term debt, net other income or expense, and depreciation and amortization expense. Non-cash impairment losses on goodwill and other long-lived assets and non-cash gains and losses on equity investments are also added back if applicable. To arrive at our measure of Adjusted EBITDA, we exclude the gain or loss on disposition of assets, acquisition and integration costs, the change in fair value of contingent consideration and the general provision (release) for current expected credit losses, if any. In addition, we include realized losses from foreign currency exchange contracts not designated as hedging instruments, which are excluded from EBITDA as a component of net other income or expense. We define Free Cash Flow as cash flows from operating activities less capital expenditures, net of proceeds from sale of assets. Net Debt is calculated as long-term debt including current maturities of long-term debt less cash and cash equivalents and restricted cash. In the following reconciliation, we provide amounts as reflected in the condensed consolidated financial statements unless otherwise noted.

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The reconciliation of our net income (loss) to EBITDA and Adjusted EBITDA is as follows (in thousands):

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The reconciliation of our cash flows from operating activities to Free Cash Flow is as follows (in thousands):

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The reconciliation of our long-term debt to Net Debt is as follows (in thousands):

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Comparison of Years Ended December 31, 2022 and 2021

We have four reportable business segments: Well Intervention, Robotics, Shallow Water Abandonment and Production Facilities. All material intercompany transactions between the segments have been eliminated in our condensed consolidated financial statements, including our condensed consolidated results of operations. The following table details various financial and operational highlights for the periods presented (dollars in thousands):

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Intercompany segment amounts are derived primarily from equipment and services provided to other business segments. Intercompany segment revenues are as follows (in thousands):

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Net Revenues. Our consolidated net revenues increased by 29% in 2022 as compared to 2021, reflecting the addition of Shallow Water Abandonment segment in the third quarter 2022 and higher revenues from all of our segments.

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Our Well Intervention revenues increased by 1% in 2022 as compared to 2021, primarily reflecting higher vessel utilization and rates in the Gulf of Mexico and the North Sea as well as higher utilization on the Siem Helix 1 during 2022, offset in part by lower utilization on the Q7000 due to its scheduled maintenance during 2022, lower rates on the Siem Helix 1 and the Siem Helix 2 as they transitioned from their legacy contracts with Petrobras, and a weaker British pound during 2022 as compared to 2021. Overall Well Intervention vessel utilization increased to 80% in 2022 as compared to 67% in 2021.

Our Robotics revenues increased by 40% in 2022 as compared to 2021, primarily reflecting higher vessel, trenching and ROV activities. Chartered vessel days increased to 1,401 days, which included 420 spot vessel days, in 2022 as compared to 1,178 days, which included 477 spot vessel days, in 2021. Trenching days increased to 483 days during 2022 as compared to 336 days during 2021. Overall ROV and trencher utilization increased to 53% during 2022 from 36% during 2021.

Our Shallow Water Abandonment revenues in 2022 reflected revenues generated by Helix Alliance since the acquisition on July 1, 2022 (Note 3). The Epic Hedron heavy lift barge was 21% utilized, utilization of other Helix Alliance vessels was 76%, and utilization across marketable P&A and coiled tubing systems was 2,324 days, or 62%.

Our Production Facilities revenues increased by 19% in 2022 as compared to 2021, primarily reflecting higher oil and gas prices and improved rates related to the HFRS, offset in part by lower oil and gas production volumes in 2022. Revenues also benefitted from retroactive rate adjustment on our production contract with the HP I.

Gross Profit (Loss). Our consolidated 2022 gross profit increased by $35.2 million as compared to 2021, primarily reflecting increased profitability in our Robotics and Production Facilities segments and the addition of Shallow Water Abandonment segment in the third quarter 2022, offset in part by decreased profitability in our Well Intervention segment.

Our Well Intervention segment had a gross loss of $40.1 million in 2022 as compared to a gross loss of $21.3 million in 2021, primarily reflecting our mix of contracting year over year, with our lower rates in Brazil generating higher losses, offset in part by increased Gulf of Mexico and North Sea revenues generating lower incremental margins driven by an increase in integrated projects and reimbursable revenues during 2022.

Our Robotics gross profit increased by $24.1 million in 2022 as compared to 2021, primarily reflecting higher revenues due to increased trenching and ROV activities and a higher number of vessel days.

Our Shallow Water Abandonment gross profit in 2022 reflected results from Helix Alliance since the acquisition on July 1, 2022.

Our Production Facilities gross profit increased by $5.6 million in 2022 as compared to 2021, primarily reflecting increases in revenues, offset in part by higher costs during 2022.

Acquisition and Integration Costs. Our acquisition and integration costs of $2.7 million reflected Alliance acquisition related costs incurred during 2022 (Note 3).

Change in Fair Value of Contingent Consideration. The $16.1 million change in fair value of contingent consideration reflected an increase in the estimated earn-out payable in 2024 to the seller in the Alliance transaction as Helix Alliance’s 2022 results following the acquisition date and its expected 2023 results have both improved as compared to forecasts and information available at the time of acquisition (Notes 3 and 19).

Selling, General and Administrative Expenses. Our selling, general and administrative expenses were $76.8 million in 2022 as compared to $63.4 million in 2021, primarily reflecting higher employee incentive and share-based compensation costs as well as increased general and administrative expenses related to Helix Alliance.

Equity in Earnings of Investment. Equity in earnings of investment of $8.3 million primarily reflected the cash distribution as a result of the sale of the “Independence Hub” platform in 2022 (Note 2).

Net Interest Expense. Our net interest expense totaled $19.0 million in 2022 as compared to $23.2 million in 2021, primarily reflecting lower funded debt, which decreased by $42.9 million during 2022, and lower fees associated with our credit facility as compared to 2021 (Note 7).

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Other Income (Expense), Net. Net other expense was $23.3 million in 2022 as compared to $1.5 million in 2021, primarily reflecting higher foreign currency losses due to weakening of the British pound in 2022.

Income Tax Provision (Benefit). Income tax provision was $12.6 million for 2022 as compared to income tax benefit of $9.0 million for 2021. The effective tax rates for 2022 and 2021 were (16.8)% and 12.7%, respectively. These variances were primarily attributable to the earnings mix between our higher and lower tax rate jurisdictions as well as losses in certain jurisdictions for which no financial statement benefits have been recognized (Note 8).

Comparison of Years Ended December 31, 2021 and 2020

Various financial and operational highlights for the years ended December 31, 2021 and 2020 were previously presented in our 2021 Annual Report on Form 10-K.

LIQUIDITY AND CAPITAL RESOURCES

Financial Condition and Liquidity

The following table presents certain information useful in the analysis of our financial condition and liquidity (in thousands):

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Net Working Capital

Net working capital is equal to current assets minus current liabilities and includes current maturities of long-term debt. Net working capital measures short-term liquidity and is important for predicting cash flow and debt servicing capacity.

Long-Term Debt

Long-term debt in the table above is net of unamortized debt issuance costs and excludes current maturities of $38.2 million and $42.9 million, respectively, at December 31, 2022 and 2021. See Note 7 for information relating to our long-term debt.

Liquidity

We define liquidity as cash and cash equivalents, excluding restricted cash, plus available capacity under our credit facility. Our liquidity at December 31, 2022 included $186.6 million of cash and cash equivalents and $98.1 million of available borrowing capacity under the ABL Facility (Note 7) and excluded $2.5 million of restricted cash. Our liquidity at December 31, 2021 included $253.5 million of cash and cash equivalents and $51.1 million of available borrowing capacity under the ABL Facility and excluded $73.6 million of short-term project related restricted cash. The reduction in cash and cash equivalents was primarily attributable to our acquisition of Alliance on July 1, 2022 (Note 3). The increase in available borrowing capacity under the ABL Facility resulted from debt repayments during 2022. As of December 31, 2022, we had approximately $28.9 million in Nigerian Naira, which is subject to currency exchange controls established by the Central Bank of Nigeria. Those exchange controls have to date restricted our ability to convert our Nigerian Naira into U.S. dollars.

During 2022, we saw an improvement in the markets we serve as evidenced by increases in our revenues and gross profit. We expect continued improvements in our operating performance, increases in our cash position and high availability on the ABL Facility. We believe that our cash on hand, internally generated cash flows and availability under the ABL Facility will be sufficient to fund our operations and service our debt over at least the next 12 months.

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A period of weak industry activity may make it difficult to comply with the covenants and other restrictions in our debt agreements. Our failure to comply with the covenants and other restrictions could lead to an event of default. Decreases in our borrowing base may limit our ability to fully access the ABL Facility. We currently do not anticipate borrowing under the ABL Facility other than for the issuance of letters of credit.

On February 20, 2023, we announced that our Board authorized a new share repurchase program under which we are authorized to repurchase up to $200 million issued and outstanding shares of our common stock. The repurchase program has no set expiration date. Repurchases under the program would be made through open market purchases in compliance with Rule 10b-18 under the Exchange Act, privately negotiated transactions or plans, instructions or contracts established under Rule 10b5-1 under the Exchange Act. The manner, timing and amount of any purchase will be determined by management based on an evaluation of market conditions, stock price, liquidity and other factors. The program does not obligate us to acquire any particular amount of common stock and may be modified or superseded at any time at our discretion. The purchase of shares by us under the program is at our discretion and subject to prevailing financial and market conditions. Any repurchased shares are expected to be cancelled. No repurchases have been made pursuant to this program at the time of this filing.

Cash Flows

The following table provides summary data from our consolidated statements of cash flows (in thousands):

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Operating Activities

The decrease in our operating cash flows for 2022 as compared to 2021 primarily reflects higher regulatory recertification costs for our vessels and systems and negative changes in net working capital. Regulatory recertification spend on our vessels and systems amounted to $35.1 million and $9.6 million, respectively, during the comparable year over year periods. Operating cash flows for 2022 and 2021 included the receipt of $1.1 million and $18.9 million, respectively, in income tax refunds related to the U.S. Coronavirus Aid, Relief, and Economic Security Act.

Investing Activities

Cash flows used in investing activities for 2022 as compared to 2021 primarily reflect $112.6 million in net cash paid to acquire Alliance (Note 3), offset in part by $7.8 million in net cash distribution from Independence Hub in May 2022 (Note 2) and the deferral or reduction of our planned capital expenditures as our response to the adverse impact to our operations as a result of the COVID-19 pandemic.

Financing Activities

Net cash outflows from financing activities in 2022 primarily reflect the repayment of $7.9 million related to the MARAD Debt and $35 million related to the 2022 Notes (Note 7). Net cash outflows from financing activities of $96.0 million in 2021 primarily reflect the repayment of $90.9 million related to our indebtedness, including the final maturity of $53.6 million of the Nordea Q5000 Loan in January 2021 and $28.0 million in full repayment of the Term Loan in September 2021.

Material Cash Requirements

Our material cash requirements include our obligations to repay our long-term debt, satisfy other contractual cash commitments and fund other obligations, including the payment of the Alliance earn-out consideration to the seller in the Alliance transaction.

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Long-term debt and other contractual commitments

The following table summarizes the principal amount of our long-term debt and related debt service costs as well as other contractual commitments, which include commitments for property and equipment and operating lease obligations, as of December 31, 2022 and the portions of those amounts that are short-term (due in less than one year) and long-term (due in one year or greater) based on their stated maturities (in thousands). Our property and equipment commitments include contractually committed amounts to purchase and service certain property and equipment (inclusive of commitments related to regulatory recertification and dry dock as discussed below) but do not include expected capital spending that is not contractually committed as of December 31, 2022. Our 2023 Notes and 2026 Notes have certain early redemption and conversion features that could affect the timing and amount of any cash requirements. Although upon conversion these notes are able to be settled in either cash or shares, we intend to settle their principal amounts in cash (Note 7).

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Other material cash requirements

Other material cash requirements include the following:

Decommissioning. We have decommissioning obligations associated with our oil and gas properties (Note 15). Those obligations, which are presented on a discounted basis on the consolidated balance sheets, approximate $78.6 million (undiscounted) as of December 31, 2022, none of which is expected to be paid during the next 12 months. We are entitled to receive certain amounts from Marathon Oil as certain decommissioning obligations are fulfilled.

Regulatory certification and dry dock. Our Well Intervention vessels and systems are subject to certain regulatory recertification requirements that must be satisfied in order for the vessels and systems to operate. Recertification may require dry dock and other compliance costs on a periodic basis, usually every 30 months. Although the amount and timing of these costs may vary, they generally range between $3.0 million to $15.0 million per vessel and $0.5 million to $5.0 million per system.

We expect the sources of funds to satisfy our material cash requirements to primarily come from our ongoing operations and existing cash on hand, but may also come from availability under the Amended ABL Facility and access to capital markets.

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CRITICAL ACCOUNTING ESTIMATES

Our discussion and analysis of our financial condition and results of operations, as reflected in the consolidated financial statements and related footnotes included in Item 8. Financial Statements and Supplementary Data of this Annual Report, are prepared in conformity with GAAP. As such, we are required to make certain estimates, judgments and assumptions that have had or are reasonably likely to have a material impact on our financial condition or results of operations. We base our estimates on historical experience, available information and various other assumptions we believe to be reasonable under the circumstances. These estimates involve a significant level of estimation uncertainty and may change over time as new events occur, as more experience is acquired, as additional information is obtained and as our operating environment changes. We believe that the most critical accounting estimates are described below. See Note 2 to our consolidated financial statements for a detailed discussion on the application of our accounting policies.

Business Acquisition

We account for business acquisitions under the acquisition method of accounting. We determine the purchase price to be the cash and other assets transferred to the seller and the value of any liabilities, such as contingent consideration or other seller financing incurred. The estimate of any contingent consideration and its fair value on the acquisition date and subsequent reporting periods is a significant estimate.

We allocate the purchase price of businesses we acquire to identifiable assets acquired and liabilities assumed based on their estimated fair values at the acquisition date. Any excess purchase price over the fair value of the net identifiable assets acquired is recorded as goodwill. The allocation of the purchase price requires management to make significant estimates in determining the fair values of assets acquired and liabilities assumed. These estimates and assumptions may include, but are not limited to, the cash flows that an asset is expected to generate in the future, the appropriate weighted average cost of capital, and the estimated useful lives. Changes in these assumptions could affect the carrying value of these assets, the amount of future depreciation or amortization and any possible impairment charges.

We use available and relevant information to estimate fair values (including quoted market prices when available) and the nominal value of acquired assets and assumed liabilities as well as deploy various valuation techniques such as discounted cash flows. We may engage third party specialists to assist in the fair value determination of acquired assets and liabilities, including identifiable long-lived assets and identifiable intangible assets, as well as any contingent earn-out consideration to be paid to the seller if certain future conditions are met. The judgments made in determining the estimated fair value assigned to each class of assets acquired and liabilities assumed, the estimated fair value of contingent earn-out considerations, as well as the remaining useful lives of these assets, could materially impact our financial condition or results of operations. See Note 3 to our consolidated financial statements for further discussion on our acquisition of Alliance during 2022.

Property and Equipment

We review our property and equipment for impairment indicators at least quarterly or whenever changes in facts and circumstances indicate that the carrying amount of the asset or asset group may not be recoverable. We evaluate impairment indicators considering the nature of the asset or asset group, the future economic benefits of the asset or asset group, historical and estimated future profitability measures, and other external market conditions or factors that may be present. We often estimate future earnings and cash flows of our assets to corroborate our determination of whether impairment indicators exist. If impairment indicators suggest that the carrying amount of an asset may not be recoverable, we determine whether an impairment has occurred by estimating undiscounted cash flows of the asset and comparing those cash flows to the asset’s carrying value. If the undiscounted cash flows are less than the asset’s carrying value (i.e., the asset is unrecoverable), impairment, if any, is recognized for the difference between the asset’s carrying value and its estimated fair value. The expected future cash flows used for the assessment of recoverability are based on judgmental assessments of operating costs, project margins and capital project spending, considering information available at the date of review. Because there usually is a lack of quoted market prices for long-lived assets, the fair value of impaired assets is typically determined based on the present values of expected future cash flows using discount rates believed to be consistent with those used by principal market participants or based on a multiple of operating cash flows validated with historical market transactions of similar assets where possible.

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The determination of the appropriate asset groups at which to evaluate impairment, the review of property and equipment for impairment indicators, the projection of future cash flows of property and equipment, and the estimated fair value of any property and equipment that may be deemed unrecoverable involve significant judgment and estimation by our management. Changes to those judgments and estimations could require us to recognize impairment charges in the future.

New Accounting Standards

For discussion on the potential impact of new accounting standards issued but not yet adopted, see Note 2 to our consolidated financial statements.

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Item 7A. Quantitative and Qualitative Disclosures About Market Risk

As a multi-national organization, we are subject to market risks associated with foreign currency exchange rates, interest rates and commodity prices.

Foreign Currency Exchange Rate Risk. Because we operate in various regions around the world, we conduct a portion of our business in currencies other than the U.S. dollar. As such, our earnings are impacted by movements in foreign currency exchange rates when (i) transactions are denominated in currencies other than the functional currency of the relevant Helix entity or (ii) the functional currency of our subsidiaries is not the U.S. dollar. In order to mitigate the effects of exchange rate risk in areas outside the U.S., we endeavor to pay a portion of our expenses in local currencies to partially offset revenues that are denominated in the same local currencies. In addition, a substantial portion of our contracts are denominated, and provide for collections from our customers, in U.S. dollars.

Assets and liabilities of our subsidiaries that do not have the U.S. dollar as their functional currency are translated using the exchange rates in effect at the balance sheet date, and changes in the exchange rates can result in translation adjustments that are reflected in “Accumulated other comprehensive loss” in the shareholders’ equity section of our consolidated balance sheets. At December 31, 2022, approximately 40% of our net assets were impacted by changes in foreign currencies (primarily the British pound) in relation to the U.S. dollar. For the years ended December 31, 2022, 2021 and 2020, we recorded foreign currency translation gains (losses) of $(49.2) million, $(4.5) million and $12.8 million, respectively, to accumulated other comprehensive loss. Deferred taxes have not been provided on foreign currency translation adjustments as the related undistributed earnings are permanently reinvested.

When currencies other than the functional currency are to be paid or received, the resulting transaction gain or loss associated with changes in the applicable foreign currency exchange rate is recognized in the consolidated statements of operations as a component of “Other income (expense), net.” Foreign currency gains or losses from the remeasurement of monetary assets and liabilities as well as unsettled foreign currency transactions, including intercompany transactions that are not of a long-term investment nature, are also recognized as a component of “Other income (expense), net.” For the years ended December 31, 2022, 2021 and 2020, we recorded foreign currency transaction gains (losses) of $(23.4) million, $(1.5) million and $4.6 million, respectively, primarily related to U.S. dollar denominated intercompany debt in our U.K. entities.

Interest Rate Risk. In order to maintain a cost-effective capital structure, we borrow funds using a mix of fixed rate debt and variable rate debt. For fixed rate debt, changes in interest rates generally affect the fair value of the debt instrument, but not our earnings or cash flows. Conversely, for variable rate debt, changes in interest rates generally do not impact the fair value of the debt instrument, but may affect our future earnings and cash flows. Changes in fair value should not have a significant impact on fixed rate debt as there is typically no repayment obligation prior to maturity. We currently have no exposure to interest rate risks as we have no outstanding debt subject to floating rates. However, we may be at risk upon refinancing maturing debt.

Commodity Price Risk. We are exposed to market price risks related to oil and natural gas with respect to offshore oil and gas production in our Production Facilities business. Prices are volatile and unpredictable and are dependent on many factors beyond our control. See Item 1A. Risk Factors for a list of factors affecting oil and gas prices.

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Item 8. Financial Statements and Supplementary Data

Report of Independent Registered Public Accounting Firm

To the Board of Directors and Shareholders

Helix Energy Solutions Group, Inc.:

Opinion on the Consolidated Financial Statements

We have audited the accompanying consolidated balance sheets of Helix Energy Solutions Group, Inc. and subsidiaries (the Company) as of December 31, 2022 and 2021, the related consolidated statements of operations, comprehensive income (loss), shareholders’ equity, and cash flows for each of the years in the three-year period ended December 31, 2022, and the related notes (collectively, the consolidated financial statements). In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company as of December 31, 2022 and 2021, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2022, in conformity with U.S. generally accepted accounting principles.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the Company’s internal control over financial reporting as of December 31, 2022, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission, and our report dated February 23, 2023 expressed an unqualified opinion on the effectiveness of the Company’s internal control over financial reporting.

Basis for Opinion

These consolidated financial statements are the responsibility of the Company’s management. Our responsibility is to express an opinion on these consolidated 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 Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether the consolidated 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 consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks. Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial statements. Our audits also included evaluating the accounting principles used and significant estimates made by management, as well as evaluating the overall presentation of the consolidated financial statements. We believe that our audits provide a reasonable basis for our opinion.

Critical Audit Matters

The critical audit matters communicated below are matters arising from the current period audit of the consolidated financial statements that were communicated or required to be communicated to the audit committee and that: (1) relate to accounts or disclosures that are material to the consolidated financial statements and (2) involved our especially challenging, subjective, or complex judgments. The communication of critical audit matters does not alter in any way our opinion on the consolidated financial statements, taken as a whole, and we are not, by communicating the critical audit matters below, providing separate opinions on the critical audit matters or on the accounts or disclosures to which they relate.

Evaluation of property and equipment impairment triggering events

As discussed in Note 2 to the consolidated financial statements, the Company evaluates property and equipment for impairment at least quarterly or whenever events or changes in circumstances indicate that the carrying amount of an asset or asset group may not be recoverable, or triggering events. The Company performs this evaluation considering the future economic benefits of the asset or asset groups, historical and estimated future profitability measures, and other factors that may be present, such as extended periods of idle time or the inability to contract the Company’s equipment at economical rates. The carrying value of property and equipment as of December 31, 2022 was $1,642 million.

We identified the evaluation of property and equipment impairment triggering events as a critical audit matter. Sustained decreases in commodity prices and uncertainty regarding spending trends by customers in the industry may lead to periods of low utilization and low day rates for those assets or asset groups not under a long-term contract, and the evaluation of the impact of these factors required a higher degree of subjective auditor judgment.

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The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls related to the evaluation of property and equipment for impairment. This included controls related to the Company’s process to identify and evaluate triggering events that indicate that the carrying value of an asset or asset group may not be recoverable, including the consideration of forecasted to actual results and market conditions in determination of a triggering event. We evaluated the Company’s identification of triggering events, including consideration of future expected revenues from executed contracts. We compared data used by the Company against analyst and industry reports. We compared the Company’s historical forecasts to actual results by asset group to assess the Company’s ability to accurately forecast.

Fair value measurement of contingent consideration and property and equipment acquired in the Alliance acquisition

As discussed in Note 3 to the consolidated financial statements, on July 1, 2022, the Company acquired the Alliance group of companies (Alliance) in a business combination for total purchase consideration of $145.7 million, including contingent consideration related to the post-closing earn-out consideration. In connection with the transaction, the purchase price consideration was allocated to the assets acquired and liabilities assumed of Alliance based upon their fair values as of the acquisition date, primarily comprised of property and equipment which the Company estimated the fair value to be approximately $117.3 million. The acquisition date fair value of the contingent consideration was approximately $26.7 million and year end fair value was approximately $42.8 million.

We identified the evaluation of the fair value measurement of the contingent consideration and the property and equipment acquired in the Alliance acquisition, including the subsequent fair value measurement of the contingent consideration, as a critical audit matter. Specifically, there was complex auditor judgment involved in evaluating (1) the weighted average cost of capital and the expected gross profit assumptions used to estimate the fair value of the contingent consideration which was sensitive to changes in those assumptions and (2) the estimated replacement cost and economic obsolescence assumptions used to determine the fair value of the property and equipment.

The following are the primary procedures we performed to address this critical audit matter. We evaluated the design and tested the operating effectiveness of certain internal controls over the Company’s acquisition-date and year-end valuation process, including controls related to the determination of the assumptions listed above. We evaluated the reasonableness of the Company’s forecasted gross profit as of the acquisition date and year-end for the period of the contingent consideration by comparing the forecast to (1) Alliance’s historical gross profit trends, (2) Alliance’s actual performance subsequent to the acquisition, and (3) external economic and market data. In addition, we involved valuation professionals with specialized skills and knowledge, who assisted in evaluating:

/s/ KPMG LLP

We have served as the Company’s auditor since 2016.

Houston, Texas

February 23, 2023

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Report of Independent Registered Public Accounting Firm

To the Board of Directors and Shareholders

Helix Energy Solutions Group, Inc.:

Opinion on Internal Control Over Financial Reporting

We have audited Helix Energy Solutions Group, Inc. and subsidiaries’ (the Company) internal control over financial reporting as of December 31, 2022, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission. In our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of December 31, 2022, based on criteria established in Internal Control — Integrated Framework (2013) issued by the Committee of Sponsoring Organizations of the Treadway Commission.

We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States) (PCAOB), the consolidated balance sheets of the Company as of December 31, 2022 and 2021, the related consolidated statements of operations, comprehensive income (loss), shareholders’ equity, and cash flows for each of the years in the three-year period ended December 31, 2022, and the related notes (collectively, the consolidated financial statements), and our report dated February 23, 2023 expressed an unqualified opinion on those consolidated financial statements.

The Company acquired the Alliance group of companies during 2022, and management excluded from its assessment of the effectiveness of the Company’s internal control over financial reporting as of December 31, 2022, the Alliance group of companies’ internal control over financial reporting associated with approximately 8.7% of total assets and 14.3% of total revenues included in the consolidated financial statements of the Company as of and for the year ended December 31, 2022. Our audit of internal control over financial reporting of the Company also excluded an evaluation of the internal control over financial reporting of the Alliance group of companies.

Basis for Opinion

The Company’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 Company’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 Company in accordance with the U.S. federal securities laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.

We conducted our audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all material respects. Our audit of internal control over financial reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk. Our audit also included 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, 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/ KPMG LLP

Houston, Texas

February 23, 2023

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HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES

CONSOLIDATED BALANCE SHEETS

(in thousands)

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

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HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES

CONSOLIDATED STATEMENTS OF OPERATIONS

(in thousands, except per share amounts)

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