HELIX ENERGY SOLUTIONS GROUP INC 10-K

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, 2023 and 2022, 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, 2023, 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, 2023 and 2022, and the results of its operations and its cash flows for each of the years in the three-year period ended December 31, 2023, 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, 2023, 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 28, 2024 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 Matter The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial statements that was communicated or required to be communicated to the audit committee and that: (1) relates 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 a critical audit matter 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 matter below, providing separate opinions on the critical audit matter or on the accounts or disclosures to which it relates. 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, 2023 was $1,573 million. 47 Table of Contents 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. 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. /s/ KPMG LLP We have served as the Company’s auditor since 2016. Houston, Texas February 28, 2024 ​ 48 Table of Contents 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, 2023, 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, 2023, 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, 2023 and 2022, 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, 2023, and the related notes (collectively, the consolidated financial statements), and our report dated February 28, 2024 expressed an unqualified opinion on those consolidated financial statements. 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 28, 2024 ​ 49 Table of Contents HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES CONSOLIDATED BALANCE SHEETS (in thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ December 31, ​ 2023 2022 ASSETS ​ ​ Current assets: ​ ​ Cash and cash equivalents ​ $ 332,191 ​ $ 186,604 Restricted cash ​ — ​ 2,507 Accounts receivable, net of allowance for credit losses of $ 3,407 and $ 2,277 , respectively ​ 280,427 ​ 212,779 Other current assets ​ 85,223 ​ 58,699 Total current assets ​ 697,841 ​ 460,589 Property and equipment ​ 3,078,571 ​ 3,016,312 Less accumulated depreciation ​ ( 1,505,722 ) ​ ( 1,374,697 ) Property and equipment, net ​ 1,572,849 ​ 1,641,615 Operating lease right-of-use assets ​ 169,233 ​ 197,849 Deferred recertification and dry dock costs, net ​ ​ 71,290 ​ ​ 38,778 Other assets, net ​ 44,823 ​ 50,507 Total assets ​ $ 2,556,036 ​ $ 2,389,338 ​ ​ ​ ​ ​ ​ ​ LIABILITIES AND SHAREHOLDERS' EQUITY ​ ​ Current liabilities: ​ ​ Accounts payable ​ $ 134,552 ​ $ 135,267 Accrued liabilities ​ 203,112 ​ 73,574 Current maturities of long-term debt ​ 48,292 ​ 38,200 Current operating lease liabilities ​ 62,662 ​ 50,914 Total current liabilities ​ 448,618 ​ 297,955 Long-term debt ​ 313,430 ​ 225,875 Operating lease liabilities ​ 116,185 ​ 154,686 Deferred tax liabilities ​ 110,555 ​ 98,883 Other non-current liabilities ​ 66,248 ​ 95,230 Total liabilities ​ 1,055,036 ​ 872,629 Commitments and contingencies ​ ​ ​ ​ ​ ​ Shareholders’ equity: ​ ​ Common stock, no par, 240,000 shares authorized, 152,291 and 151,935 shares issued, respectively ​ 1,271,565 ​ 1,298,740 Retained earnings ​ 312,450 ​ 323,288 Accumulated other comprehensive loss ​ ( 83,015 ) ​ ( 105,319 ) Total shareholders’ equity ​ 1,501,000 ​ 1,516,709 Total liabilities and shareholders’ equity ​ $ 2,556,036 ​ $ 2,389,338 ​ The accompanying notes are an integral part of these consolidated financial statements. ​ 50 Table of Contents HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF OPERATIONS (in thousands, except per share amounts) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 2022 2021 Net revenues ​ $ 1,289,728 ​ $ 873,100 ​ $ 674,728 Cost of sales ​ 1,089,372 ​ 822,484 ​ 659,335 Gross profit ​ 200,356 ​ 50,616 ​ 15,393 Gain (loss) on disposition of assets, net ​ 367 ​ — ​ ( 631 ) Acquisition and integration costs ​ ​ ( 540 ) ​ ​ ( 2,664 ) ​ ​ — Change in fair value of contingent consideration ​ ​ ( 42,246 ) ​ ​ ( 16,054 ) ​ ​ — Selling, general and administrative expenses ​ ( 94,427 ) ​ ( 76,753 ) ​ ( 63,449 ) Income (loss) from operations ​ 63,510 ​ ( 44,855 ) ​ ( 48,687 ) Equity in earnings (losses) of investment ​ — ​ 8,262 ​ ( 1 ) Net interest expense ​ ( 17,338 ) ​ ( 18,950 ) ​ ( 23,201 ) Loss on extinguishment of long-term debt ​ ( 37,277 ) ​ — ​ ( 136 ) Other expense, net ​ ( 3,590 ) ​ ( 23,330 ) ​ ( 1,490 ) Royalty income and other ​ 2,209 ​ 3,692 ​ 2,873 Income (loss) before income taxes ​ 7,514 ​ ( 75,181 ) ​ ( 70,642 ) Income tax provision (benefit) ​ 18,352 ​ 12,603 ​ ( 8,958 ) Net loss ​ ( 10,838 ) ​ ( 87,784 ) ​ ( 61,684 ) Net loss attributable to redeemable noncontrolling interests ​ — ​ — ​ ( 146 ) Net loss attributable to common shareholders ​ $ ( 10,838 ) ​ $ ( 87,784 ) ​ $ ( 61,538 ) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Loss per share of common stock: ​ ​ ​ Basic ​ $ ( 0.07 ) ​ $ ( 0.58 ) ​ $ ( 0.41 ) Diluted ​ $ ( 0.07 ) ​ $ ( 0.58 ) ​ $ ( 0.41 ) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted average common shares outstanding: ​ ​ ​ Basic ​ 150,917 ​ 151,276 ​ 150,056 Diluted ​ 150,917 ​ 151,276 ​ 150,056 ​ The accompanying notes are an integral part of these consolidated financial statements. ​ HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (in thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 2022 ​ 2021 Net loss ​ $ ( 10,838 ) $ ( 87,784 ) ​ $ ( 61,684 ) Other comprehensive income (loss), net of tax: ​ ​ ​ ​ Foreign currency translation gain (loss) ​ 22,304 ​ ( 49,237 ) ​ ​ ( 4,462 ) Other comprehensive income (loss), net of tax ​ 22,304 ​ ( 49,237 ) ​ ​ ( 4,462 ) Comprehensive income (loss) ​ 11,466 ​ ( 137,021 ) ​ ​ ( 66,146 ) Less comprehensive loss attributable to redeemable noncontrolling interests: ​ ​ ​ ​ Net loss ​ — ​ — ​ ​ ( 146 ) Foreign currency translation gain ​ — ​ — ​ ​ 50 Comprehensive loss attributable to redeemable noncontrolling interests ​ — ​ — ​ ​ ( 96 ) Comprehensive income (loss) attributable to common shareholders ​ $ 11,466 $ ( 137,021 ) ​ $ ( 66,050 ) ​ The accompanying notes are an integral part of these consolidated financial statements. ​ 51 Table of Contents HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY (in thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accumulated ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Other ​ Total ​ Redeemable ​ ​ Common Stock ​ Retained Comprehensive ​ Shareholders’ ​ Noncontrolling ​ Shares Amount Earnings Loss Equity Interests Balance, December 31, 2020 150,341 ​ $ 1,327,592 ​ $ 464,524 ​ $ ( 51,620 ) ​ $ 1,740,496 ​ $ 3,855 Net loss — ​ — ​ ( 61,538 ) ​ — ​ ( 61,538 ) ​ ( 146 ) Cumulative-effect adjustments upon adoption of ASU No. 2020-06 — ​ ( 41,456 ) ​ 6,682 ​ — ​ ( 34,774 ) ​ — Foreign currency translation adjustments — ​ — ​ — ​ ( 4,462 ) ​ ( 4,462 ) ​ 50 Accretion of redeemable noncontrolling interests — ​ — ​ 1,404 ​ — ​ 1,404 ​ ( 1,404 ) Acquisition of redeemable noncontrolling interests — ​ — ​ — ​ — ​ — ​ ( 2,355 ) Activity in company stock plans, net and other 783 ​ ( 1,128 ) ​ — ​ — ​ ( 1,128 ) ​ — Share-based compensation — ​ 7,471 ​ — ​ — ​ 7,471 ​ — Balance, December 31, 2021 151,124 ​ $ 1,292,479 ​ $ 411,072 ​ $ ( 56,082 ) ​ $ 1,647,469 ​ $ — Net loss — ​ — ​ ( 87,784 ) ​ — ​ ( 87,784 ) ​ — Foreign currency translation adjustments — ​ — ​ — ​ ( 49,237 ) ​ ( 49,237 ) ​ — Activity in company stock plans, net and other 811 ​ ( 991 ) ​ — ​ — ​ ( 991 ) ​ — Share-based compensation — ​ 7,252 ​ — ​ — ​ 7,252 ​ — Balance, December 31, 2022 151,935 ​ $ 1,298,740 ​ $ 323,288 ​ $ ( 105,319 ) ​ $ 1,516,709 ​ $ — Net loss — ​ — ​ ( 10,838 ) ​ — ​ ( 10,838 ) ​ — Foreign currency translation adjustments — ​ — ​ — ​ 22,304 ​ 22,304 ​ — Repurchase of convertible senior notes ​ 1,500 ​ ​ ( 35,469 ) ​ ​ — ​ ​ — ​ ​ ( 35,469 ) ​ ​ — Termination of capped calls ​ — ​ ​ 14,225 ​ ​ — ​ ​ — ​ ​ 14,225 ​ ​ — Repurchases of common stock ​ ( 1,584 ) ​ ​ ( 11,988 ) ​ ​ — ​ ​ — ​ ​ ( 11,988 ) ​ ​ — Activity in company stock plans, net and other 440 ​ ( 92 ) ​ — ​ — ​ ( 92 ) ​ — Share-based compensation — ​ 6,149 ​ — ​ — ​ 6,149 ​ — Balance, December 31, 2023 152,291 ​ $ 1,271,565 ​ $ 312,450 ​ $ ( 83,015 ) ​ $ 1,501,000 ​ $ — ​ The accompanying notes are an integral part of these consolidated financial statements. ​ 52 Table of Contents HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES CONSOLIDATED STATEMENTS OF CASH FLOWS (in thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2023 ​ 2022 ​ 2021 Cash flows from operating activities: ​ ​ ​ ​ ​ Net loss ​ $ ( 10,838 ) ​ $ ( 87,784 ) ​ $ ( 61,684 ) Adjustments to reconcile net loss to net cash provided by operating activities: ​ ​ ​ Depreciation and amortization ​ 164,116 ​ 142,686 ​ 141,514 Amortization of debt discount ​ 17 ​ — ​ — Amortization of debt issuance costs ​ 2,485 ​ 2,334 ​ 3,179 Share-based compensation ​ 6,510 ​ 7,451 ​ 7,689 Deferred income taxes ​ 11,532 ​ 4,386 ​ ( 15,202 ) Equity in (earnings) losses of investment ​ — ​ ( 8,262 ) ​ 1 (Gain) loss on disposition of assets, net ​ ( 367 ) ​ — ​ 631 Loss on extinguishment of long-term debt ​ 37,277 ​ — ​ 136 Unrealized foreign currency loss ​ 8,310 ​ 21,596 ​ 2,252 Change in fair value of contingent consideration ​ ​ 42,246 ​ ​ 16,054 ​ ​ — Changes in operating assets and liabilities: ​ ​ ​ ​ Accounts receivable, net ​ ( 64,520 ) ​ ( 29,865 ) ​ ( 14,154 ) Other current assets ​ ​ ( 22,597 ) ​ ​ 7,593 ​ ​ 22,973 Income tax payable, net of income tax receivable ​ ( 418 ) ​ ( 49 ) ​ 18,610 Accounts payable and accrued liabilities ​ 31,996 ​ 9,807 ​ 46,645 Deferred recertification and dry dock costs, net ​ ​ ( 62,522 ) ​ ​ ( 35,072 ) ​ ​ ( 9,620 ) Other, net ​ 9,230 ​ 233 ​ ( 2,853 ) Net cash provided by operating activities ​ 152,457 ​ 51,108 ​ 140,117 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Cash flows from investing activities: ​ ​ ​ Alliance acquisition, net of cash acquired ​ — ​ ( 112,625 ) ​ — Capital expenditures ​ ( 19,588 ) ​ ( 33,504 ) ​ ( 8,322 ) Distribution from equity investment, net ​ — ​ 7,840 ​ — Proceeds from sale of assets ​ ​ 365 ​ ​ — ​ ​ 51 Proceeds from insurance recoveries ​ 564 ​ — ​ — Net cash used in investing activities ​ ( 18,659 ) ​ ( 138,289 ) ​ ( 8,271 ) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Cash flows from financing activities: ​ ​ ​ Proceeds from senior notes, net of discount ​ 298,578 ​ — ​ — Payments related to convertible senior notes ​ ( 261,147 ) ​ ( 35,000 ) ​ — Repayment of Term Loan ​ — ​ — ​ ( 29,826 ) Repayment of Nordea Q5000 Loan ​ — ​ — ​ ( 53,572 ) Repayment of MARAD Debt ​ ( 8,333 ) ​ ( 7,937 ) ​ ( 7,560 ) Proceeds from settlement of capped calls ​ 15,591 ​ — ​ — Debt issuance costs ​ ( 6,817 ) ​ ( 580 ) ​ ( 1,337 ) Acquisition of redeemable noncontrolling interests ​ ​ — ​ ​ — ​ ​ ( 2,355 ) Repurchases of common stock ​ ​ ( 11,988 ) ​ ​ — ​ ​ — Payments related to tax withholding for share-based compensation ​ ( 1,757 ) ​ ( 1,902 ) ​ ( 2,001 ) Proceeds from issuance of ESPP shares ​ 982 ​ 575 ​ 654 Net cash provided by (used in) financing activities ​ 25,109 ​ ( 44,844 ) ​ ( 95,997 ) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Effect of exchange rate changes on cash and cash equivalents and restricted cash ​ ( 15,827 ) ​ ( 5,991 ) ​ ( 42 ) Net increase (decrease) in cash and cash equivalents and restricted cash ​ 143,080 ​ ( 138,016 ) ​ 35,807 Cash and cash equivalents and restricted cash: ​ ​ ​ Balance, beginning of year ​ 189,111 ​ 327,127 ​ 291,320 Balance, end of year ​ $ 332,191 ​ $ 189,111 ​ $ 327,127 ​ The accompanying notes are an integral part of these consolidated financial statements. ​ 53 Table of Contents HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES NOTES TO CONSOLIDATED FINANCIAL STATEMENTS Note 1 — Organization Unless the context indicates otherwise, the terms “we,” “us” and “our” in this Annual Report refer collectively to Helix Energy Solutions Group, Inc. and its subsidiaries (“Helix” or the “Company”). 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 key in supporting a global energy transition by maximizing production of existing oil and gas reserves, decommissioning end-of-life oil and gas fields and supporting renewable energy developments. 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 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 re-branded as Helix Alliance. 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. Our Operations Our services are segregated into four reportable business segments: Well Intervention, Robotics, Shallow Water Abandonment, which was formed in the third quarter 2022 comprising the Helix Alliance business, and Production Facilities. Our Well Intervention segment provides services enabling our customers to safely access subsea offshore wells for the purpose of performing production enhancement or decommissioning operations, thereby mitigating the need to drill new wells by extending the useful lives of existing wells and preserving the environment by preventing uncontrolled releases of oil and natural gas. Our well intervention vessels include the Q4000 , the Q5000 , the Q7000 , the Seawell , the Well Enhancer , and two chartered monohull vessels, the Siem Helix 1 and the Siem Helix 2 . Our well intervention equipment includes intervention systems such as intervention riser systems (“IRSs”), subsea intervention lubricators (“SILs”) and the Riserless Open-water Abandonment Module, some of which we provide on a stand-alone basis. 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 with the delivery of renewable 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. We offer our ROVs, trenchers and the IROV boulder grab on a stand-alone basis or on an integrated basis with chartered robotics support vessels. Our Shallow Water Abandonment segment provides services in support of the upstream and midstream ‎industries predominantly in the Gulf of Mexico shelf, including 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, plug and abandonment (“P&A”) systems and coiled tubing (“CT”) systems. Our Production Facilities segment includes the Helix Producer I (the “ HP I ”), the Helix Fast Response System (the “HFRS”), and our ownership of mature oil and gas properties. All of our current Production Facilities activities are located in the Gulf of Mexico. ​ 54 Table of Contents Note 2 — Summary of Significant Accounting Policies Principles of Consolidation Our consolidated financial statements include the accounts of our majority-owned subsidiaries. The equity method is used to account for investments in affiliates in which we do not have majority ownership but have the ability to exert significant influence. All material intercompany accounts and transactions have been eliminated. Basis of Presentation Our consolidated financial statements have been prepared in conformity with U.S. generally accepted accounting principles (“GAAP”) in U.S. dollars. Certain reclassifications were made to previously reported amounts in the consolidated financial statements and notes thereto to make them consistent with the current presentation format. We have made all adjustments that we believe are necessary for a fair presentation of our consolidated financial statements. Use of Estimates The preparation of financial statements in conformity with GAAP requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results may differ from those estimates. Cash and Cash Equivalents Cash and cash equivalents are highly liquid financial instruments with original maturities of three months or less. They are carried at cost plus accrued interest, which approximates fair value. Restricted Cash We classify cash as restricted when there are legal or contractual restrictions for its withdrawal. Our restricted cash as of December 31, 2022 consisted of $ 2.5 million pledged toward our asset-based credit agreement (the “ABL Facility”). Accounts Receivable and Allowance for Credit Losses Accounts receivable are recognized when our right to consideration becomes unconditional. Accounts receivable are stated at the historical carrying amount, net of write-offs and allowance for credit losses. We perform ongoing credit evaluations of our customers and provide allowances for expected credit losses. We estimate current expected credit losses on our accounts receivable at each reporting date based on our credit loss history, adjusted for current factors including global economic and business conditions, offshore energy industry and market conditions, customer mix, contract payment terms and past due accounts receivable. Uncollectible receivables are written off when a settlement is reached for an amount that is less than the outstanding historical balance or when we have determined that the balance will not be collected (Note 18). Business Combinations Business combinations are accounted for using the acquisition method of accounting in accordance with Accounting Standards Codification (“ASC”) Topic 805, Business Combinations. The purchase price consideration is allocated to the assets acquired and liabilities assumed based upon estimates of their fair values as of the acquisition date. Fair values of the assets acquired and liabilities assumed are measured in accordance with ASC Topic 820, Fair Value Measurement, using income approach, cost approach and other applicable valuation techniques. The fair value of property, plant and equipment acquired from the acquisition was estimated primarily by applying the cost approach. The key assumptions of the cost approach include replacement cost new, physical deterioration, functional and economic obsolescence and economic useful life. The fair value of intangible assets acquired from the acquisition was estimated primarily by applying the income approach. The key assumptions of the income approach include revenue projections, royalty rates and economic useful life. For certain other assets and liabilities, those fair values are consistent with historical carrying values. 55 Table of Contents The purchase price allocation is subject to revision to reflect new information obtained about facts and circumstances that existed at the acquisition date. The purchase price consideration, as well as the estimated fair values of the assets acquired and liabilities assumed, is finalized as soon as practicable, but no later than one year from the closing of the acquisition. Contingent consideration payable in cash is initially measured at fair value and included as part of the purchase price and subsequently measured at fair value at the end of each reporting period with changes in value reported in “Change in fair value of contingent consideration” in the consolidated statements of operations until the liability is no longer contingent (Note 19). Acquisition and integration costs consist of legal and professional fees as well as costs incurred to integrate the acquiree’s operations and systems and to align its financial processes and procedures with those of Helix. Those costs are expensed as incurred and are presented separately from “Selling, general and administrative expenses” in the consolidated statements of operations. Property and Equipment Property and equipment (including oil and gas properties) acquired separately from a business combination is recorded initially at cost and subsequently depreciated on a straight-line basis over its estimated useful life. The cost of improvements is capitalized whereas the cost of repairs and maintenance is expensed as incurred. Assets used in operations are assessed for impairment whenever events or changes in circumstances indicate that the carrying amount of an asset or asset group may not be recoverable because such carrying amount may exceed the asset’s or asset group’s expected undiscounted cash flows. If the carrying amount of the asset or asset group is not recoverable and is greater than its fair value, an impairment charge is recorded. The amount of the impairment recorded is calculated as the difference between the carrying amount of the asset or asset group and its estimated fair value. Individual assets are evaluated for impairment at the lowest level where there are identifiable cash flows that are largely independent of the cash flows of other groups of assets. Equity Investment We have a 20 % ownership interest in Independence Hub, LLC (“Independence Hub”), which is included in our Production Facilities segment. We account for our ownership interest in Independence Hub using the equity method of accounting. In May 2022, we received a net cash distribution of $ 7.8 million from the sale of the “Independence Hub” platform owned by Independence Hub. Our remaining investment in Independence Hub is insignificant. Leases Leases with a term greater than one year are recognized in the consolidated balance sheet as right-of-use (“ROU”) assets and lease liabilities. We have not recognized in the consolidated balance sheet leases with an initial term of one year or less. Lease liabilities and their corresponding ROU assets are recorded at the commencement date based on the present value of lease payments over the expected lease term. The lease term may include the option to extend or terminate the lease when it is reasonably certain that we will exercise the option. We use our incremental borrowing rate, which would be the rate incurred to borrow on a collateralized basis over a similar term in a similar economic environment, to calculate the present value of lease payments. ROU assets are adjusted for any initial direct costs paid or incentives received. We separate our long-term vessel charters between their lease components and non-lease services. We estimate the lease component using the residual approach by estimating the non-lease services, which primarily include crew, repair and maintenance, and regulatory certification costs. For all other leases, we have not separated the lease components and non-lease services. We recognize operating lease cost on a straight-line basis over the lease term for both (i) leases that are recognized in the consolidated balance sheet and (ii) short-term leases. We recognize lease cost related to variable lease payments that are not recognized in the consolidated balance sheet in the period in which the obligation is incurred. 56 Table of Contents Deferred Recertification and Dry Dock Costs Our vessels and systems are required by regulation to be periodically recertified. Recertification costs for a vessel are typically incurred while the vessel is in regulatory docking. We defer and amortize recertification costs, including vessel dry dock costs, over the period that the certification applies, which generally ranges from 24 to 60 months if the appropriate permitting is obtained. A recertification process, including vessel dry dock, typically lasts between one to three months for our vessels, a period during which a vessel or system is idle and generally not available to earn revenue. Major replacements and improvements that extend the economic useful life or functional operating capability of a vessel or system are capitalized and depreciated over the asset’s remaining economic useful life. Routine repairs and maintenance costs are expensed as incurred. During the years ended December 31, 2023, 2022 and 2021, amortization expense related to deferred recertification and dry dock costs was $ 25.7 million, $ 14.0 million and $ 14.6 million, respectively. Revenue Recognition Revenue from Contracts with Customers We generate revenue in our Well Intervention segment by supplying vessels, personnel and equipment to provide well intervention services, which involve providing marine access, serving as a deployment mechanism to the subsea well, connecting to and maintaining a secure connection to the subsea well and maintaining well control through the duration of the intervention services. We may also perform down-hole intervention work and provide certain engineering services. We generate revenue in our Robotics segment by operating ROVs and trenchers to provide subsea trenching and burial of pipelines and cables as well as seabed clearance for the oil and gas and the renewable energy markets and to provide offshore construction, well intervention support and IRM services to oil and gas companies. We also provide integrated robotic services by supplying vessels that deploy ROVs and trenchers. We generate revenue in our Production Facilities segment by supplying vessels, personnel and equipment for oil and natural gas processing, well control response services, and oil and gas production from owned properties. We generate revenue in our Shallow Water Abandonment segment by providing decommissioning and intervention services with P&A and CT systems and personnel; by providing marine access to offshore facilities with liftboats, OSVs and the crew boat in order to perform decommissioning, intervention, diving and other work scopes; and by providing diving and platform decommissioning services with DSVs and personnel and with the heavy lift barge. Our revenues are primarily derived from short-term and long-term service contracts with customers. Our service contracts generally contain provisions for specific time, material and equipment charges that are billed in accordance with the terms of such contracts (dayrate contracts) but we occasionally contract on a lump sum basis (lump sum contracts). We record revenues net of taxes collected from customers and remitted to governmental authorities. Contracts are classified as long-term if all or part of the contract is to be performed over a period extending beyond 12 months from the effective date of the contract. Long-term contracts may include multi-year agreements whereby the commitment for services in any one year may be short in duration. We generally account for our services under contracts with customers as a single performance obligation satisfied over time. The single performance obligation in our dayrate contracts is comprised of a series of distinct time increments in which we provide services. We do not account for activities that are immaterial or not distinct within the context of our contracts as separate performance obligations. Consideration received under a contract is allocated to the single performance obligation on a systematic basis that depicts the pattern of the provision of our services to the customer. We generally consider integrated offerings to be a single performance obligation due to the interdependencies of the offerings. The total transaction price for a contract is determined by estimating both fixed and variable consideration expected to be earned over the term of the contract and excludes certain amounts that have been disputed by our customers. We generally do not provide significant financing to our customers and do not adjust contract consideration for the time value of money if extended payment terms are granted for less than one year. Estimated variable consideration, if any, is considered to be constrained and therefore is not included in the transaction price until it is probable that a significant reversal in the amount of cumulative revenue recognized will not occur. At the end of each reporting period, we reassess and update our estimates of variable consideration and amounts of that variable consideration that should be constrained. 57 Table of Contents Dayrate Contracts . Revenues generated from dayrate contracts generally provide for payment according to the rates per day as stipulated in the contract (e.g., operating rate, standby rate, and repair rate). Invoices billed to the customer are typically based on the varying rates applicable to operating status on an hourly basis. Dayrate consideration is allocated to the distinct hourly time increment to which it relates and is therefore recognized in line with the contractual rate billed for the services provided for any given hour. Similarly, revenues from contracts that stipulate a monthly rate are recognized ratably during the month. Dayrate contracts also may contain fees charged to the customer for mobilizing and/or demobilizing equipment and personnel. Mobilization and demobilization are considered contract fulfillment activities, and related fees (subject to any constraint on estimates of variable consideration) are allocated to the single performance obligation and recognized ratably over the term of the contract. Mobilization fees are generally billable to the customer in the initial phase of a contract and generate contract liabilities until they are recognized as revenue. Demobilization fees are generally received at the end of the contract and generate contract assets when they are recognized as revenue prior to becoming receivables from the customer. We receive reimbursements from our customers for the purchase of supplies, equipment, personnel services and other services provided at their request. Reimbursable revenues are variable as the amounts received are generally subject to uncertainty. Accordingly, these revenues are constrained and not recognized until the related costs are incurred on behalf of the customer. We are generally considered a principal in these transactions and record the associated revenues at the gross amounts billed to the customer. A dayrate contract modification involving an extension of the contract by adding days of services is generally accounted for prospectively as a separate contract, but may be accounted for as a termination of the existing contract and creation of a new contract if the consideration for the extended services does not represent their stand-alone selling prices. Lump Sum Contracts . Revenues generated from lump sum contracts are recognized over time. Revenue is recognized based on the extent of progress towards completion of the performance obligation. We generally use the cost-to-cost measure of progress for our lump sum contracts because it best depicts the progress toward satisfaction of our performance obligation, which occurs as we incur costs under those contracts. Under the cost-to-cost measure of progress, the extent of progress towards completion is measured based on the ratio of cumulative costs incurred to date to the total estimated costs at completion of the performance obligation. Consideration, including lump sum mobilization and demobilization fees billed to the customer, is recorded proportionally as revenue in accordance with the cost-to-cost measure of progress. Consideration for lump sum contracts is generally due from the customer based on the achievement of milestones. As such, contract assets are generated to the extent we recognize revenues in advance of our rights to collect contract consideration and contract liabilities are generated when contract consideration due or received is greater than revenues recognized to date. We review and update our contract-related estimates regularly and recognize adjustments in estimated profit on contracts under the cumulative catch-up method. Under this method, the impact of the adjustment on profit recorded to date on a contract is recognized in the period in which the adjustment is identified. Revenue and profit in future periods of contract performance are recognized using the adjusted estimate. If a current estimate of total contract costs to be incurred exceeds the estimate of total revenues to be earned, we recognize the projected loss in full when it is identified. A modification to a lump sum contract is generally accounted for as part of the existing contract and recognized as an adjustment to revenue on a cumulative catch-up basis. Income from Oil and Gas Production Income from oil and gas production is recognized according to monthly oil and gas production volumes from the oil and gas properties that we own, and is included in revenues from our Production Facilities segment. Income from Royalty Interests Income from royalty interests is recognized according to our share of monthly oil and gas production volumes and is included in “Royalty income and other” in the consolidated statements of operations. 58 Table of Contents Income Taxes Deferred income taxes are based on the differences between financial reporting and tax bases of assets and liabilities. We utilize the liability method of computing deferred income taxes. The liability method is based on the amount of current and future taxes payable using tax rates and laws in effect at the balance sheet date. Income taxes have been provided based upon the tax laws and rates in the countries in which operations are conducted and income is earned. A valuation allowance for deferred tax assets is recorded when it is more likely than not that some or all of the benefit from the deferred tax asset will not be realized. We provide for uncertain tax positions and related interest and penalties based upon management’s assessment of whether a tax benefit is more likely than not to be sustained upon examination by local taxing authorities. At December 31, 2023, we believe we have appropriately accounted for any unrecognized tax benefits. Share-Based Compensation Share-based payment awards are classified as either equity or liability awards based on various factors such as award conditions, settlement features, substantive terms and past practices. Shared-based compensation is initially measured at the grant date based on the estimated fair value of an award and subsequently measured depending on their award conditions and classification. Forfeitures are recognized as they occur. Restricted stock awards are based solely on service conditions and are accounted for as equity awards. Compensation cost for restricted stock is the product of the grant date fair value of each share and the number of shares granted and is recognized over the applicable vesting period on a straight-line basis. For performance share unit (“PSU”) awards with a service and a market condition that are accounted for as equity awards, compensation cost is measured based on the grant date estimated fair value determined using a Monte Carlo simulation model and subsequently recognized over the vesting period on a straight-line basis. For PSUs with a service and a performance condition that are accounted for as equity awards, compensation cost is initially measured based on the grant date fair value. Cumulative compensation cost is subsequently adjusted at the end of each reporting period to reflect the current estimation of achieving the performance condition. Restricted stock unit (“RSU”) awards accounted for as liability awards are measured at their estimated fair value based on the closing share price of our common stock as of each balance sheet date, and subsequent changes in the fair value of the awards are recognized in earnings for the portion of the award for which the requisite service period has elapsed. Cumulative compensation cost for vested liability RSUs equals the actual payout value upon vesting. Asset Retirement Obligations Asset retirement obligations (“AROs”) are recorded initially at fair value and consist of estimated costs for subsea infrastructure decommissioning and P&A activities associated with our oil and gas properties. The estimated costs are discounted to present value using a credit-adjusted risk-free discount rate. After its initial recognition, an ARO liability is increased for the passage of time as accretion expense, which is a component of our depreciation and amortization expense. An ARO liability may also change based on revisions in estimated costs and/or timing to settle the obligations. Foreign Currency Because we operate in various regions around the world, we conduct a portion of our business in currencies other than the U.S. dollar. Results of operations for our non-U.S. dollar subsidiaries are translated into U.S. dollars using average exchange rates during the period. Assets and liabilities of these non-U.S. dollar subsidiaries are translated into U.S. dollars using the exchange rate in effect at the end of the reporting period, and the resulting translation adjustments are included in other comprehensive income (loss) (“OCI”). 59 Table of Contents For transactions denominated in a currency other than a subsidiary’s functional currency, the effects of changes in exchange rates are reported in “Other income (expense), net” in the consolidated statements of operations. 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, 2023, 2022 and 2021, our foreign currency transaction losses totaled $ 4.4 million, $ 23.4 million and $ 1.5 million, respectively. Earnings Per Share We have shares of restricted stock issued and outstanding that are currently unvested. Because holders of shares of unvested restricted stock are entitled to the same liquidation and dividend rights as the holders of our unrestricted common stock, we are required to compute earnings per share (“EPS”) under the two-class method in periods in which we have earnings. Under the two-class method, net income for each period is allocated based on the participation rights of both common shareholders and the holders of any participating securities as if earnings for the respective periods had been distributed. For periods in which we have a net loss we do not use the two-class method as holders of our restricted shares are not obligated to share in such losses. Basic earnings per share (“EPS”) is computed by dividing net income allocated to common shareholders or net loss by the weighted average shares of our common stock outstanding. Diluted EPS is computed in a similar manner after considering the potential dilutive effect of share-based awards and convertible senior notes and taking the more dilutive of the two-class method and the treasury stock method or if-converted method, as applicable. The dilutive effect of share-based awards is computed using the treasury stock method, as applicable, which includes the incremental shares that would be hypothetically vested in excess of the number of shares assumed to be hypothetically repurchased with the assumed proceeds. The effect of convertible senior notes is computed using the if-converted method, if dilutive, which assumes conversion of the convertible senior notes into shares of our common stock at the beginning of the period, giving income recognition for the add-back of related interest expense (net of tax). Major Customers and Concentration of Risk We offer our products and services primarily in the offshore oil and gas and renewable energy markets. Oil and gas companies spend capital on exploration, drilling and production operations, the amount of which is generally dependent on the prevailing view of future oil and natural gas prices and volatility, which are subject to many external factors. 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 percentages of consolidated revenue from major customers (those representing 10% or more of our consolidated revenues) were as follows: 2023 — Apache ( 11 %) and Shell ( 10 %); 2022 — Shell ( 15 %); and 2021 — Petrobras ( 23 %) and Shell ( 17 %). Most of the concentration of revenues are in our Well Intervention segment and, for 2023, our Shallow Water Abandonment segment. As of December 31, 2023, 19 % of our labor force was covered by collective bargaining agreements or similar arrangements and 17 % of our labor force was covered by those agreements that will expire within one year. Fair Value Measurements Fair value is defined as the price that would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date. The fair value accounting rules establish a three-tier fair value hierarchy, which prioritizes the inputs used in measuring fair value as follows: ● Level 1. Observable inputs such as quoted prices in active markets; ● Level 2. Inputs, other than the quoted prices in active markets, that are observable either directly or indirectly; and ● Level 3. Unobservable inputs for which there is little or no market data, which require the reporting entity to develop its own assumptions. 60 Table of Contents Assets and liabilities measured at fair value are based on one or more of three valuation approaches as follows: (a) Market Approach. Prices and other relevant information generated by market transactions involving identical or comparable assets or liabilities. (b) Cost Approach. Amount that would be required to replace the service capacity of an asset (replacement cost). (c) Income Approach. Techniques to convert expected future cash flows to a single present amount based on market expectations (including present value techniques, option-pricing and excess earnings models). New Accounting Standards New accounting standards adopted In August 2020, the Financial Accounting Standards Board (the “FASB”) issued Accounting Standards Update (“ASU”) No. 2020-06, “Accounting for Convertible Instruments and Contracts in an Entity's Own Equity,” which simplifies the accounting for certain financial instruments with characteristics of liabilities and equity, including convertible instruments and contracts in an entity’s own equity. Among other changes, this ASU removes from GAAP the requirement to separate certain convertible instruments, such as our Convertible Senior Notes due 2022 (the “2022 Notes”), Convertible Senior Notes due 2023 (the “2023 Notes”) and Convertible Senior Notes due 2026 (the “2026 Notes”) (Note 7), into liability and equity components. Consequently, those convertible instruments will be accounted for in their entirety as liabilities measured at their amortized cost. We elected to early adopt ASU No. 2020-06 on a modified retrospective basis beginning January 1, 2021. The adoption of this ASU increased our long-term debt and decreased the reported value of our common stock by $ 44.1 million and $ 41.5 million, respectively, as we reclassified the conversion features associated with our various outstanding convertible senior notes from equity to long-term debt. The adoption of this ASU also increased our retained earnings and decreased deferred tax liabilities by $ 6.7 million and $ 9.3 million, respectively. New accounting standards issued but not yet effective In November 2023, the FASB issued ASU No. 2023-07, “Improvements to Reportable Segment Disclosures,” which requires all public entities to disclose, on an annual and interim basis, significant segment expenses that are regularly provided to the chief operating decision maker (the “CODM”) and included within each reported measure of segment profit or loss as well as an amount for other segment items by reportable segment and a description of its composition. ASU No. 2023-07 requires all annual disclosures about a reportable segment’s profit or loss and assets to be provided in interim periods as well. Among other things, this ASU also requires that a public entity disclose the title and position of the CODM and an explanation of how the CODM uses the reported measure(s) of segment profit or loss in assessing segment performance and deciding how to allocate resources. ASU No. 2023-07 will be effective on a retrospective basis for annual periods beginning January 1, 2024 and for interim periods beginning January 1, 2025. This ASU is not expected to have a material impact on our consolidated financial statements other than increased disclosure requirements. In December 2023, the FASB issued ASU No. 2023-09, “Improvements to Income Tax Disclosures,” which requires public business entities on an annual basis to disclose specific categories in a tabular rate reconciliation using both percentages and reporting currency amounts and to provide additional information for reconciling items that meet certain quantitative threshold. This ASU also requires that all entities disclose on an annual basis the disaggregation of income taxes paid (net of refunds received) by federal, state and foreign and by jurisdictions, of income (or loss) from continuing operations before income tax expense (or benefit) between domestic and foreign, and of income tax expense (or benefit) from continuing operations by federal, state and foreign. Certain previous disclosure requirements on unrecognized tax benefits and cumulative amount of temporary differences are eliminated. ASU No. 2023-09 will be effective for us beginning January 1, 2025. This ASU is not expected to have a material impact on our consolidated financial statements other than increased disclosure requirements. We do not expect other recently issued accounting standards to have a material impact on our financial position, results of operations or cash flows when they become effective. ​ 61 Table of Contents Note 3 — Business Combinations Alliance Acquisition On July 1, 2022, we completed our acquisition of Alliance. The Alliance acquisition extended our energy transition strategy by adding shallow water capabilities into the growing offshore decommissioning market. The aggregate purchase price of the Alliance acquisition was $ 145.7 million, consisting of $ 119.0 million of cash on hand and the acquisition-date estimated fair value of $ 26.7 million related to the post-closing earn-out consideration. The earn-out was calculated based on certain financial metrics of the Helix Alliance business for 2022 and 2023 relative to amounts as set forth in the Equity Purchase Agreement dated May 16, 2022. During the fourth quarter 2023, we finalized the calculation and agreed with the seller in the Alliance transaction on an $ 85.0 million earn-out expected to be paid in cash in April 2024. As of December 31, 2023, the Alliance earn-out consideration is reported at $ 85.0 million in “Accrued liabilities” in the accompanying consolidated balance sheet (Note 4). The following table summarizes the purchase consideration and the preliminary purchase price allocation to estimated fair values of the identifiable assets acquired and liabilities assumed as of July 1, 2022 (in thousands): ​ ​ ​ ​ ​ ​ ​ July 1, 2022 Cash consideration ​ $ 118,961 Contingent consideration ​ 26,700 Total fair value of consideration transferred ​ $ 145,661 ​ ​ ​ ​ Assets acquired: ​ ​ ​ Cash and cash equivalents ​ $ 6,336 Accounts receivable ​ ​ 43,378 Other current assets ​ ​ 6,077 Property and equipment ​ ​ 117,321 Operating lease right-of-use assets ​ ​ 1,205 Intangible assets ​ ​ 1,500 Other assets ​ 2,133 Total assets acquired ​ ​ 177,950 Liabilities assumed: ​ ​ ​ Accounts payable ​ ​ 20,480 Accrued liabilities ​ ​ 3,073 Operating lease liabilities ​ 1,205 Deferred tax liabilities ​ 7,531 Total liabilities assumed ​ 32,289 Net assets acquired ​ $ 145,661 ​ The pro forma summary table below presents the results of operations as if the Alliance acquisition had occurred on January 1, 2021 (in thousands). The unaudited pro forma summary includes certain transaction accounting adjustments as necessary and uses estimates and assumptions based on information available at the time. The pro forma summary is provided for illustrative purposes only and does not purport to represent Helix’s actual consolidated results of operations had the acquisition been completed as of the date presented, nor should it be considered indicative of Helix’s future consolidated results of operations. ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2022 2021 Revenues ​ $ 952,837 ​ $ 789,051 Net loss ​ ​ ( 79,686 ) ​ ​ ( 56,203 ) ​ STL Acquisition In May 2019, we acquired a 70 % controlling interest in Subsea Technologies Group Ltd. (“STL”), a subsea engineering firm based in Aberdeen, Scotland. In June 2021, we acquired the remaining 30 % interest in STL, which had been recognized as temporary equity. STL is included in our Well Intervention segment and its revenue and earnings are immaterial to our consolidated results. ​ 62 Table of Contents Note 4 — Details of Certain Accounts Other current assets consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2023 2022 Prepaids ​ $ 28,352 $ 26,609 Contract assets (Note 11) ​ ​ 5,824 ​ ​ 6,295 Deferred costs (Note 11) ​ ​ 36,041 ​ ​ 13,969 Other ​ 15,006 ​ 11,826 Total other current assets ​ $ 85,223 $ 58,699 ​ Other assets, net consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2023 2022 Prepaid charter (1) ​ $ 12,544 ​ $ 12,544 Deferred costs (Note 11) ​ ​ 587 ​ 6,432 Other receivable (2) ​ 25,623 ​ 24,827 Intangible assets with finite lives, net ​ 4,105 ​ 4,465 Other ​ 1,964 ​ 2,239 Total other assets, net ​ $ 44,823 $ 50,507 (1) Represents prepayments to the owner of the Siem Helix 1 and the Siem Helix 2 to offset certain payment obligations associated with the vessels at the end of their respective charter term. (2) Represents the present value of the agreed-upon amounts that we are entitled to receive from Marathon Oil Corporation (“Marathon Oil”) for remaining P&A work to be performed by us on Droshky oil and gas properties we acquired from Marathon Oil in 2019. ​ Accrued liabilities consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2023 2022 Accrued payroll and related benefits ​ $ 59,010 $ 41,339 Accrued interest ​ ​ 4,181 ​ ​ 6,306 Income tax payable ​ ​ 1,938 ​ ​ 479 Deferred revenue (Note 11) ​ 32,763 ​ 9,961 Earn-out consideration (Note 3) ​ 85,000 ​ — Other (1) ​ 20,220 ​ 15,489 Total accrued liabilities ​ $ 203,112 $ 73,574 (1) During the third quarter 2023, we acquired five P&A systems and other assets for total consideration of $ 17.6 million including $ 6.0 million in cash in addition to credits towards future services offered by us. Amount as of December 31, 2023 included $ 9.0 million of those credits . ​ Other non-current liabilities consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2023 2022 Asset retirement obligations (Note 15) ​ $ 61,356 $ 51,956 Contingent consideration (Note 19) ​ ​ — ​ ​ 42,754 Other (1) ​ 4,892 ​ 520 Total other non-current liabilities ​ $ 66,248 $ 95,230 (1) Amount as of December 31, 2023 included $ 2.6 million of credits offered by us in exchange for the purchase of P&A equipment (see above). ​ ​ ​ 63 Table of Contents Note 5 — Property and Equipment The following is a summary of the gross components of property and equipment (dollars in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ ​ Estimated Useful Life 2023 2022 Vessels 15 to 30 years ​ $ 2,406,089 ​ $ 2,371,084 Systems and equipment ​ 5 to 15 years ​ ​ 337,913 ​ ​ 306,316 ROVs and trenchers 5 to 10 years ​ 252,753 ​ 262,763 Buildings and other 5 to 39 years ​ 81,816 ​ 76,149 Total property and equipment ​ ​ ​ $ 3,078,571 ​ $ 3,016,312 ​ ​ ​ Note 6 — Leases We charter vessels and lease facilities and equipment under non-cancelable contracts that expire on various dates through 2031. Our operating lease additions during the year ended December 31, 2023 are primarily related to the vessel charters for the Glomar Wave and the Horizon Enabler (Note 16). Our operating lease additions during the year ended December 31, 2022 are primarily related to the charter extensions for the Siem Helix 1 , the Siem Helix 2 , the Grand Canyon II , the Grand Canyon III and the Shelia Bordelon . We also sublease some of our facilities under non-cancelable sublease agreements. As of December 31, 2023, the minimum sublease income to be received in the future was minimal. The following table details the components of our lease cost (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2023 2022 2021 Operating lease cost ​ $ 72,775 $ 61,067 $ 60,636 Variable lease cost ​ 21,423 ​ 20,562 ​ 16,711 Short-term lease cost ​ 54,613 ​ 29,487 ​ 20,590 Sublease income ​ ( 1,113 ) ​ ( 1,275 ) ​ ( 1,303 ) Net lease cost ​ $ 147,698 $ 109,841 $ 96,634 ​ Maturities of our operating lease liabilities as of December 31, 2023 are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Facilities and ​ ​ ​ Vessels Equipment Total Less than one year ​ $ 67,488 ​ $ 6,639 $ 74,127 One to two years ​ 55,453 ​ 3,508 ​ 58,961 Two to three years ​ 35,200 ​ 1,289 ​ 36,489 Three to four years ​ 26,245 ​ 1,272 ​ 27,517 Four to five years ​ 3,040 ​ 1,244 ​ 4,284 Over five years ​ — ​ 1,926 ​ 1,926 Total lease payments ​ $ 187,426 ​ $ 15,878 $ 203,304 Less: imputed interest ​ ( 22,419 ) ​ ( 2,038 ) ​ ( 24,457 ) Total operating lease liabilities ​ $ 165,007 ​ $ 13,840 $ 178,847 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current operating lease liabilities ​ $ 56,602 ​ $ 6,060 $ 62,662 Non-current operating lease liabilities ​ 108,405 ​ 7,780 ​ 116,185 Total operating lease liabilities ​ $ 165,007 ​ $ 13,840 $ 178,847 ​ 64 Table of Contents Maturities of our operating lease liabilities as of December 31, 2022 are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Facilities and ​ ​ ​ Vessels Equipment Total Less than one year ​ $ 58,063 ​ $ 6,603 $ 64,666 One to two years ​ 55,515 ​ 5,697 ​ 61,212 Two to three years ​ 43,400 ​ 2,797 ​ 46,197 Three to four years ​ 35,200 ​ 959 ​ 36,159 Four to five years ​ 26,244 ​ 959 ​ 27,203 Over five years ​ 3,041 ​ 2,783 ​ 5,824 Total lease payments ​ $ 221,463 ​ $ 19,798 $ 241,261 Less: imputed interest ​ ( 32,986 ) ​ ( 2,675 ) ​ ( 35,661 ) Total operating lease liabilities ​ $ 188,477 ​ $ 17,123 $ 205,600 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current operating lease liabilities ​ $ 45,131 ​ $ 5,783 $ 50,914 Non-current operating lease liabilities ​ 143,346 ​ 11,340 ​ 154,686 Total operating lease liabilities ​ $ 188,477 ​ $ 17,123 $ 205,600 ​ The following table presents the weighted average remaining lease term and discount rate: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ 2023 ​ 2022 ​ 2021 Weighted average remaining lease term 3.1 years ​ 4.0 years ​ 2.4 years Weighted average discount rate 8.20 % ​ 7.84 % ​ 7.57 % ​ The following table presents other information related to our operating leases (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2023 2022 2021 Cash paid for operating lease liabilities ​ $ 68,788 $ 58,129 $ 61,826 Right-of-use assets obtained in exchange for new operating lease obligations ​ 26,502 ​ 144,134 ​ 5,992 ​ ​ ​ ​ Note 7 — Long-Term Debt Long-term debt consists of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ ​ 2023 2022 2023 Notes (matured September 2023) ​ $ — ​ $ 30,000 2026 Notes (mature February 2026) ​ 40,199 ​ 200,000 MARAD Debt (matures February 2027) ​ 32,580 ​ 40,913 2029 Notes (mature March 2029) ​ 300,000 ​ — Gross debt ​ ​ 372,779 ​ ​ 270,913 Unamortized debt discount ​ ( 1,404 ) ​ — Unamortized debt issuance costs ​ ( 9,653 ) ​ ( 6,838 ) Total debt ​ 361,722 ​ 264,075 Less current maturities (1) ​ ( 48,292 ) ​ ( 38,200 ) Long-term debt ​ $ 313,430 ​ $ 225,875 (1) Current maturities as of December 31, 2023 included the carrying amount of the 2026 Notes that are subject to conversion and/or redemption in 2024 (see Note 19 for their fair value). Current maturities as of December 31, 2022 included the carrying amount of the 2023 Notes that matured in September 2023. Current maturities as of December 31, 2023 and 2022 both included the current portion of the MARAD Debt. ​ 65 Table of Contents Credit Agreement On September 30, 2021 we entered into an asset-based credit agreement with Bank of America, N.A. (“Bank of America”), Wells Fargo Bank, N.A. and Zions Bancorporation and subsequently we entered into amendments to the credit agreement on July 1, 2022, June 23,2023 and November 15, 2023 (collectively, the “Amended ABL Facility”). The Amended ABL Facility provides for a $ 120 million asset-based revolving credit facility, which matures on September 30, 2026 , with a springing maturity 91 days prior to the maturity of any outstanding indebtedness with a principal amount in excess of $ 50 million. The Amended ABL Facility also permits us to request an increase of the facility by up to $ 30 million, subject to certain conditions. Commitments under the Amended ABL Facility are comprised of separate U.S. and U.K. revolving credit facility commitments of $ 85 million and $ 35 million, respectively. The Amended ABL Facility provides funding based on a borrowing base calculation that includes eligible U.S. and U.K. customer accounts receivable and cash, and provides for a $ 20 million sub-limit for the issuance of letters of credit. As of December 31, 2023, we had no borrowings under the Amended ABL Facility, and our available borrowing capacity under that facility, based on the borrowing base, totaled $ 99.3 million, net of $ 6.9 million of letters of credit issued under that facility. We and certain of our U.S. and U.K. subsidiaries are the current borrowers under the Amended ABL Facility, whose obligations under the Amended ABL Facility are guaranteed by those borrowers and certain other U.S. and U.K. subsidiaries, excluding Cal Dive I – Title XI, Inc. (“CDI Title XI”), Helix Offshore Services Limited and certain other enumerated subsidiaries. Other subsidiaries may be added as guarantors of the facility in the future. The Amended ABL Facility is secured by all accounts receivable and designated deposit accounts of the U.S. borrowers and guarantors, and by substantially all of the assets of the U.K. borrowers and guarantors. U.S. borrowings under the Amended ABL Facility bear interest at the Term SOFR (also known as CME Term SOFR as administered by CME Group, Inc.) rate plus a margin of 1.50 % to 2.00 % or at a base rate plus a margin of 0.50 % to 1.00 %. U.K. borrowings under the Amended ABL Facility denominated in U.S. dollars bear interest at the Term SOFR rate with SOFR adjustment of 0.10 % and U.K. borrowings denominated in the British pound bear interest at the SONIA daily rate, each plus a margin of 1.50 % to 2.00 %. We also pay a commitment fee of 0.375 % to 0.50 % per annum on the unused portion of the facility. The Amended ABL Facility includes certain limitations on our ability to incur additional indebtedness, grant liens on assets, pay dividends and make distributions on equity interests, dispose of assets, make investments, repay certain indebtedness, engage in mergers, and other matters, in each case subject to certain exceptions. The Amended ABL Facility contains customary default provisions which, if triggered, could result in acceleration of all amounts then outstanding. The Amended ABL Facility requires us to satisfy and maintain a fixed charge coverage ratio of not less than 1.0 to 1.0 if availability is less than the greater of 10 % of the borrowing base or $ 12 million. The Amended ABL Facility also requires us to maintain a pro forma minimum excess availability of $ 30 million for the 91 days prior to the maturity of each of our outstanding senior notes and for any portion of the Alliance earn-out payment to be made in cash. The Amended ABL Facility also (i) limits the amount of permitted debt for the deferred purchase price of property not to exceed $ 50 million, and (ii) provides for potential ESG-related pricing adjustments based on specific metrics and performance targets determined by us and Bank of America, as agent with respect to the Amended ABL Facility. 66 Table of Contents 2026 Notes The 2026 Notes bear interest at a coupon interest rate of 6.75 % per annum payable semi-annually in arrears on February 15 and August 15 of each year, beginning on February 15, 2021. The 2026 Notes mature on February 15, 2026 unless earlier converted, redeemed or repurchased by us (see below). The 2026 Notes are convertible by their holders at any time beginning November 17, 2025 at an initial conversion rate of 143.3795 shares of our common stock per $1,000 principal amount, which initially represented 28,675,900 shares at an initial conversion price of approximately $ 6.97 per share of common stock. Upon conversion, we have the right to satisfy our conversion obligation by delivering cash, shares of our common stock or any combination thereof. In order to reduce the potential dilution of the 2026 Notes to shareholders’ equity, we entered into capped call transactions (the “2026 Capped Calls”) in August 2020 concurrent with the 2026 Notes offering (Note 9). The 2026 Capped Calls effectively increase the conversion price of the 2026 Notes to approximately $ 8.42 per share. However, the 2026 Capped Calls are separate transactions from the 2026 Notes and do not change the holders’ rights under the 2026 Notes, and holders of the 2026 Notes do not have any rights with respect to the 2026 Capped Calls. The effective interest rate for the 2026 Notes is 7.6 %. For the years ended December 31, 2023, 2022 and 2021, total interest expense related to the 2026 Notes was $ 14.6 million, $ 14.8 million and $ 14.7 million, respectively, with coupon interest expense of $ 13.3 million, $ 13.5 million and $ 13.5 million, respectively, and the amortization of debt issuance costs of $ 1.3 million, $ 1.3 million and $ 1.2 million, respectively. Prior to November 17, 2025, holders of the 2026 Notes may convert their notes if the closing price of our common stock exceeds 130 % of the conversion price for at least 20 days in the period of 30 consecutive trading days ending on the last trading day of the preceding fiscal quarter (share price condition) or if the trading price of the 2026 Notes is equal to or less than 97 % of the conversion value of the notes during the five consecutive business days immediately after any ten consecutive trading day period (trading price condition). The 2026 Notes have been convertible since October 1, 2023 and will continue to be convertible through March 31, 2024 as a result of the share price condition being met. Holders of the 2026 Notes may also convert their notes if we make certain distributions on shares of our common stock or engage in certain corporate transactions, in which case the holders may be entitled to an increase in the conversion rate, depending on the price of our common shares and the time remaining to maturity, of up to 64.5207 shares of our common stock per $1,000 principal amount. Prior to August 15, 2023, the 2026 Notes were not redeemable. Beginning August 15, 2023, we may, at our option, redeem all or any portion of the 2026 Notes if the price of our common stock has been at least 130 % of the conversion price for at least 20 trading days during any 30 consecutive trading day period preceding the date we provide a notice of redemption and the trading day immediately preceding such date (redemption price condition). Any redemption would be payable in cash equal to 100 % of the principal amount plus accrued and unpaid interest and a “make-whole premium” calculated as the present value of all remaining scheduled interest payments. The 2026 Notes were redeemable as of December 31, 2023 based on the redemption price condition being met and on January 16, 2024 we issued a notice for the redemption of remaining 2026 Notes (see below). Holders of the 2026 Notes may convert any of their notes if we call the notes for redemption. Holders of the 2026 Notes may also require us to repurchase the notes following a “fundamental change,” which includes a change of control or a termination of trading of our common stock (as defined in the indenture governing the 2026 Notes). The indenture governing the 2026 Notes contains customary terms and covenants, including that upon certain events of default, the entire principal amount of and any accrued interest on the notes may be declared immediately due and payable. In the case of certain events of bankruptcy, insolvency or reorganization relating to us or a significant subsidiary, the principal amount of the 2026 Notes together with any accrued interest will become immediately due and payable. 67 Table of Contents In December 2023, we entered into privately negotiated agreements with certain holders of our 2026 Notes to repurchase $ 159.8 million aggregate principal amount of the 2026 Notes (the “2026 Notes Repurchases”) for 1.5 million shares of our common stock and aggregate cash payments of $ 229.7 million, plus accrued and unpaid cash interest of $ 3.8 million. We recognized pre-tax inducement charges of $ 37.4 million for the 2026 Notes Repurchases, representing the total settlement value in excess of the total conversion value of the 2026 Notes Repurchases when the final negotiated offers were accepted. These charges are reflected in “Loss on extinguishment of long-term debt” in the accompanying consolidated statements of operations. The conversion value paid in excess of the carrying amount of the 2026 Notes Repurchases is reflected in “Common stock” in the shareholders’ equity section of the accompanying consolidated balance sheet. Concurrently with the 2026 Notes Repurchases, we entered into agreements with the 2026 Capped Calls counterparties to terminate a proportionate amount of the 2026 Capped Calls and received $ 15.6 million in cash proceeds for the termination (Note 9). In January 2024, we issued a notice for the redemption of the remaining $ 40.0 million aggregate principal amount of the 2026 Notes to be settled March 20, 2024. The redemption price, which consists of the principal amount and the make-whole premium, plus accrued and unpaid interest, is required to be settled in cash. Holders can convert their 2026 Notes prior to the redemption date, and any conversion thereof will be settled in cash. The ultimate settlement amount of the 2026 Notes will be dependent on various factors, including the number of notes converted and the volume weighted average trading price of our common stock during the measurement period preceding their settlement. In December 2023, $ 0.2 million aggregate principal amount of the 2026 Notes was tendered for conversion, which is also expected to be cash settled in March 2024. The carrying amount of the remaining 2026 Notes as of December 31, 2023 is reflected in “Current maturities of long-term debt” in the accompanying consolidated balance sheet (see Note 19 for their fair value). MARAD Debt In 2005, Helix’s subsidiary CDI-Title XI issued its U.S. Government Guaranteed Ship Financing Bonds, Q4000 Series, to refinance the construction financing originally granted in 2002 of the Q4000 vessel (the “MARAD Debt”). The MARAD Debt is guaranteed by the U.S. government pursuant to Title XI of the Merchant Marine Act of 1936, administered by the Maritime Administration (“MARAD”). The obligation of CDI-Title XI to reimburse MARAD in the event CDI-Title XI fails to repay the MARAD Debt is collateralized by the Q4000 and is guaranteed 50 % by us. In addition, we have agreed to bareboat charter the Q4000 from CDI-Title XI for so long as the MARAD Debt remains outstanding. The MARAD Debt is payable in equal semi-annual installments through February 2027 and bears interest at a rate of 4.93 %. We believe the agreements relating to the bonds and the terms and conditions of our obligations to MARAD in respect of the MARAD Debt were typical for U.S. government-guaranteed ship financing transactions when they were entered into, including customary restrictions on incurring additional liens on the Q4000 and trading restrictions with respect to the vessel as well as working capital requirements. 2029 Notes On December 1, 2023, we issued $ 300 million aggregate principal amount of Senior Notes due 2029 (the “2029 Notes”). The net proceeds from the issuance of the 2029 Notes were approximately $ 291.1 million, after deducting the purchasers’ discount and debt issuance costs. We used $ 229.7 million of cash proceeds from the offering (excluding accrued interest), together with 1.5 million shares of our common stock, to fund the repurchase of $ 159.8 million aggregate principal amount of the 2026 Notes in December 2023. We intend to use the remainder of the net proceeds from this offering for redemption of the remaining 2026 Notes outstanding and for general corporate purposes, which may include repayment of other indebtedness. The 2029 Notes bear interest at a coupon interest rate of 9.75 % per annum payable semi-annually in arrears on March 1 and September 1 of each year, beginning on March 1, 2024. The 2029 Notes mature on March 1, 2029 unless earlier redeemed or repurchased by us. 68 Table of Contents Prior to March 1, 2026, we may, at our option, redeem the 2029 Notes, in whole or in part, at a price equal to 100 % of the aggregate principal amount of the notes to be redeemed, plus a make-whole premium and accrued and unpaid interest, if any, to, but excluding, the redemption date. On or after March 1, 2026, we may, at our option, redeem the 2029 Notes, in whole or in part, at the redemption prices (expressed as percentages of the principal amount of the notes to be redeemed) set forth below, plus accrued and unpaid interest, if any, to, but excluding, the redemption date. Prior to March 1, 2026, following certain equity offerings we may, at our option, on any one or more occasions, redeem up to 40 % of the 2029 Notes at a price equal to 109.750 % of the aggregate principal amount of the notes to be redeemed, plus accrued and unpaid interest, if any, to, but excluding, the redemption date, in an amount not exceeding the proceeds of such equity offerings. ​ ​ ​ ​ ​ ​ Redemption Year Price 2026 ​ 104.875 % 2027 ​ 102.438 % 2028 and thereafter ​ 100.000 % ​ Upon the occurrence of a Change of Control Triggering Event, as defined in the indenture governing the 2029 Notes, we may be required to make an offer to repurchase all of the notes then outstanding at a price equal to 101 % of the principal amount thereof, plus accrued and unpaid interest, if any, to, but not including, the repurchase date. The indenture governing the 2029 Notes contains customary terms and covenants, including limitations on additional indebtedness, restricted payments, liens, asset sales, transactions with affiliates, mergers and consolidations, designation of unrestricted subsidiaries, and dividend and other restrictions affecting restricted subsidiaries. The 2029 Notes are guaranteed on a senior unsecured basis by the subsidiaries that guarantee the Amended ABL Facility, as well as certain future subsidiaries that guarantee certain of our indebtedness, including the Amended ABL Facility. The 2029 Notes are junior in right of payment to all our existing and future secured indebtedness and obligations and rank equally in right of payment with all our existing and future senior unsecured indebtedness. The 2029 Notes rank senior in right of payment to any of our future subordinated indebtedness and are fully and unconditionally guaranteed by the guarantors described above on a senior basis. Other In accordance with the Amended ABL Facility, the 2026 Notes, the MARAD Debt and the 2029 Notes, we are required to comply with certain covenants, including minimum liquidity and a springing fixed charge coverage ratio (applicable under certain conditions that are currently not applicable) with respect to the Amended ABL Facility and the maintenance of net worth, working capital and debt-to-equity requirements with respect to the MARAD Debt. As of December 31, 2023, we were in compliance with these covenants. The 2023 Notes matured on September 15, 2023. Upon maturity of the 2023 Notes, we paid $ 29.6 million in cash to settle the conversion of $ 29.2 million aggregate principal amount of the notes, plus accrued and unpaid interest. We recorded the conversion value in excess of such principal amount converted to “Common stock” in the accompanying consolidated balance sheet. Notes representing the remaining $ 0.8 million aggregate principal amount of the 2023 Notes were redeemed at par, plus accrued and unpaid interest. The 2023 Notes had a coupon interest rate of 4.125 % per annum and an effective interest rate of 4.8 %. For the years ended December 31, 2023, 2022 and 2021, total interest expense related to the 2023 Notes was $ 1.0 million, $ 1.4 million and $ 1.4 million, respectively, primarily from coupon interest expense. We fully paid the $ 35 million remaining principal amount of the 2022 Notes plus accrued interest by delivering cash upon maturity as of May 1, 2022. The effective interest rate for the 2022 Notes was 4.8 %. For the years ended December 31, 2022 and 2021, total interest expense related to the 2022 Notes was $ 0.6 million and $ 1.7 million, respectively, primarily from coupon interest expense. 69 Table of Contents We previously had a credit agreement (and the amendments made thereafter, collectively the “Credit Agreement”) with a group of lenders led by Bank of America. The Credit Agreement was comprised of a term loan (the “Term Loan”) and a revolving credit facility (the “Revolving Credit Facility”) with a maximum availability of $ 175 million and had a maturity date of December 31, 2021 . Concurrent with our entering into the ABL Facility on September 30, 2021, the Credit Agreement was terminated, the $ 28 million remaining balance of the Term Loan was repaid in full and the letters of credit issued under the Revolving Credit Facility were transferred to the ABL Facility. We had no borrowings under the Revolving Credit Facility. We previously had a credit agreement with a syndicated bank lending group for a term loan (the “Nordea Q5000 Loan”) to finance the construction of the Q5000 . The loan was secured by the Q5000 and its charter earnings. In January 2021, we repaid the remaining principal amount of $ 53.6 million. Scheduled maturities of our long-term debt outstanding as of December 31, 2023 are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 2026 ​ MARAD ​ 2029 ​ ​ ​ ​ Notes Debt Notes Total Less than one year ​ $ 40,199 ​ $ 8,749 ​ $ — $ 48,948 One to two years ​ — ​ 9,186 ​ — ​ 9,186 Two to three years ​ — ​ 9,644 ​ — ​ 9,644 Three to four years ​ — ​ 5,001 ​ — ​ 5,001 Four to five years ​ — ​ — ​ — ​ — Over five years ​ — ​ — ​ 300,000 ​ 300,000 Gross debt ​ 40,199 ​ 32,580 ​ 300,000 ​ 372,779 Unamortized debt discount (1) ​ ​ — ​ ​ — ​ ​ ( 1,404 ) ​ ​ ( 1,404 ) Unamortized debt issuance costs (1) ​ ( 656 ) ​ ( 1,586 ) ​ ( 7,411 ) ​ ( 9,653 ) Total debt ​ 39,543 ​ 30,994 ​ 291,185 ​ 361,722 Less current maturities (2) ​ ( 39,543 ) ​ ( 8,749 ) ​ — ​ ( 48,292 ) Long-term debt ​ $ — ​ $ 22,245 ​ $ 291,185 $ 313,430 (1) Debt discount and debt issuance costs are amortized to interest expense over the term of the applicable debt agreement. (2) Current maturities of the 2026 Notes reflect the carrying amount of the remaining 2026 Notes that are subject to conversion and/or redemption in 2024 (see Note 19 for their fair value). ​ The following table details the components of our net interest expense (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 2022 2021 Interest expense ​ $ 21,359 ​ $ 20,176 ​ $ 23,489 Interest income ​ ​ ( 4,021 ) ​ ​ ( 1,226 ) ​ ​ ( 288 ) Net interest expense ​ $ 17,338 ​ $ 18,950 ​ $ 23,201 ​ ​ Note 8 — Income Taxes We operate in multiple jurisdictions with complex tax laws subject to interpretation and judgment. We believe that our application of such laws and the tax impact thereof are reasonable and fairly presented in our consolidated financial statements. 70 Table of Contents Components of income tax provision (benefit) reflected in the consolidated statements of operations consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 2022 2021 Current tax provision (benefit): ​ ​ ​ ​ ​ ​ ​ ​ ​ Domestic ​ $ 1,510 ​ $ — ​ $ ( 1,103 ) Foreign ​ 5,310 ​ 8,217 ​ 7,347 Total current ​ $ 6,820 ​ $ 8,217 ​ $ 6,244 Deferred tax provision (benefit): ​ ​ ​ ​ ​ ​ ​ ​ ​ Domestic ​ $ 8,689 ​ $ 1,167 ​ $ ( 5,756 ) Foreign ​ 2,843 ​ 3,219 ​ ( 9,446 ) Total deferred ​ $ 11,532 ​ $ 4,386 ​ $ ( 15,202 ) Total income tax provision (benefit) ​ $ 18,352 ​ $ 12,603 ​ $ ( 8,958 ) ​ Components of income (loss) before income taxes are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 2022 2021 Domestic ​ $ ( 31,646 ) ​ $ ( 13,745 ) ​ $ ( 53,989 ) Foreign ​ 39,160 ​ ( 61,436 ) ​ ( 16,653 ) Income (loss) before income taxes ​ $ 7,514 ​ $ ( 75,181 ) ​ $ ( 70,642 ) ​ The primary differences between the income tax provision (benefit) at the U.S. statutory rate and our actual income tax provision (benefit) are as follows (dollars in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 2022 2021 Taxes at U.S. statutory rate ​ $ 1,578 21.0 % $ ( 15,788 ) 21.0 % $ ( 14,835 ) 21.0 % Foreign tax provision ​ 1,590 21.2 ​ 18,011 ( 24.0 ) ​ 10,326 ( 14.6 ) ​ Change in valuation allowance ​ ​ 6,374 ​ 84.8 ​ ​ 8,110 ​ ( 10.8 ) ​ ​ ( 5,675 ) ​ 8.0 ​ Non-deductible expenses ​ ​ 2,926 ​ 38.9 ​ ​ 2,366 ​ ( 3.1 ) ​ ​ 1,487 ​ ( 2.1 ) ​ Extinguishment of long-term debt (1) ​ ​ 6,372 ​ 84.8 ​ ​ — ​ — ​ ​ — ​ — ​ Other ​ ( 488 ) ( 6.5 ) ​ ( 96 ) 0.1 ​ ( 261 ) 0.4 ​ Income tax provision (benefit) ​ $ 18,352 244.2 % $ 12,603 ( 16.8 ) % $ ( 8,958 ) 12.7 % (1) Primarily relates to the non-deductibility for U.S. federal income tax purposes of certain charges associated with the 2026 Notes Repurchases (Note 7). ​ For the year ended December 31, 2023, the valuation allowance increased by $ 59.0 million, which included a $ 51.4 million increase for a change in assessment of our Luxembourg net operating losses, and a $ 7.6 million increase in valuation allowance, which was predominantly driven by current year activity, including adjustments to prior year returns. Due to changes in the Luxembourg taxation of our Brazilian operations during the year, the assessment on the realizability of our Luxembourg net operating losses changed from remote to not more likely than not. Therefore, a deferred tax asset and corresponding valuation allowance have been recorded accordingly. For the year ended December 31, 2022, the $ 8.1 million increase in valuation allowance was predominantly driven by current year activity and the related change in unrealizable net deferred tax assets. During the year ended December 31, 2021, we released a non-U.S. valuation allowance of $ 5.0 million for deferred tax assets as it is more likely than not that they will be fully utilized. 71 Table of Contents Deferred income taxes result from the effect of transactions that are recognized in different periods for financial and tax reporting purposes. The nature of these differences and the income tax effect of each are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ ​ 2023 2022 Deferred tax liabilities: ​ ​ ​ ​ Depreciation ​ $ 132,178 ​ $ 147,302 Prepaid and other ​ ​ 1,560 ​ ​ 1,868 Total deferred tax liabilities ​ $ 133,738 ​ $ 149,170 Deferred tax assets: ​ ​ Net operating losses ​ $ ( 78,250 ) ​ $ ( 53,136 ) Reserves, accrued liabilities and other ​ ( 26,048 ) ​ ( 19,308 ) Total deferred tax assets ​ ( 104,298 ) ​ ( 72,444 ) Valuation allowance ​ 81,115 ​ 22,157 Net deferred tax liabilities ​ $ 110,555 ​ $ 98,883 ​ At December 31, 2023, our U.S. tax attributes included $ 35.6 million of net operating losses, which do not expire, and $ 3.0 million in tax credits, which are subject to a full valuation allowance. At December 31, 2023, our non-U.S. net operating losses totaled $ 280.6 million, which included $ 217.5 million net operating losses in Luxembourg, and $ 63.1 million net operating losses in U.K. and Brazil, which do not expire under local tax law. At December 31, 2023, we had accumulated undistributed earnings generated by our non-U.S. subsidiaries of approximately $ 79.1 million. With the enactment of the U.S. Tax Cuts and Jobs Act in 2017, repatriations of foreign earnings are generally free of U.S. federal income taxation. For the year ended December 31, 2023, we released our remaining reserve for uncertain tax positions of $ 0.1 million, which related to a research and development credit taken on our 2019 U.S. Federal Income Tax Return. We file tax returns in the U.S. and in various state, local and non-U.S. jurisdictions. We anticipate that any potential adjustments to our state, local and non-U.S. jurisdiction tax returns by taxing authorities would not have a material impact on our financial position. The tax periods from 2020 through 2023 are open to review and examination by the U.S. Internal Revenue Service. In non-U.S. jurisdictions, the open tax periods include 2019 through 2023. ​ Note 9 — Shareholders’ Equity Our amended and restated Articles of Incorporation provide for authorized Common Stock of 240,000,000 shares with no stated par value per share and 5,000,000 shares of preferred stock, $ 0.01 par value per share, issuable in one or more series. In connection with the 2026 Notes offering (Note 7), we entered into the 2026 Capped Calls with three separate option counterparties. The 2026 Capped Calls were initially for an aggregate of 28,675,900 shares of our common stock, which corresponded to the shares into which the 2026 Notes were initially convertible. The capped call shares are subject to certain anti-dilution adjustments. Each capped call option has an initial strike price of approximately $ 6.97 per share, which corresponds to the initial conversion price of the 2026 Notes, and an initial cap price of approximately $ 8.42 per share. The 2026 Capped Calls are intended to offset some or all of the potential dilution to Helix common shares or increases to the economic cost caused by any conversion of the 2026 Notes up to the cap price. The 2026 Capped Calls can be settled in either net shares or cash at our option in components commencing December 15, 2025 and ending February 12, 2026, which could be extended under certain circumstances. The 2026 Capped Calls strike and cap prices are subject to adjustment and the 2026 Capped Calls are subject to termination upon the occurrence of specified extraordinary events affecting Helix, including a merger, tender offer, nationalization, insolvency or delisting. In addition, certain events may result in a termination of the 2026 Capped Calls, including changes in law, insolvency filings and hedging disruptions. The 2026 Capped Calls were initially recorded at their aggregate cost of $ 10.6 million as a reduction to “Common stock” in the shareholders’ equity section of our consolidated balance sheets. 72 Table of Contents Concurrently with the 2026 Notes Repurchases in December 2023 (Note 7), we entered into agreements with each of the counterparties to terminate a proportionate amount of the 2026 Capped Calls (the “2026 Capped Calls Terminations”). Upon entering into the 2026 Capped Calls Terminations, we recorded the $ 14.2 million fair value of the terminated 2026 Capped Calls to “Derivative assets” with a corresponding increase in “Common stock” as those capped calls no longer qualified for equity classification. The derivative assets were subsequently marked to market to the cash settlement amount of $ 15.6 million with the changes reported in “Loss on extinguishment of long-term debt” in the accompanying consolidated statements of operations. ​ Note 10 — Share Repurchase Programs During 2023, we repurchased a total of 1,584,045 shares of our common stock for approximately $ 12.0 million or an average of $ 7.57 per share pursuant to a share repurchase program (the “2023 Repurchase Program”) authorized by our Board of Directors (our “Board”) in February 2023. Under the 2023 Repurchase Program, we are authorized to repurchase up to $ 200 million issued and outstanding shares of our common stock. Concurrent with the authorization of the 2023 Repurchase Program, our Board revoked the prior authorization to repurchase shares of our common stock in an amount equal to any equity issued to our employees, officers and directors under our share-based compensation plans, including share-based awards under our existing long-term incentive plans and shares issued to our employees under our Employee Stock Purchase Plan (the “ESPP”) (Note 13). The 2023 Repurchase Program has no set expiration date. Repurchases under the 2023 Repurchase Program have been made through open market purchases in compliance with Rule 10b-18 under the Exchange Act, but may also be made through 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 at its discretion based on an evaluation of market conditions, stock price, liquidity and other factors. The 2023 Repurchase 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. Any repurchased shares are expected to be cancelled. ​ Note 11 — Revenue from Contracts with Customers Disaggregation of Revenue The following table provides information about disaggregated revenue by contract duration (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Well ​ ​ ​ Shallow Water ​ Production ​ Intercompany ​ Total ​ Intervention Robotics Abandonment Facilities Eliminations Revenue ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year ended December 31, 2023 ​ ​ ​ ​ ​ Short-term ​ $ 443,332 ​ $ 133,740 ​ $ 241,416 ​ $ — ​ $ ( 3,441 ) ​ $ 815,047 Long-term ​ 289,429 ​ 124,135 ​ 33,538 ​ 87,885 ​ ( 60,306 ) ​ 474,681 Total ​ $ 732,761 ​ $ 257,875 ​ $ 274,954 ​ $ 87,885 ​ $ ( 63,747 ) ​ $ 1,289,728 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year ended December 31, 2022 ​ ​ ​ ​ ​ Short-term ​ $ 395,867 ​ $ 97,533 ​ $ 124,810 ​ $ — ​ $ ( 635 ) ​ $ 617,575 Long-term ​ 128,374 ​ 94,388 ​ — ​ 82,315 ​ ( 49,552 ) ​ 255,525 Total ​ $ 524,241 ​ $ 191,921 ​ $ 124,810 ​ $ 82,315 ​ $ ( 50,187 ) ​ $ 873,100 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year ended December 31, 2021 ​ ​ ​ ​ ​ Short-term ​ $ 308,734 ​ $ 89,668 ​ $ — ​ $ — ​ $ ( 627 ) ​ $ 397,775 Long-term ​ 207,830 ​ 47,627 ​ — ​ 69,348 ​ ( 47,852 ) ​ 276,953 Total ​ $ 516,564 ​ $ 137,295 ​ $ — ​ $ 69,348 ​ $ ( 48,479 ) ​ $ 674,728 ​ 73 Table of Contents Contract Balances Contract assets are rights to consideration in exchange for services that we have provided to a customer when those rights are conditioned on our future performance. Contract assets generally consist of (i) demobilization fees recognized ratably over the contract term but invoiced upon completion of the demobilization activities and (ii) revenue recognized in excess of the amount billed to the customer for lump sum contracts when the cost-to-cost method of revenue recognition is utilized. Contract assets are reflected in “Other current assets” in the accompanying consolidated balance sheets (Note 4). Contract assets as of December 31, 2023 and 2022 were $ 5.8 million and $ 6.3 million, respectively. We had no credit losses on our contract assets for the years ended December 31, 2023, 2022 and 2021. Contract liabilities are obligations to provide future services to a customer for which we have already received, or have the unconditional right to receive, the consideration for those services from the customer. Contract liabilities may consist of (i) advance payments received from customers, including upfront mobilization fees allocated to a single performance obligation and recognized ratably over the contract term and/or (ii) amounts billed to the customer in excess of revenue recognized for lump sum contracts when the cost-to-cost method of revenue recognition is utilized. Contract liabilities are reflected as “Deferred revenue,” a component of “Accrued liabilities” in the accompanying consolidated balance sheets (Note 4). Contract liabilities as of December 31, 2023 and 2022 totaled $ 32.8 million and $ 10.0 million, respectively. Revenue recognized for the years ended December 31, 2023, 2022 and 2021 included $ 8.7 million, $ 7.4 million and $ 7.9 million, respectively, that were included in the contract liability balance as the beginning of each period. We report the net contract asset or contract liability position on a contract-by-contract basis at the end of each reporting period. Performance Obligations As of December 31, 2023, $ 849.9 million related to unsatisfied performance obligations was expected to be recognized as revenue in the future, with $ 700.1 million, $ 128.9 million and $ 20.9 million in 2024 , 2025 and 2026 , respectively. These amounts include fixed consideration and estimated variable consideration for both wholly and partially unsatisfied performance obligations, including mobilization and demobilization fees. These amounts are derived from the specific terms of our contracts, and the expected timing for revenue recognition is based on the estimated start date and duration of each contract according to the information known at December 31, 2023. For the years ended December 31, 2023 and 2021, revenues recognized from performance obligations satisfied (or partially satisfied) in previous years were immaterial. For the year ended December 31, 2022, revenues recognized from performance obligations satisfied (or partially satisfied) in previous years were $ 1.0 million, which resulted from the retrospective application of certain contractual adjustments. Contract Fulfillment Costs Contract fulfillment costs consist of costs incurred in fulfilling a contract with a customer. Our contract fulfillment costs primarily relate to costs incurred for mobilization of personnel and equipment at the beginning of a contract and costs incurred for demobilization at the end of a contract. Mobilization costs are deferred and amortized ratably over the contract term (including anticipated contract extensions) based on the pattern of the provision of services to which the contract fulfillment costs relate. Demobilization costs are recognized when incurred at the end of the contract. Deferred contract costs are reflected as “Deferred costs,” a component of “Other current assets” and “Other assets, net” in the accompanying consolidated balance sheets (Note 4). Our deferred contract costs as of December 31, 2023 and 2022 totaled $ 36.6 million and $ 20.4 million, respectively. For the years ended December 31, 2023, 2022 and 2021, we recorded $ 43.2 million, $ 29.7 million and $ 39.1 million, respectively, related to amortization of deferred contract costs. There were no material impairment losses on deferred contract costs for any period presented. ​ 74 Table of Contents Note 12 — Earnings Per Share The computations of the numerator (earnings or loss) and denominator (shares) to derive the basic and diluted EPS amounts presented on the face of the accompanying consolidated statements of operations are as follows (in thousands, except per share amounts): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 ​ 2022 2021 ​ Income Shares Income Shares Income Shares Basic and Diluted: ​ ​ ​ ​ Net loss attributable to common shareholders ​ $ ( 10,838 ) ​ ​ $ ( 87,784 ) ​ $ ( 61,538 ) Less: Accretion of redeemable noncontrolling interests ​ — ​ ​ ​ — ​ ​ ( 241 ) Net loss available to common shareholders ​ $ ( 10,838 ) ​ 150,917 ​ $ ( 87,784 ) 151,276 ​ $ ( 61,779 ) 150,056 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Loss per share ​ $ ( 0.07 ) ​ ​ ​ $ ( 0.58 ) ​ ​ ​ $ ( 0.41 ) ​ ​ ​ We had net losses for the years ended December 31, 2023, 2022 and 2021. Accordingly, our diluted EPS calculation for these periods excluded the dilutive effect of share-based awards because they were deemed to be anti-dilutive, meaning their inclusion would have reduced the reported net loss per share in the applicable periods. Shares that otherwise would have been included in the diluted per share calculations assuming we had earnings are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2023 2022 2021 Diluted shares (as reported) 150,917 ​ 151,276 ​ 150,056 Share-based awards 3,154 ​ 2,158 ​ 1,282 Total 154,071 ​ 153,434 ​ 151,338 ​ The following potentially dilutive shares related to the 2022 Notes, the 2023 Notes and the 2026 Notes were excluded from the diluted EPS calculation as they were anti-dilutive (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 2022 2021 2022 Notes ​ — ​ 600 ​ 2,519 2023 Notes ​ 2,247 ​ 3,168 ​ 3,168 2026 Notes ​ 28,139 ​ 28,676 ​ 28,676 ​ We have outstanding RSUs (Note 13) that can be settled in either cash or shares of our common stock or a combination thereof, which are not included in the computation of diluted EPS as cash settlement is assumed. ​ Note 13 — Employee Benefit Plans Long-Term Incentive Plan We currently have one active long-term incentive plan, the 2005 Long-Term Incentive Plan, as amended and restated (the “2005 Incentive Plan”). The 2005 Incentive Plan is administered by the Compensation Committee of our Board (the “Compensation Committee”). The Compensation Committee also determines the type of award to be made to each recipient and, as set forth in the related award agreement, the terms, conditions and limitations applicable to each award. The Compensation Committee may grant various forms of award in accordance with the 2005 Incentive Plan. Awards that have been granted to employees under the 2005 Incentive Plan have a vesting period of three years (or 33 % per year) with the exception of PSUs, which vest in amounts in accordance with their terms on the third anniversary date of the grant. 75 Table of Contents The 2005 Incentive Plan currently has 17.3 million shares authorized for issuance, which includes a maximum of 2.0 million shares that may be granted as incentive stock options. As of December 31, 2023, there were approximately 3.4 million shares of our common stock available for issuance under the 2005 Incentive Plan and no incentive stock options are currently outstanding. The following grants of share-based awards were made in 2023 under the 2005 Incentive Plan: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Grant Date ​ ​ ​ ​ ​ ​ ​ ​ Fair Value ​ ​ Date of Grant Award Type Shares/Units Per Share/Unit Vesting Period/Vesting Date January 1, 2023 (1) RSU 506,436 ​ $ 7.38 33 % per year over three years January 3, 2023 (1) PSU 489,498 ​ $ 9.26 100 % on December 31, 2025 January 1, 2023 (2) Restricted stock 9,210 ​ $ 7.38 100 % on January 1, 2025 April 1, 2023 (2) Restricted stock 7,267 ​ $ 7.74 100 % on January 1, 2025 July 1, 2023 (2) Restricted stock 7,622 ​ $ 7.38 100 % on January 1, 2025 October 1, 2023 (2) Restricted stock 5,076 ​ $ 11.17 100 % on January 1, 2025 December 6, 2023 (2) Restricted stock 119,049 ​ $ 8.82 100 % on December 6, 2024 (1) Reflects grants to our executive officers. (2) Reflects grants to certain independent members of our Board. ​ In January 2024, we granted certain officers 375,730 RSUs and 351,410 PSUs under the 2005 Incentive Plan. The grant date fair value of the RSUs was $ 10.28 per unit or $ 3.9 million. The grant date fair value of the PSUs was $ 12.30 per unit or $ 4.3 million. PSUs and RSUs issued in 2024 are payable in either cash or stock, or a combination thereof, at the discretion of the Compensation Committee. Also in January 2024, we granted $ 6.1 million of fixed value cash awards to select management employees under the 2005 Incentive Plan. Restricted Stock Awards We grant restricted stock to members of our Board and from time to time our executive officers and select management employees. The following table summarizes information about our restricted stock: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 ​ 2022 ​ 2021 ​ ​ ​ ​ Grant Date ​ ​ ​ Grant Date ​ ​ ​ Grant Date ​ Shares Fair Value (1) Shares Fair Value (1) Shares Fair Value (1) Awards outstanding at beginning of year 387,628 ​ $ 6.70 853,726 ​ $ 5.62 1,176,951 ​ $ 6.61 Granted 148,224 ​ 8.68 253,358 ​ 5.33 332,841 ​ 3.59 Vested (2) ( 342,723 ) ​ 7.10 ( 719,456 ) ​ 4.94 ( 656,066 ) ​ 6.35 Awards outstanding at end of year 193,129 ​ $ 7.52 387,628 ​ $ 6.70 853,726 ​ $ 5.62 (1) Represents the weighted average grant date fair value, which is based on the quoted closing market price of our common stock on the trading day prior to the date of grant. (2) Total fair value of restricted stock that vested during the years ended December 31, 2023, 2022 and 2021 was $ 2.9 million, $ 2.9 million and $ 2.6 million, respectively. ​ For the years ended December 31, 2023, 2022 and 2021, $ 1.3 million, $ 2.5 million and $ 3.3 million, respectively, were recognized as share-based compensation related to restricted stock. Future compensation cost associated with unvested restricted stock at December 31, 2023 totaled approximately $ 1.2 million. The weighted average vesting period related to unvested restricted stock at December 31, 2023 was approximately 0.7 years. 76 Table of Contents PSU Awards Our PSUs granted prior to 2021 were settled solely in shares of our common stock and were accounted for as equity awards. Our PSUs granted beginning in January 2021 may be settled in either cash or shares of our common stock, or a combination thereof, upon vesting at the discretion of the Compensation Committee and have been accounted for as equity awards. Those PSUs consist of two components: (i) 50 % based on the performance of our common stock against peer group companies, which component contains a service and a market condition, and (ii) 50 % based on cumulative total Free Cash Flow, which component contains a service and a performance condition. Free Cash Flow is calculated as cash flows from operating activities less capital expenditures, net of proceeds from sale of assets. Our PSUs cliff vest at the end of a three-year period with the maximum amount of the award being 200 % of the original PSU awards and the minimum amount being zero . The following table summarizes information about our PSU awards: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 ​ 2022 ​ 2021 ​ ​ ​ ​ Grant Date ​ ​ ​ Grant Date ​ ​ ​ Grant Date ​ Units Fair Value (1) Units Fair Value (1) Units Fair Value (1) PSU awards outstanding at beginning of year 1,888,024 ​ $ 6.25 1,381,469 ​ $ 8.34 1,297,126 ​ $ 9.99 Granted 489,498 ​ 9.26 1,065,705 ​ 4.25 452,381 ​ 5.33 Vested ( 369,938 ) ​ 13.15 ( 559,150 ) ​ 7.60 ( 368,038 ) ​ 10.44 PSU awards outstanding at end of year 2,007,584 ​ $ 5.71 1,888,024 ​ $ 6.25 1,381,469 ​ $ 8.34 (1) Represents the weighted average grant date fair value. ​ For the years ended December 31, 2023, 2022 and 2021, $ 4.8 million, $ 4.8 million and $ 4.1 million, respectively, were recognized as share-based compensation related to PSUs. Future compensation cost associated with unvested PSU awards at December 31, 2023 totaled approximately $ 5.4 million. The weighted average vesting period related to unvested PSUs at December 31, 2023 was approximately 1.0 year. PSUs granted in 2021 are expected to vest at a 181 % performance factor in March 2024 once the Free Cash Flow payout factor is finalized, representing an estimated 818,810 shares of our common stock. In January 2023, 369,938 PSUs granted in 2020 vested at a 77 % performance factor, representing 285,778 shares of our common stock with a total market value of $ 3.6 million. In January 2022, 559,150 PSUs granted in 2019 vested at a 157 % performance factor, representing 876,469 shares of our common stock with a total market value of $ 3.2 million. RSU Awards Our currently outstanding RSUs may be settled in either cash or shares of our common stock, or a combination thereof, upon vesting at the discretion of the Compensation Committee and have been accounted for as liability awards. The following table summarizes information about our RSU awards: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 ​ 2022 ​ 2021 ​ ​ ​ ​ Grant Date ​ ​ ​ Grant Date ​ ​ ​ Grant Date ​ Units Fair Value (1) Units Fair Value (1) Units Fair Value (1) RSU awards outstanding at beginning of year 1,367,294 ​ $ 3.36 452,381 ​ $ 4.20 — ​ $ — Granted 506,436 ​ 7.38 1,065,705 ​ 3.12 452,381 ​ 4.20 Vested ( 506,028 ) ​ 3.44 ( 150,792 ) ​ 4.20 — ​ — RSU awards outstanding at end of year 1,367,702 ​ $ 4.82 1,367,294 ​ $ 3.36 452,381 ​ $ 4.20 (1) Represents the weighted average grant date fair value, which is based on the quoted closing market price of our common stock on the trading day prior to the date of grant. ​ 77 Table of Contents Compensation cost recognized for the years ended December 31, 2023, 2022 and 2021 was $ 6.8 million and $ 3.7 million and $ 0.5 million, respectively, which approximated the fair value of RSUs vested in January 2024, 2023 and 2022, respectively. Future compensation cost based on the fair value of unvested RSUs at December 31, 2023 totaled approximately $ 7.1 million. The weighted average vesting period related to unvested RSUs at December 31, 2023 was approximately 1.3 years. Cash Awards In 2023, 2022 and 2021, we granted fixed value cash awards of $ 6.0 million, $ 5.5 million and $ 3.5 million, respectively, to select management employees under the 2005 Incentive Plan. The value of these cash awards is recognized on a straight-line basis over a vesting period of three years . For the years ended December 31, 2023, 2022 and 2021, we recognized compensation costs of $ 4.5 million and $ 4.3 million and $ 4.0 million, respectively, which reflect the cash payouts made in January 2024, 2023 and 2022, respectively. Defined Contribution Plans We sponsor a defined contribution 401(k) retirement plan in the U.S. We also contribute to various other defined contribution plans globally. For the years ended December 31, 2023, 2022 and 2021, we made contributions to our defined contribution plans totaling $ 4.3 million, $ 3.0 million and $ 1.3 million, respectively. Employee Stock Purchase Plan As of December 31, 2023, 1.2 million shares were available for issuance under the ESPP. Eligible employees who participate in the ESPP may purchase shares of our common stock through payroll deductions on an after-tax basis over a four-month period beginning on January 1, May 1, and September 1 of each year during the term of the ESPP, subject to certain restrictions and limitations established by the Compensation Committee and Section 423 of the Internal Revenue Code. The per share price of common stock purchased under the ESPP is equal to 85 % of the lesser of its fair market value on (i) the first trading day of the purchase period or (ii) the last trading day of the purchase period. The ESPP currently has a purchase limit of 260 shares per employee per purchase period. ​ Note 14 — Business Segment Information We have four reportable business segments: Well Intervention, Robotics, Shallow Water Abandonment and Production Facilities. Our U.S., U.K. and Brazil Well Intervention operating segments are aggregated into the Well Intervention segment for financial reporting purposes. We formed the Shallow Water Abandonment segment in the third quarter 2022 following the Alliance acquisition (Note 3). All material intercompany transactions between the segments have been eliminated. See Note 1 for more information on our business segments. We evaluate our performance based on operating income of each reportable segment. Certain financial data by reportable segment are summarized as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 2022 2021 Net revenues — ​ ​ ​ ​ Well Intervention ​ $ 732,761 ​ $ 524,241 ​ $ 516,564 Robotics ​ 257,875 ​ 191,921 ​ 137,295 Shallow Water Abandonment ​ ​ 274,954 ​ ​ 124,810 ​ ​ — Production Facilities ​ 87,885 ​ 82,315 ​ 69,348 Intercompany eliminations ​ ( 63,747 ) ​ ( 50,187 ) ​ ( 48,479 ) Total ​ $ 1,289,728 ​ $ 873,100 ​ $ 674,728 ​ 78 Table of Contents ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 2022 2021 Income (loss) from operations — ​ ​ ​ Well Intervention ​ $ 32,398 ​ $ ( 53,056 ) ​ $ ( 35,882 ) Robotics ​ 52,450 ​ 29,981 ​ 5,762 Shallow Water Abandonment ​ ​ 66,240 ​ ​ 22,184 ​ ​ — Production Facilities ​ 20,832 ​ 27,201 ​ 22,906 Segment operating income (loss) ​ 171,920 ​ 26,310 ​ ( 7,214 ) Change in fair value of contingent consideration ​ ​ ( 42,246 ) ​ ​ ( 16,054 ) ​ ​ — Corporate, eliminations and other ​ ( 66,164 ) ​ ( 55,111 ) ​ ( 41,473 ) Total ​ $ 63,510 ​ $ ( 44,855 ) ​ $ ( 48,687 ) Net interest expense ​ ​ ( 17,338 ) ​ ​ ( 18,950 ) ​ ​ ( 23,201 ) Other non-operating income (expense), net ​ ​ ( 38,658 ) ​ ​ ( 11,376 ) ​ ​ 1,246 Income (loss) before income taxes ​ $ 7,514 ​ $ ( 75,181 ) ​ $ ( 70,642 ) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Capital expenditures — ​ ​ ​ ​ ​ ​ ​ ​ ​ Well Intervention ​ $ 7,763 ​ $ 17,617 ​ $ 2,349 Robotics ​ 3,957 ​ 15,603 ​ 120 Shallow Water Abandonment ​ ​ 6,890 ​ ​ 532 ​ ​ — Production Facilities ​ — ​ ( 1,424 ) ​ 6,770 Corporate, eliminations and other ​ 978 ​ 1,176 ​ ( 917 ) Total ​ $ 19,588 ​ $ 33,504 ​ $ 8,322 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Depreciation and amortization — ​ ​ ​ ​ ​ ​ ​ ​ ​ Well Intervention ​ $ 113,025 ​ $ 103,952 ​ $ 107,551 Robotics ​ 9,604 ​ 12,209 ​ 15,158 Shallow Water Abandonment ​ ​ 20,150 ​ ​ 8,172 ​ ​ — Production Facilities ​ 21,028 ​ 18,520 ​ 19,465 Corporate and eliminations ​ 309 ​ ( 167 ) ​ ( 660 ) Total ​ $ 164,116 ​ $ 142,686 ​ $ 141,514 ​ Intercompany segment amounts are derived primarily from equipment and services provided to other business segments. Intercompany segment revenues are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ ​ 2023 2022 2021 Well Intervention ​ $ 28,396 ​ $ 16,545 ​ $ 21,521 Robotics ​ 35,263 ​ 33,642 ​ 26,958 Shallow Water Abandonment ​ 88 ​ — ​ — Total ​ $ 63,747 ​ $ 50,187 ​ $ 48,479 ​ Revenues by individually significant geographic location are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2023 2022 2021 U.S. ​ $ 644,755 ​ $ 447,205 ​ $ 232,661 North Sea (1) ​ 274,745 ​ 206,647 ​ 129,772 Brazil ​ 177,070 ​ 81,940 ​ 154,326 Asia Pacific ​ ​ 163,957 ​ ​ 43,648 ​ ​ 16,792 West Africa ​ ​ 8,423 ​ ​ 87,488 ​ ​ 126,856 Other ​ 20,778 ​ 6,172 ​ 14,321 Total ​ $ 1,289,728 ​ $ 873,100 ​ $ 674,728 (1) Includes revenues generated from the U.K. of $ 236.2 million, $ 167.0 million and $ 100.2 million, respectively, during the years ended December 31, 2023, 2022 and 2021. ​ 79 Table of Contents Our operational assets work in various regions around the world such as the Gulf of Mexico, Brazil, the North Sea, Asia Pacific and West Africa. The following table provides our property and equipment, net of accumulated depreciation, by individually significant geographic location where those assets are based (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ ​ 2023 2022 U.S. ​ $ 735,406 ​ $ 780,803 U.K. (1) ​ 617,819 ​ 625,001 Brazil (2) ​ 219,624 ​ 235,811 Total ​ $ 1,572,849 ​ $ 1,641,615 (1) Includes the Q7000 and certain other assets that are based in the U.K. but have operated in West Africa and may also operate in the North Sea, Asia Pacific and other regions. (2) Includes the equipment on the Siem Helix 1 chartered vessel and certain other assets that are based in Brazil but have operated in West Africa and may also operate in the North Sea, Asia Pacific and other regions. ​ Segment assets are comprised of all assets attributable to each reportable segment. Corporate and other includes all assets not directly identifiable with our business segments, most notably the majority of our cash and cash equivalents. The following table reflects total assets by reportable segment (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, ​ December 31, ​ 2023 2022 Well Intervention ​ $ 1,790,971 ​ $ 1,796,269 Robotics ​ 177,801 ​ 192,694 Shallow Water Abandonment ​ ​ 256,356 ​ ​ 206,944 Production Facilities ​ 120,234 ​ 136,382 Corporate and other ​ 210,674 ​ 57,049 Total ​ $ 2,556,036 ​ $ 2,389,338 ​ ​ ​ Note 15 — Asset Retirement Obligations Our AROs relate to mature offshore oil and gas properties that we acquired with the intention to perform decommissioning work at the end of their life cycles. In August 2022, we acquired from MP Gulf of Mexico, LLC (“MP GOM”), a joint venture controlled by Murphy Exploration & Production Company – USA, all of MP GOM’s 62.5 % interest in the Thunder Hawk Field, in exchange for the assumption of MP GOM’s abandonment obligations (initially estimated at $ 23.6 million). Our AROs also include P&A costs associated with our Droshky oil and gas properties (Note 4). The following table describes the changes in our AROs (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ 2023 2022 2021 AROs at January 1, ​ $ 51,956 ​ $ 29,658 ​ $ 30,913 Liability incurred during the period ​ ​ — ​ ​ 23,601 ​ ​ — Revisions in estimates ​ 3,257 ​ ( 3,285 ) ​ ( 2,631 ) Accretion expense ​ 6,143 ​ 1,982 ​ 1,376 AROs at December 31, ​ $ 61,356 ​ $ 51,956 ​ $ 29,658 ​ ​ ​ Note 16 — Commitments and Contingencies and Other Matters Commitments Our Well Intervention segment has long-term charter agreements with Siem Offshore AS for the Siem Helix 1 and Siem Helix 2 vessels expiring in February 2025 and February 2027, respectively, with options to extend. Our Robotics segment has vessel charters for the Grand Canyon II , the Grand Canyon III , the Shelia Bordelon , the Glomar Wave and the Horizon Enabler . Our time charter agreements for the Grand Canyon II and Grand Canyon III vessels expire in December 2027 and May 2028, respectively, with options to renew the Grand Canyon III . In January 2023, we entered into a three-year charter agreement for the Glomar Wave in the North Sea with options to extend. In July 2023, we entered into a new agreement to extend the Horizon Enabler charter until December 2025, with further options to extend. 80 Table of Contents In January 2024, the expiration date of our time charter agreement for the Shelia Bordelon in the Gulf of Mexico was extended from June 2024 to June 2026. In February 2024, we extended the vessel charters for the Siem Helix 1 until December 2030 and for the Siem Helix 2 until December 2031. These subsequent extensions increased our vessel charter commitments by $ 559.6 million. Contingencies and Claims From time to time, we may incur losses related to our contracts for matters such as costs in excess of contract consideration or claims related to disputes with customers and any obligations thereon. While we believe we maintain appropriate accruals for such matters, the actual loss to us may be more or less than the amounts reserved. During the fourth quarter 2023, we finalized the calculation and agreed with the seller in the Alliance transaction on an $ 85.0 million earn-out expected to be paid in cash in April 2024 (Note 3). Consequently, any uncertainty related to this liability has been resolved as the payment amount was fixed and the measurement period ended on December 31, 2023. We are involved in various legal proceedings in the normal course of business, including claims under the General Maritime Laws of the United States and the Merchant Marine Act of 1920 (commonly referred to as the Jones Act), contract-related disputes, employee-related disputes and subsequently identified legacy issues related to Alliance. We recognize losses for lawsuits when the probability of an unfavorable outcome is probable and we can reasonably estimate the amount of the loss. For insured claims, we recognize such losses to the extent they exceed applicable insurance coverage. Although we can give no assurance about the outcome of litigation, claims or other proceedings, we do not currently believe that any loss resulting from litigation, claims or other proceedings, to the extent not otherwise covered by insurance, will have a material adverse impact on our consolidated financial statements. ​ Note 17 — Statement of Cash Flow Information The following table provides supplemental cash flow information (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Year Ended December 31, ​ 2023 2022 2021 Interest paid ​ $ 20,984 ​ $ 18,267 ​ $ 20,719 Income taxes paid (1) ​ 7,394 ​ 9,516 ​ 8,310 (1) Exclusive of any income tax refunds. During the years ended December 31, 2022 and 2021, we received refunds related to the U.S. Coronavirus Aid, Relief, and Economic Security Act of $ 1.1 million and $ 18.9 million, respectively. ​ Our capital additions include the acquisition of property and equipment for which payment has not been made. As of December 31, 2023 and 2022, these non-cash capital additions totaled $ 1.1 million and $ 0.4 million, respectively. Non-cash investing and financing activities for the year ended December 31, 2023 included a portion of P&A equipment purchase financed by the seller in the form of credits towards future services offered by us which had an estimated fair value of $ 11.6 million at the time of purchase in the third quarter 2023 (Note 4). Non-cash financing activities for the year ended December 31, 2023 included the issuance of 1.5 million shares of our common stock for the repurchase of a portion of our 2026 Notes. Non-cash investing activities for the year ended December 31, 2022 included $ 26.7 million in estimated fair value of contingent earn-out consideration as of July 1, 2022, the date of the Alliance acquisition (Note 3). ​ 81 Table of Contents Note 18 — Allowance Accounts The following table sets forth the activity in our valuation accounts for each of the three years in the period ended December 31, 2023 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Allowance for ​ Deferred Tax Asset ​ Credit Losses Valuation Allowance Balance at December 31, 2020 ​ $ 3,469 ​ $ 19,722 Additions (reductions) (1) ​ ( 146 ) ​ — Write-offs (2) ​ ​ ( 1,846 ) ​ ​ — Adjustments (3) ​ — ​ ( 5,675 ) Balance at December 31, 2021 ​ ​ 1,477 ​ ​ 14,047 Additions (reductions) (1) ​ ​ 800 ​ ​ — Adjustments (4) ​ ​ — ​ ​ 8,110 Balance at December 31, 2022 ​ ​ 2,277 ​ ​ 22,157 Additions (reductions) (1) (5) ​ 1,149 ​ 51,354 Write-offs (2) ​ ​ ( 19 ) ​ ​ — Adjustments (4) ​ — ​ 7,604 Balance at December 31, 2023 ​ $ 3,407 ​ $ 81,115 (1) The additions (reductions) in allowance for credit losses relate to reserves (releases) for expected credit losses during the respective years. (2) The write-offs of allowance for credit losses reflect certain receivables related to our Robotics segment that were previously reserved and subsequently deemed to be uncollectible. (3) The decrease in valuation allowance primarily relates to the valuation allowance release for certain of our U.K. operations. (4) The increase in valuation allowance relates to current year activity, including adjustments to prior year returns, and the related change in unrealized net deferred tax assets. (5) The addition in valuation allowance relates to the adjustment for a change in assessment on the realizability of our Luxembourg net operating losses from remote to less likely than not. ​ See Note 2 for a detailed discussion regarding our accounting policy on accounts receivable and allowance for credit losses. See Note 8 for a detailed discussion of the valuation allowance related to our deferred tax assets. ​ Note 19 — Fair Value Measurements Our financial instruments include cash and cash equivalents, receivables, accounts payable and long-term debt. The carrying amount of cash and cash equivalents, trade and other current receivables as well as accounts payable approximates fair value due to the short-term nature of these instruments. Contingent consideration liability related to the Alliance acquisition (Note 3) was previously measured at fair value using Level 3 unobservable inputs and determined based on our evaluation of the probability and amount of earn-out that may be achieved based on expected future performance of Helix Alliance. During the fourth quarter 2023, we finalized the calculation and agreed with the seller in the Alliance transaction on an $ 85.0 million earn-out expected to be paid in cash in April 2024. As such, the Alliance earn-out consideration has been reported at $ 85.0 million in the accompanying consolidated balance sheet (Note 4) and was no longer contingent and subject to fair value measurement as of December 31, 2023. The following table sets forth our assets and liabilities that are measured at fair value on a recurring basis by level within the fair value hierarchy as of December 31, 2022 (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Fair Value at December 31, 2022 ​ Level 1 Level 2 Level 3 Total Liabilities: ​ ​ ​ ​ Contingent consideration ​ $ — ​ $ — ​ $ 42,754 ​ $ 42,754 ​ 82 Table of Contents The reconciliation of Level 3 recurring fair value measurements is as follows (in thousands): ​ ​ ​ ​ ​ ​ 2023 Balance at January 1, ​ $ 42,754 Change in fair value ​ ​ 42,246 Transfers out of Level 3 ​ ( 85,000 ) Balance at December 31, ​ $ — ​ The principal amount and estimated fair value of our long-term debt are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ December 31, 2023 ​ December 31, 2022 ​ ​ Principal ​ Fair ​ Principal ​ Fair ​ Amount (1) Value (2) Amount (1) Value (2) 2023 Notes (matured September 2023) ​ $ — ​ $ — ​ $ 30,000 ​ $ 31,149 2026 Notes (mature February 2026) ​ 40,199 ​ 64,117 ​ 200,000 ​ 277,014 MARAD Debt (matures February 2027) ​ ​ 32,580 ​ ​ 32,348 ​ ​ 40,913 ​ ​ 40,940 2029 Notes (mature March 2029) ​ ​ 300,000 ​ ​ 315,987 ​ ​ — ​ ​ — Total debt ​ $ 372,779 ​ $ 412,452 ​ $ 270,913 ​ $ 349,103 (1) Principal amount includes current maturities and excludes any related unamortized debt discount and debt issuance costs. See Note 7 for additional disclosures on our long-term debt. (2) The estimated fair value was determined using Level 2 fair value inputs under the market approach, which was determined using a third-party evaluation of the remaining average life and outstanding principal balance of the indebtedness as compared to other obligations in the marketplace with similar terms. ​ Item 9. Changes in and Disagreements with Accountants on Accounting and Financial Disclosure None. ​