HELIX ENERGY SOLUTIONS GROUP INC 10-Q

Item 1. Financial Statements HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES CONDENSED CONSOLIDATED BALANCE SHEETS (in thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, ​ December 31, ​ 2025 2024 ASSETS ​ ​ Current assets: ​ ​ Cash and cash equivalents ​ $ 338,033 ​ $ 368,030 Accounts receivable, net of allowance for credit losses of $ 3,954 and $ 3,682 , respectively ​ 359,607 ​ 258,630 Other current assets ​ 100,600 ​ 83,022 Total current assets ​ 798,240 ​ 709,682 Property and equipment ​ 3,173,123 ​ 3,068,755 Less accumulated depreciation ​ ( 1,765,891 ) ​ ( 1,630,902 ) Property and equipment, net ​ 1,407,232 ​ 1,437,853 Operating lease right-of-use assets ​ 297,021 ​ 329,649 Deferred recertification and dry dock costs, net ​ ​ 81,869 ​ ​ 71,718 Other assets, net ​ 47,525 ​ 48,178 Total assets ​ $ 2,631,887 ​ $ 2,597,080 ​ ​ ​ ​ ​ ​ ​ LIABILITIES AND SHAREHOLDERS' EQUITY ​ ​ Current liabilities: ​ ​ Accounts payable ​ $ 147,402 ​ $ 144,793 Accrued liabilities ​ 99,248 ​ 90,455 Current maturities of long-term debt ​ 9,644 ​ 9,186 Current operating lease liabilities ​ 57,826 ​ 59,982 Total current liabilities ​ 314,120 ​ 304,416 Long-term debt ​ 297,828 ​ 305,971 Operating lease liabilities ​ 257,159 ​ 285,984 Deferred tax liabilities ​ 117,821 ​ 113,973 Other non-current liabilities ​ 70,084 ​ 66,971 Total liabilities ​ 1,057,012 ​ 1,077,315 Commitments and contingencies ​ ​ ​ ​ ​ ​ Shareholders’ equity: ​ ​ Common stock, no par, 240,000 shares authorized, 147,081 and 150,243 shares issued, respectively ​ 1,221,626 ​ 1,252,253 Retained earnings ​ 390,644 ​ 368,087 Accumulated other comprehensive loss ​ ( 37,395 ) ​ ( 100,575 ) Total shareholders’ equity ​ 1,574,875 ​ 1,519,765 Total liabilities and shareholders’ equity ​ $ 2,631,887 ​ $ 2,597,080 ​ The accompanying notes are an integral part of these condensed consolidated financial statements. ​ 3 Table of Contents HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (UNAUDITED) (in thousands, except per share amounts) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended ​ Nine Months Ended ​ ​ September 30, ​ September 30, ​ 2025 2024 2025 2024 Net revenues ​ $ 376,960 ​ $ 342,419 ​ $ 957,312 ​ $ 1,003,427 Cost of sales ​ 310,941 ​ 276,754 ​ 848,807 ​ 842,722 Gross profit ​ 66,019 ​ 65,665 ​ 108,505 ​ 160,705 Gain (loss) on disposition of assets, net ​ — ​ 100 ​ — ​ ( 50 ) Selling, general and administrative expenses ​ ( 18,168 ) ​ ( 21,125 ) ​ ( 55,634 ) ​ ( 64,098 ) Income from operations ​ 47,851 ​ 44,640 ​ 52,871 ​ 96,557 Net interest expense ​ ( 5,616 ) ​ ( 5,689 ) ​ ( 17,197 ) ​ ( 17,057 ) Losses related to convertible senior notes ​ — ​ — ​ — ​ ( 20,922 ) Other expense, net ​ ( 983 ) ​ ( 49 ) ​ ( 903 ) ​ ( 2,647 ) Royalty income and other ​ — ​ 132 ​ 1,411 ​ 2,132 Income before income taxes ​ 41,252 ​ 39,034 ​ 36,182 ​ 58,063 Income tax provision ​ 19,169 ​ 9,520 ​ 13,625 ​ 22,547 Net income ​ $ 22,083 ​ $ 29,514 ​ $ 22,557 ​ $ 35,516 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Earnings per share of common stock: ​ ​ ​ ​ Basic ​ $ 0.15 ​ $ 0.19 ​ $ 0.15 ​ $ 0.23 Diluted ​ $ 0.15 ​ $ 0.19 ​ $ 0.15 ​ $ 0.23 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Weighted average common shares outstanding: ​ ​ ​ ​ Basic ​ 146,907 ​ 151,914 ​ 148,805 ​ 152,171 Diluted ​ 147,698 ​ 154,851 ​ 149,550 ​ 155,038 ​ The accompanying notes are an integral part of these condensed consolidated financial statements. ​ HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (UNAUDITED) (in thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended ​ Nine Months Ended ​ ​ September 30, ​ September 30, ​ 2025 2024 ​ 2025 2024 Net income ​ $ 22,083 ​ $ 29,514 ​ $ 22,557 $ 35,516 Other comprehensive income (loss) - foreign currency translation gain (loss), net of tax ​ ( 18,133 ) ​ 41,689 ​ 63,180 ​ 35,272 Comprehensive income ​ $ 3,950 ​ $ 71,203 ​ $ 85,737 $ 70,788 ​ The accompanying notes are an integral part of these condensed consolidated financial statements. ​ 4 Table of Contents HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF SHAREHOLDERS’ EQUITY (UNAUDITED) (in thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accumulated ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Other ​ Total ​ ​ Common Stock ​ Retained ​ Comprehensive ​ Shareholders’ ​ Shares Amount Earnings Loss Equity Balance, June 30, 2025 146,986 ​ $ 1,219,477 ​ $ 368,561 ​ $ ( 19,262 ) ​ $ 1,568,776 Net income — ​ — ​ 22,083 ​ — ​ 22,083 Foreign currency translation adjustments — ​ — ​ — ​ ( 18,133 ) ​ ( 18,133 ) Repurchases of common stock — ​ 6 ​ — ​ — ​ 6 Activity in company stock plans, net and other 95 ​ 622 ​ — ​ — ​ 622 Share-based compensation — ​ 1,521 ​ — ​ — ​ 1,521 Balance, September 30, 2025 147,081 ​ $ 1,221,626 ​ $ 390,644 ​ $ ( 37,395 ) ​ $ 1,574,875 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Balance, June 30, 2024 152,051 ​ $ 1,267,768 ​ $ 318,452 ​ $ ( 89,432 ) ​ $ 1,496,788 Net income — ​ — ​ 29,514 ​ — ​ 29,514 Foreign currency translation adjustments — ​ — ​ — ​ 41,689 ​ 41,689 Activity in company stock plans, net and other 50 ​ 901 ​ — ​ — ​ 901 Share-based compensation — ​ 1,678 ​ — ​ — ​ 1,678 Balance, September 30, 2024 152,101 ​ $ 1,270,347 ​ $ 347,966 ​ $ ( 47,743 ) ​ $ 1,570,570 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Accumulated ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Other ​ Total ​ ​ Common Stock ​ Retained ​ Comprehensive ​ Shareholders’ ​ Shares Amount Earnings Loss Equity Balance, December 31, 2024 150,243 ​ $ 1,252,253 ​ $ 368,087 ​ $ ( 100,575 ) ​ $ 1,519,765 Net income — ​ — ​ 22,557 ​ — ​ 22,557 Foreign currency translation adjustments — ​ — ​ — ​ 63,180 ​ 63,180 Repurchases of common stock ( 4,643 ) ​ ( 30,177 ) ​ — ​ — ​ ( 30,177 ) Activity in company stock plans, net and other 1,481 ​ ( 5,014 ) ​ — ​ — ​ ( 5,014 ) Share-based compensation — ​ 4,564 ​ — ​ — ​ 4,564 Balance, September 30, 2025 147,081 ​ $ 1,221,626 ​ $ 390,644 ​ $ ( 37,395 ) ​ $ 1,574,875 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Balance, December 31, 2023 152,291 ​ $ 1,271,565 ​ $ 312,450 ​ $ ( 83,015 ) ​ $ 1,501,000 Net income — ​ — ​ 35,516 ​ — ​ 35,516 Foreign currency translation adjustments — ​ — ​ — ​ 35,272 ​ 35,272 Settlement of convertible debt conversion — ​ ( 84 ) ​ — ​ — ​ ( 84 ) Repurchases of common stock ​ ( 938 ) ​ ​ ( 10,218 ) ​ ​ — ​ ​ — ​ ​ ( 10,218 ) Termination of capped calls — ​ 4,381 ​ — ​ — ​ 4,381 Activity in company stock plans, net and other 748 ​ ( 401 ) ​ — ​ — ​ ( 401 ) Share-based compensation — ​ 5,104 ​ — ​ — ​ 5,104 Balance, September 30, 2024 152,101 ​ $ 1,270,347 ​ $ 347,966 ​ $ ( 47,743 ) ​ $ 1,570,570 ​ The accompanying notes are an integral part of these condensed consolidated financial statements. ​ 5 Table of Contents HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED) (in thousands) ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Nine Months Ended ​ ​ September 30, ​ 2025 2024 Cash flows from operating activities: ​ ​ ​ Net income ​ $ 22,557 ​ $ 35,516 Adjustments to reconcile net income to net cash provided by operating activities: ​ ​ ​ Depreciation and amortization, excluding amortization of deferred recertification and dry dock costs ​ 101,026 ​ 105,532 Amortization of deferred recertification and dry dock costs ​ 42,506 ​ 27,196 Deferred recertification and dry dock costs ​ ​ ( 48,276 ) ​ ​ ( 29,239 ) Payment of earnout consideration ​ ​ — ​ ​ ( 58,300 ) Amortization of debt discount ​ 177 ​ 161 Amortization of debt issuance costs ​ 1,533 ​ 1,611 Share-based compensation ​ 4,941 ​ 5,524 Deferred income taxes ​ 3,819 ​ 13,167 Loss on disposition of assets, net ​ — ​ 50 Losses related to convertible senior notes ​ — ​ 20,922 Unrealized foreign currency gains ​ ( 690 ) ​ ( 1,213 ) Changes in operating assets and liabilities: ​ ​ Accounts receivable, net ​ ( 93,298 ) ​ 12,741 Other current assets ​ ​ ( 900 ) ​ ​ ( 13,778 ) Income tax receivable, net of income tax payable ​ ( 15,175 ) ​ ( 509 ) Accounts payable and accrued liabilities ​ 2,644 ​ ( 14,869 ) Other, net ​ 2,722 ​ 3,539 Net cash provided by operating activities ​ 23,586 ​ 108,051 ​ ​ ​ ​ ​ ​ ​ Cash flows from investing activities: ​ ​ Capital expenditures ​ ( 10,646 ) ​ ( 10,780 ) Proceeds from sale of assets ​ ​ — ​ ​ 100 Proceeds from insurance recoveries ​ — ​ 363 Net cash used in investing activities ​ ( 10,646 ) ​ ( 10,317 ) ​ ​ ​ ​ ​ ​ ​ Cash flows from financing activities: ​ ​ Payments related to convertible senior notes ​ — ​ ( 60,720 ) Repayment of MARAD Debt ​ ( 9,186 ) ​ ( 8,749 ) Proceeds from settlement of capped calls ​ — ​ 4,381 Debt issuance costs ​ — ​ ( 1,453 ) Repurchases of common stock ​ ​ ( 30,214 ) ​ ​ ( 10,189 ) Payments related to tax withholding for share-based compensation ​ ( 7,266 ) ​ ( 4,003 ) Proceeds from issuance of ESPP shares ​ 1,745 ​ 1,859 Payment of earnout consideration ​ ​ — ​ ​ ( 26,700 ) Net cash used in financing activities ​ ( 44,921 ) ​ ( 105,574 ) ​ ​ ​ ​ ​ ​ ​ Effect of exchange rate changes on cash and cash equivalents ​ 1,984 ​ ( 231 ) Net decrease in cash and cash equivalents ​ ( 29,997 ) ​ ( 8,071 ) Cash and cash equivalents: ​ ​ Balance, beginning of year ​ 368,030 ​ 332,191 Balance, end of period ​ $ 338,033 ​ $ 324,120 ​ The accompanying notes are an integral part of these condensed consolidated financial statements. ​ 6 Table of Contents HELIX ENERGY SOLUTIONS GROUP, INC. AND SUBSIDIARIES NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED) ​ Note 1 — Basis of Presentation and New Accounting Standards The accompanying condensed consolidated financial statements include the accounts of Helix Energy Solutions Group, Inc. and its subsidiaries (collectively, “Helix”). Unless the context indicates otherwise, the terms “we,” “us” and “our” in this report refer collectively to Helix and its subsidiaries. All material intercompany accounts and transactions have been eliminated. These unaudited condensed consolidated financial statements in U.S. dollars have been prepared in accordance with instructions for the Quarterly Report on Form 10-Q required to be filed with the Securities and Exchange Commission (the “SEC”) and do not include all information and footnotes normally included in annual financial statements prepared in accordance with accounting principles generally accepted in the U.S. (“GAAP”). The preparation of these financial statements requires us to make estimates and judgments that affect the amounts reported in the financial statements and the related disclosures. Actual results may differ from our estimates. We have made all adjustments, which, unless otherwise disclosed, are of normal recurring nature, that we believe are necessary for a fair presentation of the condensed consolidated balance sheets, statements of operations, statements of comprehensive loss, statements of shareholders’ equity and statements of cash flows, as applicable. The operating results for the three- and nine-month periods ended September 30, 2025 are not necessarily indicative of the results that may be expected for the year ending December 31, 2025. Our balance sheet as of December 31, 2024 included herein has been derived from the audited balance sheet as of December 31, 2024 included in our 2024 Annual Report on Form 10-K (our “2024 Form 10-K”). These unaudited condensed consolidated financial statements should be read in conjunction with the audited annual consolidated financial statements and notes thereto included in our 2024 Form 10-K. 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. New accounting standards In December 2023, the Financial Accounting Standards Board (the “FASB”) issued accounting Standards Update (“ASU”) No. 2023-09, “Improvements to Income Tax Disclosures,” which requires entities to disclose, on an annual basis, specific categories in a tabular rate reconciliation using both percentages and reporting currency amounts and to provide additional information for reconciling items that meet a quantitative threshold. This ASU also requires that entities disclose on an annual basis: a) income taxes paid (net) disaggregated by federal, state and foreign taxes; b) income taxes paid (net) by individual jurisdiction; c) income (or loss) from continuing operations before income tax expense (or benefit) between domestic and foreign; and d) 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 for annual 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 November 2024, the FASB issued ASU No. 2024-03, “Disaggregation of Income Statement Expenses,” which requires entities to disclose, on an annual and interim basis, specified information about certain costs and expenses: a) the amounts of (i) purchases of inventory, (ii) employee compensation, (iii) depreciation, (iv) intangible asset amortization, and (v) depreciation, depletion, and amortization recognized as part of oil and gas-producing activities (or other amounts of depletion expense) included in each relevant expense caption; b) certain amounts that are already required to be disclosed under current GAAP in the same disclosure as the other disaggregation requirements; c) a qualitative description of the amounts remaining in relevant expense captions that are not separately disaggregated quantitatively; and d) the total amount of selling expenses and, in annual periods, an entity’s definition of selling expenses. ASU No. 2024-03 will be effective for us for annual periods beginning January 1, 2027 and for interim periods beginning January 1, 2028. 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. ​ 7 Table of Contents Note 2 — Company Overview 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 decommissioning operations. Our services are key in supporting a global energy transition: ● Production maximization — our assets and methodologies are specifically designed to safely and efficiently enhance and extend the lives of existing oil and gas reserves; ● Decommissioning — we are a full-field abandonment contractor and believe that regulatory push for plug and abandonment (“P&A”) and transition to renewable energy will facilitate the continued growth of the abandonment market; and ● Renewables — we are an established global leader in jet trenching and provide specialty support services to renewable energy developments (primarily offshore wind farms), including boulder removal and unexploded ordnance clearance. We provide a range of services to the oil and gas and renewable energy markets primarily in the Gulf of America (deepwater and shelf), U.S. East Coast, Brazil, North Sea, Asia Pacific and West Africa regions. Our North Sea operations and our Gulf of America shelf operations are usually subject to seasonal changes in activity levels, which generally peak in the summer months and decline in the winter months. Our services are segregated into four reportable business segments: Well Intervention, Robotics, Shallow Water Abandonment 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 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 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, IROV boulder grabs and robotics support vessels under term charters as well as spot vessels as needed. We offer our ROVs, trenchers and IROV boulder grabs 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 America shelf, including offshore oilfield decommissioning and ‎reclamation, well intervention, IRM, heavy lift and commercial diving services. Our Shallow Water Abandonment segment includes Helix Alliance that was acquired in July 2022, a vertically integrated company that offers a diversified fleet of marine assets including liftboats, offshore supply vessels (“OSVs”), dive support vessels (“DSVs”), a heavy lift derrick barge, a crew boat, P&A systems and coiled tubing (“CT”) systems. Our Production Facilities segment includes the Helix Producer I (the “ HP I ”), a ship-shaped dynamically positioned floating production vessel, the Helix Fast Response System (the “HFRS”), which combines our capabilities with certain well control equipment that can be deployed to respond to a well control incident, and our ownership of mature oil and gas properties. All of our current Production Facilities activities are located in the Gulf of America. ​ 8 Table of Contents Note 3 — Details of Certain Accounts Other current assets consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, ​ December 31, ​ 2025 2024 Prepaids ​ $ 39,093 $ 26,780 Income tax receivable ​ ​ 15,154 ​ ​ 2,635 Contract assets (Note 8) ​ ​ 8,759 ​ ​ 12,221 Deferred costs (Note 8) ​ 25,707 ​ 31,874 Other ​ 11,887 ​ 9,512 Total other current assets ​ $ 100,600 $ 83,022 ​ Other assets, net consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, ​ December 31, ​ 2025 2024 Prepaid charter (1) ​ $ 12,544 $ 12,544 Deferred costs (Note 8) ​ ​ 3,428 ​ 5,348 Other receivable (2) ​ 26,653 ​ 24,827 Intangible assets with finite lives, net ​ 3,365 ​ 3,630 Other ​ 1,535 ​ 1,829 Total other assets, net ​ $ 47,525 $ 48,178 (1) Represents prepayments to the owner of the Siem Helix 1 and the Siem Helix 2 , which may be used to offset certain payment obligations associated with the vessels at the end of their respective charter term. (2) Represents the present value of receivables for P&A work to be performed by us on Droshky oil and gas properties we acquired from Marathon Oil Corporation in 2019. ​ Accrued liabilities consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, ​ December 31, ​ 2025 2024 Accrued payroll and related benefits ​ $ 42,890 $ 49,521 Accrued interest ​ ​ 2,607 ​ ​ 10,278 Deferred revenue (Note 8) ​ 31,090 ​ 14,914 Other ​ 22,661 ​ 15,742 Total accrued liabilities ​ $ 99,248 $ 90,455 ​ Other non-current liabilities consist of the following (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, ​ December 31, ​ 2025 2024 Deferred revenue (Note 8) ​ $ — $ 699 Asset retirement obligations (Note 12) ​ ​ 67,266 ​ 62,947 Other ​ 2,818 ​ 3,325 Total other non-current liabilities ​ $ 70,084 $ 66,971 ​ ​ ​ 9 Table of Contents Note 4 — Leases We charter vessels and lease facilities and equipment under non-cancelable contracts that expire on various dates through 2034. The following table details the components of our lease cost (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended ​ Nine Months Ended ​ ​ September 30, ​ September 30, ​ 2025 2024 2025 2024 Operating lease cost ​ $ 23,378 ​ $ 22,643 ​ $ 67,957 $ 65,475 Variable lease cost ​ 4,160 ​ 2,236 ​ 9,192 ​ 8,353 Short-term lease cost ​ 14,920 ​ 18,665 ​ 36,609 ​ 41,324 Sublease income ​ ( 29 ) ​ ( 26 ) ​ ( 87 ) ​ ( 70 ) Net lease cost ​ $ 42,429 ​ $ 43,518 ​ $ 113,671 $ 115,082 ​ Maturities of our operating lease liabilities as of September 30, 2025 are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Facilities and ​ ​ ​ Vessels Equipment Total Less than one year ​ $ 74,427 ​ $ 4,145 $ 78,572 One to two years ​ 65,768 ​ 3,532 ​ 69,300 Two to three years ​ 62,216 ​ 4,132 ​ 66,348 Three to four years ​ 54,059 ​ 3,011 ​ 57,070 Four to five years ​ 52,748 ​ 4,367 ​ 57,115 Over five years ​ 46,804 ​ 12,937 ​ 59,741 Total lease payments ​ $ 356,022 ​ $ 32,124 $ 388,146 Less: imputed interest ​ ( 64,434 ) ​ ( 8,727 ) ​ ( 73,161 ) Total operating lease liabilities ​ $ 291,588 ​ $ 23,397 $ 314,985 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current operating lease liabilities ​ $ 54,325 ​ $ 3,501 $ 57,826 Non-current operating lease liabilities ​ 237,263 ​ 19,896 ​ 257,159 Total operating lease liabilities ​ $ 291,588 ​ $ 23,397 $ 314,985 ​ Maturities of our operating lease liabilities as of December 31, 2024 are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Facilities and ​ ​ ​ Vessels Equipment Total Less than one year ​ $ 78,442 ​ $ 5,324 $ 83,766 One to two years ​ 66,020 ​ 3,442 ​ 69,462 Two to three years ​ 61,771 ​ 3,871 ​ 65,642 Three to four years ​ 55,933 ​ 3,368 ​ 59,301 Four to five years ​ 52,748 ​ 3,185 ​ 55,933 Over five years ​ 86,257 ​ 15,736 ​ 101,993 Total lease payments ​ $ 401,171 ​ $ 34,926 $ 436,097 Less: imputed interest ​ ( 80,564 ) ​ ( 9,567 ) ​ ( 90,131 ) Total operating lease liabilities ​ $ 320,607 ​ $ 25,359 $ 345,966 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Current operating lease liabilities ​ $ 55,643 ​ $ 4,339 $ 59,982 Non-current operating lease liabilities ​ 264,964 ​ 21,020 ​ 285,984 Total operating lease liabilities ​ $ 320,607 ​ $ 25,359 $ 345,966 ​ 10 Table of Contents The following table presents the weighted average remaining lease term and discount rate: ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, ​ December 31, ​ 2025 ​ 2024 Weighted average remaining lease term 5.4 years ​ 5.9 years Weighted average discount rate 7.80 % ​ 7.89 % ​ The following table presents other information related to our operating leases (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Nine Months Ended ​ ​ September 30, ​ 2025 2024 Cash paid for operating lease liabilities ​ $ 66,229 $ 60,042 Right-of-use assets related to new operating lease liabilities (1) ​ 14,776 ​ 213,480 (1) Our operating lease additions are primarily related to the charter for the Trym during the nine-month period ended September 30, 2025, and the charter extensions for the Siem Helix 1 , the Siem Helix 2 , the Grand Canyon II and the Shelia Bordelon during the nine-month period ended September 30, 2024 (Note 13). ​ Note 5 — Long-Term Debt Scheduled maturities of our long-term debt outstanding as of September 30, 2025 are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ MARAD ​ 2029 ​ ​ ​ ​ Debt Notes Total Less than one year ​ $ 9,644 ​ $ — $ 9,644 One to two years ​ 5,001 ​ — ​ 5,001 Two to three years ​ — ​ — ​ — Three to four years ​ — ​ 300,000 ​ 300,000 Gross debt ​ 14,645 ​ 300,000 ​ 314,645 Unamortized debt discount (1) ​ ​ — ​ ​ ( 1,009 ) ​ ​ ( 1,009 ) Unamortized debt issuance costs (1) ​ ( 732 ) ​ ( 5,432 ) ​ ( 6,164 ) Total debt ​ 13,913 ​ 293,559 ​ 307,472 Less current maturities ​ ( 9,644 ) ​ — ​ ( 9,644 ) Long-term debt ​ $ 4,269 ​ $ 293,559 $ 297,828 (1) Debt discount and debt issuance costs are amortized to interest expense over the term of the applicable debt agreement. ​ Below is a summary of our indebtedness: 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 various amendments (collectively, the “Amended ABL Facility”). The Amended ABL Facility provides a $ 120 million asset-based revolving credit line that matures on August 2, 2029 , 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 permits us to request an increase of the facility of up to $ 30 million, subject to certain conditions. 11 Table of Contents 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 $ 55 million sub-limit for the issuance of letters of credit. As of September 30, 2025, we had no borrowings under the Amended ABL Facility, and our available borrowing capacity, based on the borrowing base, totaled $ 94.3 million, net of $ 1.5 million of letters of credit issued and includes $ 2.5 million of cash pledged to the 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 rate (also known as CME Term SOFR as administered by CME Group, Inc.) 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 (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. 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 %. Senior Notes Due 2029 (“2029 Notes”) On December 1, 2023, we issued $ 300 million aggregate principal amount of 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 cash proceeds from the offering to redeem our former Convertible Senior Notes due 2026 (the “2026 Notes”). See details regarding the redemption of the 2026 Notes below. 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. 12 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 may 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. 2026 Notes Redemption 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 in March 2024 (the “2026 Notes Redemptions”). The redemption price consisted of the principal amount and the make-whole premium, plus accrued and unpaid interest. Our redemption notice enabled holders of $ 39.7 million aggregate principal amount of the 2026 Notes to tender their notes for conversion prior to the redemption date, with the remaining $ 0.3 million aggregate principal amount of the notes redeemed. We settled both the conversions and redemptions for an aggregate $ 60.2 million cash in March 2024 and recognized pre-tax losses of $ 20.9 million. These losses are reflected in “Losses related to convertible senior notes” in the accompanying condensed consolidated statement of operations. The 2026 Notes had a coupon interest rate of 6.75 % per annum and an effective interest rate of 7.6 %. For the nine-month period ended September 30, 2024, total interest expense related to the 2026 Notes was $ 0.4 million with coupon interest expense of $ 0.3 million and the amortization of debt issuance costs of $ 0.1 million. In connection with the 2026 Notes offering, we entered into capped call transactions (the “2026 Capped Calls”) with three separate counterparties to hedge the dilution risk of the 2026 Notes. Concurrent with the settlement of the 2026 Notes Redemptions in March 2024, we terminated the remaining 2026 Capped Calls and received $ 4.4 million in cash, recognizing an increase to “Common stock” in the shareholders’ equity section of the accompanying condensed consolidated balance sheets. 13 Table of Contents Other In accordance with the Amended ABL Facility, 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 September 30, 2025, we were in compliance with these covenants. The following table details the components of our net interest expense (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, ​ September 30, ​ 2025 2024 2025 2024 Interest expense ​ $ 8,241 ​ $ 8,414 ​ $ 24,733 $ 25,594 Interest income ​ ( 2,625 ) ​ ( 2,725 ) ​ ( 7,536 ) ​ ( 8,537 ) Net interest expense ​ $ 5,616 ​ $ 5,689 ​ $ 17,197 $ 17,057 ​ ​ Note 6 — 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 condensed consolidated financial statements. On July 4, 2025, the One Big Beautiful Bill Act was passed into law. The legislation provides us with benefits that are temporary in nature with no material impact on our income tax expense or effective tax rate for the three- and nine-month periods ended September 30, 2025. For the three- and nine-month periods ended September 30, 2025, we recorded income tax provision of $ 19.2 million and $ 13.6 million, respectively, resulting in effective tax rates of 46.5 % and 37.7 % respectively. The effective tax rates for these periods were impacted by certain discrete items and the jurisdictional mix of earnings. For the three- and nine-month periods ended September 30, 2024, we recorded income tax provision of $ 9.5 million and $ 22.5 million, respectively, resulting in effective tax rates of 24.4 % and 38.8 %, respectively. The effective rate for the three-month period ended September 30, 2024 was impacted by certain non-deductible expenses and non-creditable foreign income taxes. The effective rate for the nine-month period ended September 30, 2024 was impacted by the non-deductibility of certain losses associated with the 2026 Notes Redemptions, which was characterized as a discrete event. ​ ​ ​ ​ Note 7 — Share Repurchase Programs In February 2023, our Board of Directors (our “Board”) authorized a share repurchase program to repurchase issued and outstanding shares of our common stock up to $ 200 million (the “2023 Repurchase Program”). As of September 30, 2025, approximately $ 128.4 million remained authorized for the repurchase of shares under the 2023 Repurchase Program. During the nine-month period ended September 30, 2025, we repurchased a total of 4,643,060 shares of our common stock pursuant to the 2023 Repurchase Program for approximately $ 30.0 million. During the nine-month period ended September 30, 2024, we repurchased a total of 937,585 shares of our common stock pursuant to the 2023 Repurchase Program for approximately $ 10.2 million. 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 as well as a plan established under Rule 10b5-1 under the Exchange Act, and may also be made through privately negotiated transactions or future plans, instructions or contracts established under Rule 10b5-1. 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 cancelled. ​ 14 Table of Contents Note 8 — Revenue from Contracts with Customers Disaggregation of Revenue 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. Our revenues are primarily derived from short-term and long-term service contracts with customers. 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 provide services to our customers in the following markets that are key to our energy transition strategy: Production maximization, Decommissioning and Renewables. The following tables provide information about disaggregated revenue by contract duration and by market strategy (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Well ​ ​ ​ Shallow Water ​ Production ​ Intercompany ​ Total ​ Intervention Robotics Abandonment Facilities Eliminations Revenue Three months ended September 30, 2025 ​ ​ ​ ​ ​ ​ ​ ​ Short-term ​ $ 80,075 ​ $ 82,168 ​ $ 70,777 ​ $ — ​ $ — ​ $ 233,020 Long-term ​ 113,130 ​ 17,239 ​ 3,865 ​ 18,513 ​ ( 8,807 ) ​ 143,940 Total ​ $ 193,205 ​ $ 99,407 ​ $ 74,642 ​ $ 18,513 ​ $ ( 8,807 ) ​ $ 376,960 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended September 30, 2024 (1) ​ ​ ​ ​ ​ ​ ​ ​ Short-term ​ $ 130,150 ​ $ 48,906 ​ $ 53,410 ​ $ — ​ $ ( 38 ) ​ $ 232,428 Long-term ​ 44,463 ​ 35,620 ​ 18,185 ​ 20,695 ​ ( 8,972 ) ​ 109,991 Total ​ $ 174,613 ​ $ 84,526 ​ $ 71,595 ​ $ 20,695 ​ $ ( 9,010 ) ​ $ 342,419 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Nine months ended September 30, 2025 ​ ​ ​ ​ ​ ​ ​ ​ Short-term ​ $ 150,428 ​ $ 169,497 ​ $ 132,898 ​ $ — ​ $ ( 60 ) ​ $ 452,763 Long-term ​ 397,937 ​ 66,524 ​ 9,180 ​ 55,431 ​ ( 24,523 ) ​ 504,549 Total ​ $ 548,365 ​ $ 236,021 ​ $ 142,078 ​ $ 55,431 ​ $ ( 24,583 ) ​ $ 957,312 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Nine months ended September 30, 2024 (1) ​ ​ ​ ​ ​ ​ ​ ​ Short-term ​ $ 417,716 ​ $ 118,275 ​ $ 121,142 ​ $ — ​ $ ( 6,471 ) ​ $ 650,662 Long-term ​ 185,958 ​ 97,809 ​ 28,147 ​ 70,247 ​ ( 29,396 ) ​ 352,765 Total ​ $ 603,674 ​ $ 216,084 ​ $ 149,289 ​ $ 70,247 ​ $ ( 35,867 ) ​ $ 1,003,427 ​ 15 Table of Contents ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Well ​ ​ ​ Shallow Water ​ Production ​ Intercompany ​ Total ​ Intervention Robotics Abandonment Facilities Eliminations Revenue Three months ended September 30, 2025 ​ ​ ​ ​ ​ ​ ​ ​ Production maximization ​ $ 65,350 ​ $ 33,591 ​ $ 2,607 ​ $ 18,513 ​ $ ( 3,804 ) ​ $ 116,257 Decommissioning ​ 124,364 ​ 13,071 ​ 72,035 ​ — ​ ( 4,374 ) ​ 205,096 Renewables ​ — ​ 50,104 ​ — ​ — ​ — ​ 50,104 Other ​ 3,491 ​ 2,641 ​ — ​ — ​ ( 629 ) ​ 5,503 Total ​ $ 193,205 ​ $ 99,407 ​ $ 74,642 ​ $ 18,513 ​ $ ( 8,807 ) ​ $ 376,960 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended September 30, 2024 (1) ​ ​ ​ ​ ​ ​ ​ ​ Production maximization ​ $ 92,323 ​ $ 34,541 ​ $ 483 ​ $ 20,695 ​ $ ( 6,266 ) ​ $ 141,776 Decommissioning ​ 82,135 ​ 2,746 ​ 71,112 ​ — ​ ( 2,744 ) ​ 153,249 Renewables ​ — ​ 42,804 ​ — ​ — ​ — ​ 42,804 Other ​ 155 ​ 4,435 ​ — ​ — ​ — ​ 4,590 Total ​ $ 174,613 ​ $ 84,526 ​ $ 71,595 ​ $ 20,695 ​ $ ( 9,010 ) ​ $ 342,419 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Nine months ended September 30, 2025 ​ ​ ​ ​ ​ ​ ​ ​ Production maximization ​ $ 189,112 ​ $ 87,871 ​ $ 4,953 ​ $ 55,431 ​ $ ( 8,478 ) ​ $ 328,889 Decommissioning ​ 353,809 ​ 24,320 ​ 137,049 ​ — ​ ( 15,031 ) ​ 500,147 Renewables ​ — ​ 108,865 ​ 76 ​ — ​ — ​ 108,941 Other ​ 5,444 ​ 14,965 ​ — ​ — ​ ( 1,074 ) ​ 19,335 Total ​ $ 548,365 ​ $ 236,021 ​ $ 142,078 ​ $ 55,431 ​ $ ( 24,583 ) ​ $ 957,312 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Nine months ended September 30, 2024 (1) ​ ​ ​ ​ ​ ​ ​ ​ Production maximization ​ $ 270,301 ​ $ 73,573 ​ $ 6,734 ​ $ 70,247 ​ $ ( 23,704 ) ​ $ 397,151 Decommissioning ​ 332,959 ​ 15,257 ​ 142,555 ​ — ​ ( 11,812 ) ​ 478,959 Renewables ​ — ​ 117,469 ​ — ​ — ​ — ​ 117,469 Other ​ 414 ​ 9,785 ​ — ​ — ​ ( 351 ) ​ 9,848 Total ​ $ 603,674 ​ $ 216,084 ​ $ 149,289 ​ $ 70,247 ​ $ ( 35,867 ) ​ $ 1,003,427 (1) For the three- and nine-month periods ended September 30, 2024, $ 8.1 million and $ 20.1 million, respectively, have been removed from Well Intervention segment revenues and related intersegment eliminations. See Note 11 regarding this change in prior year reported segment information . ​ Contract Balances Net contract assets were $ 8.8 million as of September 30, 2025 and $ 12.2 million as of December 31, 2024 and are reflected in “Other current assets” in the accompanying condensed consolidated balance sheets (Note 3). The decrease in net contract assets was primarily attributable to less accrued revenues related to lump sum demobilization fees. We had no credit losses on our contract assets for the three- and nine-month periods ended September 30, 2025 and 2024. Net contract liabilities totaled $ 31.1 million as of September 30, 2025 and $ 15.6 million as of December 31, 2024 and are reflected as “Deferred revenue,” a component of “Accrued liabilities” and “Other non-current liabilities” in the accompanying condensed consolidated balance sheets (Note 3). The increase was primarily attributable to a larger amount of deferred mobilization fees for work that has not yet been completed as well as more prepayments on work not yet performed. Revenue recognized for the three- and nine-month periods ended September 30, 2025 included $ 19.8 million and $ 19.4 million, respectively, that were included in the contract liability balance at the beginning of each period. Revenue recognized for the three- and nine-month periods ended September 30, 2024 included $ 12.6 million and $ 34.4 million, respectively, that were included in the contract liability balance at the beginning of each period. 16 Table of Contents Performance Obligations As of September 30, 2025, $ 1.3 billion related to unsatisfied performance obligations was expected to be recognized as revenue in the future, with $ 207.6 million, $ 542.0 million and $ 559.9 million in 2025 , 2026 and 2027 and beyond, 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 September 30, 2025. For the three- and nine-month periods ended September 30, 2025 and 2024, revenues recognized from performance obligations satisfied (or partially satisfied) in previous periods were immaterial. Contract Fulfillment Costs Deferred contract costs are reflected as “Deferred costs,” a component of “Other current assets” and “Other assets, net” in the accompanying condensed consolidated balance sheets (Note 3). Our deferred contract costs totaled $ 29.1 million as of September 30, 2025 and $ 37.2 million as of December 31, 2024. For the three- and nine-month periods ended September 30, 2025, we recorded $ 20.5 million and $ 53.7 million, respectively, related to amortization of these deferred contract costs. For the three- and nine-month periods ended September 30, 2024, we recorded $ 9.9 million and $ 41.1 million, respectively, related to amortization of these deferred contract costs. There were no associated impairment losses for any period presented. For additional information regarding revenue recognition, see Notes 2 and 11 to our 2024 Form 10-K. ​ Note 9 — Earnings Per Share The computations of the numerator (earnings) and denominator (shares) to derive the basic and diluted earnings per share (“EPS”) amounts presented on the face of the accompanying condensed consolidated statements of operations are as follows (in thousands, except per share amounts): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended ​ Three Months Ended ​ ​ September 30, 2025 ​ September 30, 2024 ​ Income Shares Income Shares Basic: ​ ​ Net income ​ $ 22,083 ​ ​ $ 29,514 Less: Undistributed earnings allocated to participating securities ​ ( 15 ) ​ ​ ​ ( 29 ) Net income available to common shareholders, basic ​ $ 22,068 ​ 146,907 ​ $ 29,485 151,914 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Earnings per share, basic ​ $ 0.15 ​ ​ ​ $ 0.19 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Diluted: ​ ​ ​ Net income available to common shareholders, basic ​ $ 22,068 ​ 146,907 ​ $ 29,485 151,914 Effect of dilutive securities: ​ ​ ​ Share-based awards other than participating securities ​ — ​ 791 ​ — 2,937 Undistributed earnings reallocated to participating securities ​ — ​ — ​ 1 — Net income available to common shareholders, diluted ​ $ 22,068 ​ 147,698 ​ $ 29,486 ​ 154,851 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Earnings per share, diluted ​ $ 0.15 ​ ​ ​ $ 0.19 ​ ​ 17 Table of Contents ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Nine Months Ended ​ Nine Months Ended ​ ​ September 30, 2025 ​ September 30, 2024 ​ Income Shares Income Shares Basic: ​ ​ Net income ​ $ 22,557 ​ ​ $ 35,516 Less: Undistributed earnings allocated to participating securities ​ ( 16 ) ​ ​ ​ ( 36 ) Net income available to common shareholders, basic ​ $ 22,541 ​ 148,805 ​ $ 35,480 152,171 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Earnings per share, basic ​ $ 0.15 ​ ​ ​ $ 0.23 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Diluted: ​ ​ ​ Net income available to common shareholders, basic ​ $ 22,541 ​ 148,805 ​ $ 35,480 152,171 Effect of dilutive securities: ​ ​ ​ Share-based awards other than participating securities ​ — ​ 745 ​ — 2,867 Undistributed earnings reallocated to participating securities ​ — ​ — ​ 1 — Net income available to common shareholders, diluted ​ $ 22,541 ​ 149,550 ​ $ 35,481 155,038 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Earnings per share, diluted ​ $ 0.15 ​ ​ ​ $ 0.23 ​ ​ ​ The following potentially dilutive shares related to the 2026 Notes were excluded from the diluted EPS calculation as they were anti-dilutive (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ Nine Months Ended ​ ​ September 30, ​ 2025 2024 2026 Notes — 1,729 ​ We have outstanding restricted stock units (“RSUs”) (Note 10) 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 10 — 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”). As of September 30, 2025, there were approximately 8.1 million shares of our common stock available for issuance under the 2005 Incentive Plan, assuming outstanding performance share units (“PSUs”) vest in shares of our common stock at 100 % of the original awards and outstanding RSUs are settled in cash. During the nine-month period ended September 30, 2025, the following grants of share-based awards were made 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, 2025 (1) RSU 443,401 ​ $ 9.32 33 % per year over three years January 1, 2025 (2) PSU 397,264 ​ $ 10.56 100 % on December 31, 2027 January 1, 2025 (3) Restricted stock 3,018 ​ $ 9.32 100 % on January 1, 2027 (1) Reflects grants to our executive officers and certain other officers. (2) Reflects grants to our executive officers. (3) Reflects grants to certain independent members of our Board who have elected to take their quarterly fees in stock in lieu of cash. ​ 18 Table of Contents We have restricted stock outstanding granted to members of our Board. For the three- and nine-month periods ended September 30, 2025, we recognized $ 0.2 million and $ 0.7 million, respectively, as share-based compensation related to restricted stock. For the three- and nine-month periods ended September 30, 2024, we recognized $ 0.1 million and $ 0.7 million, respectively, as share-based compensation related to restricted stock. Our outstanding PSUs can be settled in either cash or shares of our common stock, or a combination thereof, at the discretion of the Compensation Committee of our Board upon vesting and generally have been accounted for as equity awards. Those PSUs consist of two components measured across a three-year performance period: (i) 50 % containing a service and market condition based on the performance of our common stock against peer group companies, and (ii) 50 % containing a service and performance condition based on cumulative total Free Cash Flow. 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 the three-year period with the maximum amount of the award being 200 % of the original PSU awards and the minimum amount being zero . For the three- and nine-month periods ended September 30, 2025, $ 1.3 million and $ 3.8 million, respectively, were recognized as share-based compensation related to PSUs. For the three- and nine-month periods ended September 30, 2024, $ 1.6 million and $ 4.4 million, respectively, were recognized as share-based compensation related to PSUs. In the first quarter 2025, based on the performance of our common stock price as compared to our performance peer group and our cumulative total Free Cash Flow, in each case over a three-year performance period, 1,065,705 PSUs granted in 2022 vested at 200 %, resulting in 1,958,334 shares of our common stock with a total market value of $ 18.3 million and $ 1.6 million of cash. Our outstanding RSUs can be settled in either cash or shares of our common stock, or a combination thereof, at the discretion of the Compensation Committee of our Board upon vesting and generally have been accounted for as liability awards. For the three- and nine-month periods ended September 30, 2025, $ 0.8 million and $ 2.3 million, respectively, were recognized as compensation cost. For the three- and nine-month periods ended September 30, 2024, $ 1.5 million and $ 5.2 million, respectively, were recognized as compensation cost. During the nine-month period ended September 30, 2025 and the year ended December 31, 2024, we granted fixed-value cash awards of $ 6.7 million and $ 6.1 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 three- and nine-month periods ended September 30, 2025, $ 1.3 million and $ 4.2 million, respectively, were recognized as compensation cost. For the three- and nine-month periods ended September 30, 2024, $ 1.4 million and $ 4.1 million, respectively, were recognized as compensation cost. 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 three- and nine-month periods ended September 30, 2025, we made contributions to our defined contribution plans totaling $ 1.3 million and $ 4.2 million, respectively. For the three- and nine-month periods ended September 30, 2024, we made contributions to our defined contribution plans totaling $ 1.3 million and $ 4.1 million, respectively. Employee Stock Purchase Plan (“ESPP”) As of September 30, 2025, 0.7 million shares were available for issuance under the ESPP. The ESPP currently has a purchase limit of 260 shares per employee per purchase period. For more information regarding our employee benefit plans, including the 2005 Incentive Plan, the defined contribution plans and the ESPP, see Note 13 to our 2024 Form 10-K. ​ 19 Table of Contents Note 11 — 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. These reportable segments are strategic business units that utilize different mix of vessels and/or equipment to perform different types of services. All material intercompany transactions between the segments have been eliminated. See Note 2 for more information on our business segments. Our chief operating decision maker (“CODM”) is the chief operating officer. The CODM uses segment operating income or loss as the measure of segment profit or loss to evaluate segment performance by comparing the results of each segment with its annual budgeted amounts and monthly forecasts as well as the results of other segments. The CODM also uses segment operating income or loss to allocate company resources (including employees, property, and financial resources) to each segment. Information about our segment revenues and our measure of segment profit or loss is shown as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Well ​ ​ ​ Shallow Water ​ Production ​ ​ ​ ​ ​ Intervention Robotics Abandonment Facilities Total Three months ended September 30, 2025 ​ ​ ​ ​ ​ ​ ​ ​ External revenues ​ $ 193,205 ​ $ 90,600 ​ $ 74,642 ​ $ 18,513 ​ $ 376,960 Intersegment revenues (1) ​ — ​ 8,807 ​ — ​ — ​ 8,807 Segment revenues ​ ​ 193,205 ​ ​ 99,407 ​ ​ 74,642 ​ ​ 18,513 ​ ​ 385,767 Elimination of intersegment revenues ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ( 8,807 ) Total consolidated net revenues ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ $ 376,960 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Less (2) : ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Direct cost of revenues ​ ( 177,000 ) ​ ( 67,517 ) ​ ( 54,329 ) ​ ( 12,618 ) ​ ​ Operations support ​ ( 3,766 ) ​ ( 1,410 ) ​ ( 2,619 ) ​ ( 138 ) ​ ​ Selling, general and administrative expenses ​ ( 3,881 ) ​ ( 2,602 ) ​ ( 1,953 ) ​ ( 376 ) ​ ​ Segment operating income ​ $ 8,558 ​ $ 27,878 ​ $ 15,741 ​ $ 5,381 ​ $ 57,558 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three months ended September 30, 2024 ​ ​ ​ ​ ​ ​ ​ ​ External revenues ​ $ 174,613 ​ $ 75,554 ​ $ 71,557 ​ $ 20,695 ​ $ 342,419 Intersegment revenues (1) ​ — ​ 8,972 ​ 38 ​ — ​ 9,010 Segment revenues ​ ​ 174,613 ​ ​ 84,526 ​ ​ 71,595 ​ ​ 20,695 ​ ​ 351,429 Elimination of intersegment revenues ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ( 9,010 ) Total consolidated net revenues ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ $ 342,419 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Less (2) : ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Direct cost of revenues ​ ( 150,718 ) ​ ( 56,331 ) ​ ( 57,697 ) ​ ( 12,033 ) ​ ​ Operations support ​ ( 3,785 ) ​ ( 1,512 ) ​ ( 3,088 ) ​ ( 131 ) ​ ​ Selling, general and administrative expenses ​ ( 4,014 ) ​ ( 2,525 ) ​ ( 2,002 ) ​ ( 330 ) ​ ​ Other segment items (3) ​ 13 ​ — ​ — ​ 87 ​ ​ Segment operating income ​ $ 16,109 ​ $ 24,158 ​ $ 8,808 ​ $ 8,288 ​ $ 57,363 ​ 20 Table of Contents ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Well ​ ​ ​ Shallow Water ​ Production ​ ​ ​ ​ ​ Intervention Robotics Abandonment Facilities Total Nine months ended September 30, 2025 ​ ​ ​ ​ ​ ​ ​ ​ External revenues ​ $ 548,365 ​ $ 211,502 ​ $ 142,014 ​ $ 55,431 ​ $ 957,312 Intersegment revenues (1) ​ — ​ 24,519 ​ 64 ​ — ​ 24,583 Segment revenues ​ ​ 548,365 ​ ​ 236,021 ​ ​ 142,078 ​ ​ 55,431 ​ ​ 981,895 Elimination of intersegment revenues ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ( 24,583 ) Total consolidated net revenues ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ $ 957,312 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Less (2) : ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Direct cost of revenues ​ ( 512,187 ) ​ ( 171,725 ) ​ ( 126,328 ) ​ ( 37,055 ) ​ ​ Operations support ​ ( 11,723 ) ​ ( 4,146 ) ​ ( 8,144 ) ​ ( 405 ) ​ ​ Selling, general and administrative expenses ​ ( 12,357 ) ​ ( 7,881 ) ​ ( 5,663 ) ​ ( 1,221 ) ​ ​ Segment operating income ​ $ 12,098 ​ $ 52,269 ​ $ 1,943 ​ $ 16,750 ​ $ 83,060 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Nine months ended September 30, 2024 ​ ​ ​ ​ ​ ​ ​ ​ External revenues ​ $ 597,581 ​ $ 186,536 ​ $ 149,063 ​ $ 70,247 ​ $ 1,003,427 Intersegment revenues (1) ​ 6,093 ​ 29,548 ​ 226 ​ — ​ 35,867 Segment revenues ​ ​ 603,674 ​ ​ 216,084 ​ ​ 149,289 ​ ​ 70,247 ​ ​ 1,039,294 Elimination of intersegment revenues ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ( 35,867 ) Total consolidated net revenues ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ $ 1,003,427 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Less (2) : ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Direct cost of revenues ​ ( 515,440 ) ​ ( 146,155 ) ​ ( 136,830 ) ​ ( 52,732 ) ​ ​ Operations support ​ ( 11,365 ) ​ ( 4,175 ) ​ ( 9,758 ) ​ ( 399 ) ​ ​ Selling, general and administrative expenses ​ ( 12,795 ) ​ ( 7,746 ) ​ ( 6,452 ) ​ ( 1,361 ) ​ ​ Other segment items (3) ​ 13 ​ — ​ ( 150 ) ​ 87 ​ ​ Segment operating income (loss) ​ $ 64,087 ​ $ 58,008 ​ $ ( 3,901 ) ​ $ 15,842 ​ $ 134,036 (1) Intersegment amounts are derived primarily from equipment and services provided to other business segments . Beginning with the full-year 2024, certain intersegment revenues of Well Intervention are no longer evaluated by the CODM in his assessment of the segment’s results as those revenues are pass-through amounts related to non-core services. Accordingly, for the three- and nine-month periods ended September 30, 2024, $ 8.1 million and $ 20.1 million, respectively, have been removed from Well Intervention segment revenues and related intersegment eliminations. This change has no impact on our segment profit or our consolidated revenues and operating income (loss). (2) The significant expense categories and amounts align with the segment-level information that is regularly provided to the CODM. Intersegment expenses are included within the amounts shown. (3) Other segment items relate to gain (loss) on disposition of assets, net. ​ 21 Table of Contents The table below provides a reconciliation of segment profit to income before income taxes (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended ​ Nine Months Ended ​ ​ September 30, ​ September 30, ​ 2025 2024 ​ 2025 2024 Reconciliation of segment profit — ​ ​ ​ ​ ​ Segment operating income ​ $ 57,558 ​ $ 57,363 ​ $ 83,060 ​ $ 134,036 Corporate, eliminations and other ​ ( 9,707 ) ​ ( 12,723 ) ​ ( 30,189 ) ​ ( 37,479 ) Net interest expense ​ ​ ( 5,616 ) ​ ​ ( 5,689 ) ​ ​ ( 17,197 ) ​ ​ ( 17,057 ) Losses related to convertible senior notes ​ ​ — ​ ​ — ​ ​ — ​ ​ ( 20,922 ) Other non-operating income (expense), net ​ ​ ( 983 ) ​ ​ 83 ​ ​ 508 ​ ​ ( 515 ) Income before income taxes ​ $ 41,252 ​ $ 39,034 ​ $ 36,182 ​ $ 58,063 ​ The following items are also regularly provided to the CODM (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Three Months Ended ​ Nine Months Ended ​ ​ September 30, ​ September 30, ​ ​ 2025 2024 ​ 2025 2024 Capital expenditures (1) — ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Well Intervention ​ $ 304 ​ $ 1,900 ​ $ 4,663 ​ $ 5,172 Robotics ​ 1,331 ​ 1,287 ​ 5,431 ​ 4,564 Shallow Water Abandonment ​ ​ — ​ ​ ( 27 ) ​ ​ 378 ​ ​ 585 Production Facilities ​ — ​ — ​ — ​ — Corporate, eliminations and other ​ 53 ​ 26 ​ 174 ​ 459 Total ​ $ 1,688 ​ $ 3,186 ​ $ 10,646 ​ $ 10,780 ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Depreciation and amortization (2) — ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Well Intervention ​ $ 44,004 ​ $ 31,211 ​ $ 107,982 ​ $ 93,043 Robotics ​ 1,050 ​ 1,604 ​ 3,674 ​ 5,980 Shallow Water Abandonment ​ ​ 5,801 ​ ​ 5,764 ​ ​ 17,380 ​ ​ 16,818 Production Facilities ​ 4,776 ​ 4,209 ​ 14,286 ​ 16,554 Corporate and eliminations ​ 30 ​ 116 ​ 210 ​ 333 Total ​ $ 55,661 ​ $ 42,904 ​ $ 143,532 ​ $ 132,728 (1) Represent cash paid principally for the acquisition, construction, upgrade, modification and refurbishment of long-lived property and equipment . (2) Represents an aggregate of depreciation and amortization expense related to property and equipment and deferred recertification and dry dock costs, which is included within the segment expense captions “Direct cost of revenues” and “Selling, general and administrative expenses” as well as the line item caption “Corporate, eliminations and other” presented above. ​ We have not included a disclosure of total assets by segment as management’s focus is on operating performance and cash flow generation and the CODM does not regularly review segment asset information. ​ 22 Table of Contents Note 12 — Asset Retirement Obligations Our asset retirement obligations (“AROs”) relate to mature offshore oil and gas properties (Droshky and Thunder Hawk Field) that we acquired with the intention to perform decommissioning work at the end of their life cycles. The following table describes the changes in our AROs (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ 2025 2024 AROs at January 1, ​ $ 62,947 ​ $ 61,356 Revisions in estimates ​ — ​ ( 4,010 ) Accretion expense ​ 4,319 ​ 4,224 AROs at September 30, ​ $ 67,266 ​ $ 61,570 ​ ​ Note 13 — Commitments and Contingencies and Other Matters Commitments Our Well Intervention segment has long-term charter agreements with Sea1 Offshore (formerly Siem Offshore) for the Siem Helix 1 and Siem Helix 2 vessels, whose charter terms expire in December 2030 and December 2031, respectively. Our Robotics segment has long-term vessel charters for the Grand Canyon II , the Grand Canyon III , the Shelia Bordelon , the North Sea Enabler and the Glomar Wave , whose charter terms expire in December 2030, May 2028, June 2026, December 2025 and December 2025, respectively. In February 2025, our Robotics segment took delivery of the Trym with a three-year charter that expires in February 2028. On April 1, 2025, we extended the Trym charter by one year to April 1, 2029. 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 thereunder. While we believe we maintain appropriate accruals for such matters, the actual cost to us may be more or less than the amounts reserved. We are involved in various legal proceedings and other matters 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 and employee-related disputes. We recognize losses for contingencies 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 accrued for or covered by insurance, will have a material adverse impact on our consolidated financial statements. ​ Note 14 — Statement of Cash Flow Information We define cash and cash equivalents as cash and all highly liquid financial instruments with original maturities of three months or less. The following table provides supplemental cash flow information (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ Nine Months Ended ​ ​ September 30, ​ 2025 2024 Interest paid ​ $ 30,694 ​ $ 25,331 Income taxes paid (1) ​ 26,497 ​ 10,050 (1) Exclusive of any income tax refunds. ​ Our capital additions include the acquisition of property and equipment for which payment has not been made. These non-cash capital additions were $ 1.4 million at September 30, 2025 and $ 0.1 million at December 31, 2024. ​ 23 Table of Contents Note 15 — Allowance for 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. The following table sets forth the activity in our allowance for credit losses (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ 2025 2024 Balance at January 1, ​ $ 3,682 ​ $ 3,407 Additions (1) ​ 272 ​ 475 Balance at September 30, ​ $ 3,954 ​ $ 3,882 (1) Additions reflect reserves for expected credit losses during the respective periods. ​ Note 16 — 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. The principal amount and estimated fair value of our long-term debt are as follows (in thousands): ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ ​ September 30, 2025 ​ December 31, 2024 ​ ​ Principal ​ Fair ​ Principal ​ Fair ​ Amount (1) Value (2) Amount (1) Value (2) MARAD Debt (matures February 2027) ​ $ 14,645 ​ $ 14,611 ​ $ 23,831 ​ $ 23,505 2029 Notes (mature March 2029) ​ ​ 300,000 ​ ​ 313,500 ​ ​ 300,000 ​ ​ 319,500 Total debt ​ $ 314,645 ​ $ 328,111 ​ $ 323,831 ​ $ 343,005 (1) Principal amount includes current maturities and excludes any related unamortized debt discount and debt issuance costs. See Note 5 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 quotes in inactive markets. ​ ​