TechnipFMC plc (FTI)

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

EXECUTIVE OVERVIEW

We are a global leader in energy projects, technologies, systems, and services. We have manufacturing operations worldwide, strategically located to facilitate efficient delivery of these products, technologies, systems, and services to our customers. We report our results of operations in two segments: Subsea and Surface Technologies. Management’s determination of our reporting segments was made on the basis of our strategic priorities and corresponds to the manner in which our Chief Executive Officer reviews and evaluates operating performance to make decisions about resource allocations to each segment.

A summarized description of our products and services and annual financial data for each segment can be found in Note 6 to our consolidated financial statements.

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Total Company

•Inbound orders improved 5% year-over-year to $11.6 billion, driving backlog to $14.4 billion and marking a fourth consecutive year of growth in backlog;

•Cash flow from operations grew 39% versus the prior year to $961.0 million, with free cash flow growing 45% to $679.4 million;

•Nearly doubled shareholder distributions versus the prior year by returning $486 million through dividends and share repurchases, and authorized additional share repurchases of up to $1.0 billion; and

•Achieved investment grade debt ratings from multiple credit rating agencies, reflecting a stronger financial profile and improved market outlook.

Subsea

•Orders increased 7% year-over-year to $10.4 billion, highlighting continued strength in offshore activity;

•Third consecutive year for combination of direct awards, iEPCI™ projects, and Subsea Services to reach at least 70% of total Subsea inbound orders, reflecting our differentiated offerings, innovative technologies and strong client relationships;

•Record year of integrated project orders, with nearly $5 billion of inbound awarded from a diversified set of operators across six offshore basins;

•Tree orders from our Subsea 2.0® product platforms significantly outpaced the growth of our total tree awards versus the prior year; and

•Growth in Subsea Services inbound for the year was driven by increased installation activity, a growing installed base and aging infrastructure.

Surface

•Inbound orders decreased 5% year-over-year to $1.2 billion;

•Successful execution on our multi-year framework agreement with Abu Dhabi National Oil Company and further activity ramp in Saudi Arabia provided increased contribution to the Company’s revenue in international markets; and

•Continued to benefit from proactive steps taken to refocus the business through targeted actions, including the sale of the Measurement Solutions business (“MSB”) and further optimization of our Americas portfolio.

Several new energy initiatives progressed as we were awarded an iEPCI™ contract by Petrobras to deliver the Mero 3 HISEP® project, which will utilize subsea processing to capture carbon dioxide-rich dense gases and then inject them into the reservoir. We were also awarded a contract for the first all-electric iEPCI™ for carbon transportation and storage by the Northern Endurance Partnership, a joint venture between bp, Equinor, and TotalEnergies. In addition, we announced a collaboration agreement with Prysmian to further accelerate the development of floating offshore wind by providing an integrated solution that accelerates time to first power and reduces cost, while improving overall system reliability.

We finished the year having delivered on many notable achievements. Importantly, these results reflect major milestones on our more ambitious journey ahead. We enter 2025 with a strong market outlook and a further step-up in our targeted financial performance.

BUSINESS OUTLOOK

Overall Outlook – Global economic growth is expected to continue in 2025, although with regional disparity. Central banks remain diligent in their efforts to curb inflation, with many successfully navigating the balance between growth and price stability. At the same time, persistent geopolitical conflicts and economic sanctions risk further impacts to energy flows around the world, underscoring the importance of energy security worldwide.

We maintain a positive outlook for both oil and gas given the anticipated growth in energy demand, with affordability and energy security now major considerations in addition to sustainability commitments. This is reflected in the resource mix of our clients’ project portfolios and the broader strength in upstream spending.

The price of oil in the near-term continues to be supported by supply-related actions, including more disciplined capital spend as well as voluntary reductions to production by OPEC+ countries. We believe that offshore and Middle East markets will maintain investment preference for operators, with deepwater attracting a growing share of global capital flows, driven by much-improved economic returns and broad access to these resources. We also expect an increasing role for technology innovation in both conventional and new energies in the delivery of energy supply. In that context, TechnipFMC is well positioned to translate our technological, operational, and financial strength into value for our clients, employees, and shareholders.

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In 2024, we announced a differentiated set of integrated awards, with three iEPCI™ projects all representing first-of-its-kind solutions. The Mero 3 HISEP® project was our first iEPCI™ for Petrobras and the first to utilize subsea processing to capture carbon dioxide (“CO2”) directly from the well stream for injection back into the reservoir, all on the seafloor. The Shell Sparta project was our first iEPCI™ to employ a 20,000-psi production system in the Paleogene play in the Gulf of America. And finally, we were awarded the first iEPCI™ encompassing an all-electric subsea system for carbon capture and storage from the Northern Endurance Partnership, a joint venture between bp, Equinor, and TotalEnergies. Each of these projects provides a unique solution to an industry challenge and exemplifies our differentiated technology portfolio that is creating new market opportunities for our company in existing offshore basins.

As evidenced by these awards, we believe that offshore will play a meaningful role in the development of renewable energy resources and the reduction of carbon emissions. Our efforts are focused on three main pillars: GHG removal, offshore floating renewables, and hydrogen solutions. We are also building on our partnerships as we look to expand our position as the leading architect for offshore energy.

In our New Energy business, we announced a new collaboration agreement in 2024 to deliver the industry’s first full water-column solution for offshore floating wind. Together with Prysmian, the leader in cabling solutions for the energy transition, we will combine our expertise in system design and integration capabilities in dynamic offshore applications to provide an iEPCI™ solution for the offshore floating wind market. We continue to create unique opportunities where we can leverage our onshore and offshore expertise and demonstrated project execution capabilities into leadership positions in evolving energy markets.

Subsea – Innovative approaches to subsea projects, like our iEPCI™ solution, have improved project economics through more efficient design and installation of the entire subsea field architecture. Our integrated commercial model, iEPCI™, brought together the complementary work scopes of the SPS with the SURF, and installation vessels. iEPCI™ created a new market and helped expand the deepwater opportunity set for our clients and has grown to represent nearly one-third of the addressable subsea market.

As the subsea industry continues to evolve, we are driving simplification, standardization, and industrialization to reduce cycle times and further reduce costs. An example of this is Subsea 2.0®, our pre-engineered configurable product offering. This technology simplifies projects by leveraging a CTO model that further accelerates time to first production while driving greater efficiencies for TechnipFMC.

With CTO, we have designed an architecture, process, tools, and culture, that are scalable and transformational to the future of our company. CTO has allowed us to redefine our sourcing strategy and transform our manufacturing flow, resulting in up to 25 percent lower product cost and a shortened 12-month delivery time for subsea production equipment—savings that are both real and sustainable. This has paved the way for other products within our portfolio to adopt a similar operating model, enabling an enterprise-wide way of working.

Given the significant improvement in project economics, more offshore discoveries can be developed economically well below today’s oil prices. We believe these fundamental changes are sustainable, as a result of new business models and technology pioneered by our company.

There is also momentum in new offshore frontiers as nations look to expand economic growth through the development of more recent resource discoveries. In late 2024, we were awarded TotalEnergies’ GranMorgu project—the first subsea development in Suriname. This project is also the first iEPCI™ to leverage our vessel ecosystem, which provides us the industry’s most comprehensive suite of pipelay solutions through partner relationships. In Namibia, there have been multiple discoveries, and operators have initiated appraisal drilling campaigns. We believe additional countries will seek to develop deepwater resources in other new frontiers during this decade, yielding additional inbound orders well beyond those projects currently in discussion.

Offshore development is likely to remain a significant part of many of our customers’ portfolios, not only because of improved economics, but because of the size and accessibility of these resources. We estimate over 35 MMBD of new oil production will be required by 2040 to meet future energy demand. Approximately 10 MMBD of the increase is expected to come from new deepwater production, which is significantly above the current level of offshore production.

After securing $20.2 billion of Subsea orders over the past two years, our strong market visibility gives us confidence we will exceed $10 billion of inbound in the current year—ensuring we deliver on our guidance of $30 billion over the three-years ending 2025. These orders are expected to include a more diversified mix of

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opportunities and further market adoption of Subsea 2.0® equipment and iEPCI™ projects. We also foresee the expanding reach of Subsea Services, derived from an aging installed base that continues to grow.

As we look beyond the current year, client discussions remain focused on future project activity as they seek to secure the quality capacity needed to execute their offshore developments. Our visibility into this pipeline of longer-term opportunities has improved, supported by a growing list of named projects identified for potential final investment decision that extend beyond the historical planning horizon. This gives us even greater confidence that activity will remain strong through the end of the decade.

Surface Technologies – International markets comprise a significant portion of segment revenue, representing over 60 percent in 2024. We continue to benefit from our exposure to the North Sea, Asia Pacific, and the Middle East. TechnipFMC’s unique capabilities in these markets – which demand higher specification equipment and local presence, including a services footprint – provide a platform for us to extend our leadership in these geographies.

Investment in international markets is less cyclical than in North America, as most activities are undertaken by national oil companies with long-term investment horizons that are less sensitive to fluctuations in commodity prices. This is most evident in the Middle East, where the growth we anticipated is materializing, driven by the ramp up in activity in the United Arab Emirates and the Kingdom of Saudi Arabia. This represents a differentiated growth opportunity for our company.

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CONSOLIDATED RESULTS OF OPERATIONS

This section of this Annual Report on Form 10-K generally discusses 2024 and 2023 items and year-to-year comparisons between 2024 and 2023. Discussions of 2022 items and year-to-year comparisons between 2023 and 2022 that are not included in this Annual Report on Form 10-K can be found in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part II, Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2023.

We report our results of operations in U.S. dollars; however, our earnings are generated in various currencies worldwide. In order to provide worldwide consolidated results, the earnings of subsidiaries functioning in their local currencies are translated into U.S. dollars based upon the average exchange rate during the period. While the U.S. dollar results reported reflect the actual economics of the period reported upon, the variances from prior periods include the impact of translating earnings at different rates.

n/m = Not meaningful

Results of Operations in 2024 Compared to 2023

Revenue

Revenue increased $1,259.1 million in 2024, compared to the same period in 2023. Subsea revenue increased by $1,385.1 million, driven by conversion of increased backlog, which was 49.6% higher as of December 31, 2023, when compared to December 31, 2022, and resulted in increased revenue from higher iEPCI™, installation, supply of flexible pipe and services activities particularly in Angola, the United States, Guyana and Australia. Surface Technologies revenue decreased by $126.0 million, compared to the same period in 2023. The decline was primarily due to lower activity in North America, Europe, Latin America and the sale of MSB during the three months ended March 31, 2024, which collectively decreased revenues by $202.9 million. This decrease was partially offset by $76.9 million of revenue growth from higher equipment delivery across the rest of the world, with the majority of the increase occurring in the Middle East.

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Gross Profit

Gross profit (revenue less cost of sales) increased to $1,723.1 million in 2024 compared to $1,274.1 million in 2023. Subsea gross profit increased year-over-year by $450.9 million, of which $230.2 million was due to volume increase and $220.7 million due to a favorable activity mix. Surface Technologies gross profit decreased by $2.9 million compared to the same period in 2023, primarily due to lower activity in North America, Europe, Latin America and the sale of MSB in the three months ended March 31, 2024 which collectively resulted in a decrease of $35.4 million, partially offset by $32.5 million of higher profitability from growth and higher operational leverage and efficiency across international markets especially in the Middle East.

Selling, General and Administrative Expense

Selling, general and administrative expense was flat year-over-year.

Other Income (Expense), Net

Other income (expense), net includes gains and losses associated with the remeasurement of net monetary assets and liabilities, gains and losses on sales of property, plant and equipment, and non-operating gains and losses. The net decrease in expense of $202.4 million was primarily driven by the $126.5 million non-recurring legal settlement charge recognized during 2023. Foreign currency loss decreased by $90.5 million, primarily due to a reduction in exposures to certain currencies with limited derivative hedging markets such as the Argentine peso and Angolan kwanza, compared to the prior year. These decreases were partially offset by a net increase in miscellaneous other non-operating charges.

Gain on disposal of Measurement Solutions business

For the year ended December 31, 2024, we recognized a gain of $71.3 million from the sale of equity interests and assets of MSB.

Income from Equity Affiliates

For the years ended December 31, 2024 and 2023, we recorded income from equity method affiliates of $21.7 million and $34.4 million, respectively. The year-over-year decline was driven by a decrease in the operational activity of our joint ventures.

Net Interest Expense

Net interest expense decreased by $25.2 million in 2024, compared to 2023, largely due to the reduction in outstanding debt.

Provision for Income Taxes

Our provision for income taxes for 2024 and 2023 reflected effective tax rates of 9.0% and 74.9%, respectively. The change in the effective tax rate was largely due to changes of valuation allowances on some of our deferred tax assets, changes in geographical profit mix year-over-year, and tax adjustments related to uncertain tax positions.

Our effective tax rate can fluctuate depending on our country mix of earnings, since our foreign earnings are generally subject to higher tax rates than in the United Kingdom.

OPERATING RESULTS OF BUSINESS SEGMENTS

Segment operating profit is defined as total segment revenue less segment operating expenses. Certain items have been excluded in computing segment operating profit and are included in corporate items. See Note 6 to our consolidated financial statements for further details.

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Subsea

Subsea revenue increased $1,385.1 million during the year ended December 31, 2024, compared to the same period in 2023, driven by increased backlog during 2023 related to higher energy demand and upstream spending, further aided by our unique commercial offerings. $428.8 million of the increase in revenue was from Angola, $296.5 million from the United States, $295.3 million from Guyana and $168.0 million from Australia, driven by higher iEPCI™, installation, supply of flexible pipe and services activities. The rest of the world contributed a net increase of $196.5 million.

Subsea operating profit for the year ended December 31, 2024, increased by $409.5 million. This was largely due to favorable activity mix, which contributed $220.7 million, and higher volume, which added $230.2 million. These improvements were partially offset by a $41.4 million increase in operating expense related to the higher activity.

Surface Technologies

Surface Technologies revenue decreased by $126.0 million, compared to the same period in 2023, primarily due to $202.9 million decrease in revenue as a result of lower drilling and completion activity in North America, Europe, Latin America and the sale of MSB during the three months ended March 31, 2024. This decrease was partially offset by $76.9 million of revenue growth from higher equipment delivery across the rest of the world, with the majority of the increase occurring in the Middle East.

Surface Technologies operating profit increased by $89.6 million compared to the same period in 2023 and was primarily driven by the $71.3 million gain on the sale of MSB, which was partially offset by lower activity in North America and Latin America, resulting in a net increase of $57.1million. Additionally, improved operating performance in Middle East, Asia Pacific and other operating units generated improved profitability of $32.5 million.

Corporate Items

Corporate expense decreased by $119.0 million compared to the same period in the prior year, primarily driven by the non-recurring legal settlement charge of $126.5 million incurred during 2023.

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INBOUND ORDERS AND ORDER BACKLOG

Inbound orders — Inbound orders represent the estimated sales value of confirmed customer orders received during the reporting period.

Order backlog - Order backlog is calculated as the estimated sales value of unfilled, confirmed customer orders at the reporting date. Backlog reflects the current expectations for the timing of project execution. See Note 5 to our consolidated financial statements for further details.

Subsea - Subsea backlog of $13,518.1 million as of December 31, 2024 increased by $1,354.0 million compared to December 31, 2023, and was composed of various subsea projects, including TotalEnergies GranMorgu and Mozambique LNG; Equinor Raia and Rosebank; Petrobras Mero 3 HISEP® and Buzios 6; bp NEP and Kaskida, ExxonMobil Whiptail and Uaru; Shell Bonga North and Sparta; Energean Katlan; AkerBP Utsira High and Azule Energy Agogo.

Surface Technologies - Order backlog for Surface Technologies as of December 31, 2024 decreased by $208.7 million, compared to December 31, 2023. Surface Technologies’ backlog of $858.2 million as of December 31, 2024, was composed primarily of projects for customers in the Middle East, namely ADNOC and Saudi Aramco. The remaining backlog was composed of various projects in the rest of the world.

LIQUIDITY AND CAPITAL RESOURCES

Most of our cash is managed centrally and flows through bank accounts controlled and maintained by TechnipFMC globally in various jurisdictions to best meet the liquidity needs of our global operations.

Net Cash (Debt) - Net cash (debt) is a non-GAAP financial measure reflecting cash and cash equivalents, net of debt. Management uses this non-GAAP financial measure to evaluate our capital structure and financial leverage. We believe net cash, or net debt, is a meaningful financial measure that may assist investors in understanding our financial condition and recognizing underlying trends in our capital structure. Net cash (debt) should not be considered an alternative to, or more meaningful than, cash and cash equivalents as determined in accordance with GAAP or as an indicator of our operating performance or liquidity.

The following table provides a reconciliation of our cash and cash equivalents to net debt, utilizing details of classifications from our consolidated balance sheets.

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Cash Flows

Cash flows for the years ended December 31, 2024, 2023, and 2022 were as follows:

Operating cash flows - During 2024 and 2023, we generated $961.0 million and $693.0 million in operating cash flows, respectively. The increase of $268.0 million in 2024, as compared to 2023, was due to increased volume and an improved mix of projects resulting in strong cash collections, offset by a higher volume of vendor payments to support the higher business activity.

Investing cash flows - We used $75.8 million and $125.6 million in investing activities during 2024 and 2023, respectively. The decrease of $49.8 million was primarily due to $186.1 million in proceeds received from the sale of MSB, which was partially offset by a decrease of $65.5 million of proceeds from the sale of other assets and an increase in capital expenditures of $56.4 million as compared to the same period in 2023.

Financing cash flows - Financing activities used $648.0 million and $656.5 million in 2024 and 2023, respectively. The decrease of $8.5 million was mainly due to a decrease in net debt repayments of $220.3 million and an increase in proceeds from the exercise of stock options of $31.1 million. These were partially offset by an increase of $195.0 million in share repurchases and $42.4 million in dividends paid as compared to 2023.

The change in working capital represents total changes in current assets and liabilities.

Free cash flow is defined as operating cash flows from operations less capital expenditures. Management uses this non-GAAP financial measure to evaluate our financial condition. We believe free cash flow is a meaningful financial measure that may assist investors in understanding our financial condition and results of operations. The following table reconciles cash provided by operating activities, which is the most directly comparable financial measure determined in accordance with GAAP, to free cash flow (non-GAAP measure).

Debt and Liquidity

We are committed to maintaining a capital structure that provides sufficient cash resources to support future operating and investment plans. We maintain a level of liquidity sufficient to allow us to meet our cash needs in both the short term and long term.

Availability of borrowings under the Revolving Credit Facility is reduced by the outstanding letters of credit issued against the facility. As of December 31, 2024 there were no letters of credit outstanding and availability of borrowings under the Revolving Credit Facility was $1,250.0 million.

As of December 31, 2024 TechnipFMC was in compliance with all debt covenants. See Note 16 to our consolidated financial statements for further detail.

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Credit Ratings - Our credit ratings with Standard and Poor’s (“S&P”) are ‘BBB-’ for our long-term unsecured, guaranteed debt (2021 Notes) and ‘BBB-’ for our 2012 and 2020 long-term unsecured debt (the 2012 and 2020 Private Placement Notes). Our credit rating with Moody’s is ‘Ba1’ for our long-term unsecured, guaranteed debt as of December 31, 2024. See Note 16 for further details regarding our debt.

On March 7, 2024, S&P upgraded TechnipFMC to investment grade, raising its rating to ‘BBB-’ from ‘BB+’ for both the issuer credit as well as the issue-level ratings on the Company’s senior unsecured notes. On June 27, 2024, Fitch assigned a first-time investment grade long-term issuer default rating of ’BB-' to TechnipFMC. As a result of the S&P and Fitch investment grade ratings and the satisfaction of certain other conditions precedent, the Investment Grade Debt Rating (as defined in the Credit Agreement) has occurred and the collateral securing the Credit Agreement and the Performance LC Credit Agreement was released.

On January 23, 2025, Moody’s upgraded TechnipFMC to ‘Baa3’ from ‘Ba1’, while maintaining a positive outlook, for the issuer-level ratings on the Company’s senior unsecured notes due 2026.

Dividends - Our Board of Directors authorized and declared a quarterly cash dividend of $0.05 per share during each quarter of 2024. The cash dividends paid during the year ended December 31, 2024 were $85.9 million. These dividends represent $0.20 per share on an annualized basis. We intend to pay dividends on a quarterly basis, subject to review and approval by our Board of Directors in its sole discretion.

Share Repurchase - On July 26, 2023 and October 23, 2024, our Board of Directors authorized share repurchases of up to $400.0 million and $1.0 billion, respectively. The Company’s total share repurchase authorization increased to $1.8 billion of our outstanding ordinary shares under our share repurchase program, and pursuant to this share repurchase program, we repurchased $400.1 million of ordinary shares during the year ended December 31, 2024.

Based upon the remaining repurchase authority of $1.1 billion and the closing stock price as of December 31, 2024, approximately 37.8 million ordinary shares could be subject to repurchase. Since the initial share repurchase authorization in July 2022, we have purchased an aggregate amount of $705.5 million of ordinary shares through December 31, 2024. All shares repurchased were immediately cancelled.

Credit Risk Analysis

For the purposes of mitigating the effect of the changes in exchange rates, we hold derivative financial instruments. Valuations of derivative assets and liabilities reflect the fair value of the instruments, including the values associated with counterparty risk. These values must also take into account our credit standing, thus including the valuation of the derivative instrument and the value of the net credit differential between the counterparties to the derivative contract. Adjustments to our derivative assets and liabilities related to credit risk were not material for any period presented.

The income approach was used as the valuation technique to measure the fair value of foreign currency derivative instruments on a recurring basis. This approach calculates the present value of the future cash flow by measuring the change from the derivative contract rate and the published market indicative currency rate, multiplied by the contract notional values. Credit risk is then incorporated by reducing the derivative’s fair value in asset positions by the result of multiplying the present value of the portfolio by the counterparty’s published credit spread. Portfolios in a liability position are adjusted by the same calculation; however, a spread representing our credit spread is used.

Our credit spread, and the credit spread of other counterparties not publicly available, are approximated using the spread of similar companies in the same industry, of similar size, and with the same credit rating. See Notes 23 and 24 to our consolidated financial statements for further details.

At this time, we have no credit-risk-related contingent features in our agreements with the financial institutions that would require us to post collateral for derivative positions in a liability position.

Contractual and Other Obligations

The Company’s principal contractual commitments include purchase obligations, repayments of long-term debt and related interest, and payments under operating and finance leases. As of December 31, 2024, we had $1.6 billion of purchase obligations, more than 90% of which is short-term. Substantially all of these commitments are associated with purchases made to fulfill our customer’s orders, the costs associated with these agreements will ultimately be reflected in cost of sales in our consolidated statements of income.

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Refer to respective notes to the consolidated financial statements for further information about our share repurchase program (Note 17), long-term debt obligations (Note 16), guarantees (Notes 12 and 20) and lease payment obligations (Note 4).

Financial Position Outlook

We are committed to a strong balance sheet. We continue to maintain sufficient liquidity to support the needs of the business through growth, cyclicality and unforeseen events. We continue to maintain and drive sustainable leverage to preserve access to capital throughout the cycle. Our capital expenditures can be adjusted and managed to match market demand and activity levels. Projected capital expenditures do not include any contingent capital that may be needed to respond to contract awards. In maintaining our commitment to sustainable leverage and liquidity, we expect to be able to continue to generate cash flow available for investment in growth and distribution to shareholders through the business cycle.

CRITICAL ACCOUNTING ESTIMATES

The preparation of financial statements in conformity with GAAP requires management to make certain estimates, judgments and assumptions about future events that affect the reported amounts of assets and liabilities at the date of the financial statements, the reported amounts of revenue and expenses during the periods presented and the related disclosures in the accompanying notes to the financial statements. Management has reviewed these critical accounting estimates with the Audit Committee of our Board of Directors. We believe the following critical accounting estimates used in preparing our financial statements address all important accounting areas where the nature of the estimates or assumptions is material due to the levels of subjectivity and judgment necessary to account for highly uncertain matters or the susceptibility of such matters to change. See Note 1 to our consolidated financial statements for further details.

Revenue Recognition

The majority of our revenue is derived from long-term contracts that can span several years. We account for revenue in accordance with Accounting Standard Codification (“ASC”) Topic 606, Revenues from Contracts with Customers. The unit of account in ASC Topic 606 is a performance obligation. A contract’s transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. Our performance obligations are satisfied over time as work progresses or at a point in time.

A significant portion of our total revenue recognized over time relates to our Subsea segment, for the subsea exploration and production equipment projects that involve the design, engineering, manufacturing, construction, and assembly of complex systems. Because of control transferring over time, revenue is recognized based on the extent of progress towards completion of the performance obligation. The selection of the method to measure progress towards completion requires judgment and is based on the nature of the products or services to be provided. We generally use the cost-to-cost measure of progress for our contracts because it best depicts the transfer of control to the customer that occurs as we incur costs on our contracts. Under the cost-to-cost measure of progress, the extent of progress towards completion is measured based on the ratio of costs incurred to date to the total estimated costs at completion of the performance obligation. Revenues are recorded proportionally as costs are incurred.

Due to the nature of the work required to be performed on many of our performance obligations, the estimation of total revenue and cost at completion is complex, subject to many variables, and requires significant judgment. It is common for our long-term contracts to contain award fees, incentive fees, or other provisions that can either increase or decrease the transaction price. We include estimated amounts in the transaction price when we believe we have an enforceable right to the modification, the amount can be estimated reliably, and its realization is probable. The estimated amounts are included in the transaction price to the extent it is probable that a significant reversal of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is resolved.

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We execute contracts with our customers that clearly describe the equipment, systems, and/or services. After analyzing the drawings and specifications of the contract requirements, our project engineers estimate total contract costs based on their experience with similar projects and then adjust these estimates for specific risks associated with each project, such as technical risks associated with a new design. Costs associated with specific risks are estimated by assessing the probability that conditions arising from these specific risks will affect our total cost to complete the project. After work on a project begins, assumptions that form the basis for our calculation of total project cost are examined on a regular basis and our estimates are updated to reflect the most current information and management’s best judgment.

Adjustments to estimates of contract revenue, total contract cost, or extent of progress toward completion are often required as work progresses under the contract and as experience is gained, even though the scope of work required under the contract may not change. The nature of accounting for long-term contracts is such that refinements of the estimating process for changing conditions and new developments are continuous and characteristic of the process. Consequently, the amount of revenue recognized over time is sensitive to changes in our estimates of total contract costs. There are many factors, including, but not limited to, the ability to properly execute the engineering and design phases consistent with our customers’ expectations, the availability and costs of labor and material resources, productivity, and weather, all of which can affect the accuracy of our cost estimates, and ultimately, our future profitability.

Our gross profit for the year ended December 31, 2024 was negatively impacted on a net basis by approximately $55.1 million, as a result of aggregate changes in contract estimates related to projects that were in progress as of December 31, 2023 with net $57.1 million unfavorable and $2.0 million favorable in our Subsea and Surface Technologies segments, respectively.

Certain projects were significantly impacted negatively by changes to estimated project costs during this period totaled $102.2 million. These were offset partially by projects with material positive impacts from favorable negotiations of variable considerations of $97.3 million. The remaining other changes resulted in a net negative impact of $50.0 million.

Accounting for Income Taxes

Our income tax expense, deferred tax assets and liabilities, and reserves for uncertain tax positions reflect management’s best assessment of estimated future taxes to be paid. We are subject to income taxes in the United Kingdom and numerous foreign jurisdictions. Significant judgments and estimates are required in determining our consolidated income tax expense.

In determining our income tax provision, we assess temporary differences resulting from differing treatments of items for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are recorded in our consolidated balance sheets. When we maintain deferred tax assets, we must assess the likelihood that these assets will be recovered through adjustments to future taxable income. To the extent we believe recovery is not likely, we establish a valuation allowance. We record a valuation allowance to reduce the asset to a value we believe will be recoverable based on our expectation of future taxable income. We believe the accounting estimate related to the valuation allowance is a critical accounting estimate because it is highly susceptible to change from period to period, requires management to make assumptions about our future income over the lives of the deferred tax assets, and finally, the impact of increasing or decreasing the valuation allowance is potentially material to our results of operations.

Forecasting future income requires us to use a significant amount of judgment. In estimating future income, we use our internal operating budgets and long-range planning projections. We develop our budgets and long-range projections based on recent results, trends, economic and industry forecasts influencing our segments’ performance, our backlog, planned timing of new product launches; and customer sales commitments. Significant changes in our judgment related to the expected realizability of a deferred tax asset results in an adjustment to the associated valuation allowance.

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As of December 31, 2024, we have provided a valuation allowance against the related deferred tax assets where we believe it is not more likely than not that we will generate future taxable income sufficient to realize such assets. During the year ended December 31, 2024, we recorded a benefit of $194.9 million due to the release of a valuation allowance on US net deferred tax assets, the largest of which included net operating losses and a partial release of a valuation allowance on foreign tax credits. In reaching this determination, the Company considered the growing trend of profitability over the last three years in the US, as well as expectations regarding the generation of future taxable income and the sources of future taxable income. During the year we established a $63.9 million valuation allowance in a Brazil entity on the basis that it is not more likely than not that we will generate future taxable income sufficient to realize the entity’s net deferred tax assets, which resulted in additional income tax expense of $23.2 million and additional tax expense recognized within other comprehensive loss of $40.7 million.

The calculation of our income tax expense involves dealing with uncertainties in the application of complex tax laws and regulations in numerous jurisdictions in which we operate. We recognize tax benefits related to uncertain tax positions when, in our judgment, it is more likely than not that such positions will be sustained on examination, including resolutions of any related appeals or litigation, based on the technical merits. We adjust our liabilities for uncertain tax positions when our judgment changes as a result of new information previously unavailable. Due to the complexity of some of these uncertainties, their ultimate resolution may result in payments that are materially different from our current estimates. Any such differences will be reflected as adjustments to income tax expense in the periods in which they are determined.

Accounting for Pension and Other Post-retirement Benefit Plans

The determination of the projected benefit obligations of our pension and other post-retirement benefit plans are important to the recorded amounts of such obligations in our consolidated balance sheets and to the amount of pension expense in our consolidated statements of income. In order to measure the obligations and expense associated with our pension benefits, management must make a variety of estimates, including discount rates used to value certain liabilities, expected return on plan assets set aside to fund these costs, rate of compensation increase, employee turnover rates, retirement rates, mortality rates and other factors. We update these estimates on an annual basis or more frequently upon the occurrence of significant events. These accounting estimates bear the risk of change due to the uncertainty and difficulty in estimating these measures. Different estimates used by management could result in our recognition of different amounts of expense over different periods of time.

Due to the specialized and statistical nature of these calculations which attempt to anticipate future events, we engage third-party specialists to assist management in evaluating our assumptions as well as appropriately measuring the costs and obligations associated with these pension benefits. The discount rate and expected long-term rate of return on plan assets are based on investment yields available and the historical performance of our plan assets, respectively. The timing and amount of cash outflows related to the bonds included in the indices matches estimated defined benefits payments. These measures are critical accounting estimates because they are subject to management’s judgment and can materially affect net income.

The actuarial assumptions and estimates made by management in determining our pension benefit obligations may materially differ from actual results as a result of changing market and economic conditions and changes in plan participant assumptions. While we believe the assumptions and estimates used are appropriate, differences in actual experience or changes in plan participant assumptions may materially affect our financial position or results of operations.

The following table illustrates the sensitivity of changes in the discount rate and expected long-term return on plan assets on pension expense and the projected benefit obligation:

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Impairment of Long-Lived and Intangible Assets

Long-lived assets, including vessels, property, plant and equipment, identifiable intangible assets being amortized, and capitalized software costs are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of the long-lived asset may not be recoverable. The carrying amount of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If it is determined that an impairment loss has occurred, the loss is measured as the amount by which the carrying amount of the long-lived asset exceeds its fair value. The determination of future cash flows as well as the estimated fair value of long-lived assets involves significant estimates on the part of management. Because there usually is a lack of quoted market prices for long-lived assets, fair value of impaired assets is typically determined based on the present values of expected future cash flows using discount rates believed to be consistent with those used by principal market participants or based on a multiple of operating cash flows validated with historical market transactions of similar assets where possible. The expected future cash flows used for impairment reviews and related fair value calculations are based on judgmental assessments of revenue, forecasted utilization, operating costs and capital decisions, and all available information at the date of review. If future market conditions deteriorate beyond our current expectations and assumptions, impairments of long-lived assets may be identified if we conclude that the carrying amounts are no longer recoverable.

RECENTLY ISSUED ACCOUNTING STANDARDS

See Note 2 to our consolidated financial statements for further details.

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

EXECUTIVE OVERVIEW

We are a global leader in energy projects, technologies, systems and services. We have manufacturing operations worldwide, strategically located to facilitate efficient delivery of these products, technologies, systems and services to our customers. We report our results of operations in two segments: Subsea and Surface Technologies. Management’s determination of our reporting segments was made on the basis of our strategic priorities

and corresponds to the manner in which our Chief Executive Officer reviews and evaluates operating performance to make decisions about resource allocations to each segment.

A summarized description of our products and services and annual financial data for each segment can be found in Note 6 to our consolidated financial statements.

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Total Company

•Inbound orders improved to $11.0 billion, driven largely by growth in offshore activity

•Cash flow from operations of $693.0 million, increased year-over-year by $340.9 million and free cash flow of $467.8 million more than doubled when compared to the prior year

•Initiated quarterly cash dividend that represented $0.20 per share on an annualized basis, and authorized additional share repurchase of up to $400.0 million, which increased total authorization to $800.0 million

•Established new commitment to return more than 60% of annual free cash flow to shareholders through at least 2025

•Received the National Ocean Industries Association’s ESG Excellence Award, which recognized our commitment to ESG actions, including efforts in fair representation and inclusion and in energy transition technologies

Subsea

•Inbound orders increased 45% year-over-year to $9.7 billion, driven by growth in both projects and services activity

•Record year of integrated project awards for our Company, including our largest iEPCI™ contract ever for Equinor’s Raia project (formerly BM-C-33), following a successful iFEED™

•Direct awards, iEPCI™ projects and Subsea Services exceeded 70% of total Subsea orders, reflecting the positive outcomes of our differentiated offerings, strong client relationships, and project selectivity

•Increased adoption of Subsea 2.0™ product platform, including three new clients – Equinor, ExxonMobil and Chevron

Surface

•Inbound orders of $1.2 billion primarily supported by international markets

•Continued ramp up in production at our Saudi Arabia facility, as well as successful execution on our 10-year framework agreement with Abu Dhabi National Oil Company

•Experienced increased client adoption of our E-Mission™ solution, the industry’s only real-time monitoring and control system that reduces methane flaring by up to 50% and maximizes oil production

Several new energy initiatives progressed with the award of multiple commercial contracts for surface wellheads and tree systems for onshore CO2 injection in the Middle East, Netherlands, and Australia. In addition, we delivered a hydrogen wellhead for HyPSTER and completed and commissioned our Deep Purple Pilot™ project in Norway, which is our solution for Long Duration Energy Storage (LDES) using hydrogen as the energy carrier to help meet the growing demand for power.

We finished the year having delivered on many notable achievements. Importantly, these results reflect major milestones on our more ambitious journey ahead. We enter 2024 with a strong market outlook and a further step-up in our targeted financial performance.

BUSINESS OUTLOOK

Overall Outlook – The global economy remains resilient as we enter the new year despite multiple headwinds, including aggressive monetary tightening undertaken to curb high inflation. Interest rates remain elevated, but inflation has eased and central banks are poised to shift to more accommodative policies in an effort to maintain stable economic growth. These actions are anticipated to support continued growth in energy demand in 2024.

With long-term energy demand also forecast to increase, the conflicts in Ukraine and Israel have further highlighted the need for greater energy security across the globe. As a result, the energy industry has accelerated its efforts to address the essential need for hydrocarbons today to ensure the continuity of affordable energy while also playing an essential role in the energy transition.

The price of oil has been supported by regional geopolitical tensions and the industry’s more disciplined capital spend, particularly for OPEC+ countries focused on production levels that support both economic growth and energy investment. This includes Aramco’s recent decision to forego an expansion in its productive capacity above the current level of 12 million barrels per day (MMBD). An extended period of underinvestment also contributed to a supply deficit that has required increased upstream spending, lending support to a constructive view on the longer-term outlook for oil and natural gas prices.

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We see continued strength ahead, driven by the resiliency and durability of the current market. The demand for energy will continue to grow. However, we believe the market’s evolution will differ from the past, driven by three major trends. First, a shift in capital flows, which we believe will largely be directed to the offshore and Middle East markets. Second, an increased role for new technologies to drive further innovation and market expansion, particularly in the offshore market. And third, an expanded role for subsea services, driven by the needs of growing and aging infrastructure. These trends allow TechnipFMC to leverage our full suite of integrated solutions, differentiated technologies, and the industry’s most comprehensive subsea services offering.

While we are confident that conventional resources will remain a large part of the energy mix for an extended period, we are also committed to the energy transition. Here, we believe that offshore will play a meaningful role in the transition to renewable energy resources and reduction of carbon emissions. We are making real progress through our three main pillars of greenhouse gas removal, offshore floating renewables and hydrogen solutions. We have also been successful in building on our partnerships and alliances to further position ourselves as the leading architect for offshore energy.

Our most recent success was driven by our leadership in subsea processing, technology innovation, and integrated solutions with the award of the Mero 3 HISEP® project, which is the first iEPCI contract ever awarded by Petrobras. The significance of this project for the subsea industry cannot be overstated, as this will be the first to use subsea processing to capture CO2 rich dense gases directly from the well stream for injection back into the reservoir. This also allows all of the work scope to take place on the seafloor. In addition to reducing greenhouse gas emission intensity, HISEP® technologies will increase production capacity by debottlenecking the gas processing plant that currently resides on the floating production storage and offloading unit (“FPSO”). By moving the gas processing entirely to the seafloor, future FPSO and topside designs can be further simplified, driving significant improvement in project economics.

With the award of the Mero 3 HISEP® contract in January 2024, our New Energy business has now achieved more than $1 billion of inbound orders – nearly two years earlier than previously anticipated. We continue to further refine our positioning and mature our offering, particularly in carbon transportation and storage, an area we believe could drive further near-term orders.

Subsea – Innovative approaches to subsea projects, like our iEPCI solution, have improved project economics through more efficient design and installation of the entire subsea field architecture. Our integrated commercial model, iEPCI, brought together the complementary work scopes of the subsea production system (“SPS”) with the subsea umbilicals, risers, and flowlines (“SURF”) and installation vessels. iEPCI created a new market and helped expand the deepwater opportunity set for our clients and has grown to represent nearly one-third of the addressable subsea market.

As the subsea industry continues to evolve, we are driving simplification, standardization, and industrialization to reduce cycle times and further reduce costs. An example of this is Subsea 2.0, our pre-engineered configurable product offering. This technology provides simplification of unique project requirements by leveraging a configure-to-order (CTO) model that further improves the economics of our customer’s projects while driving greater efficiencies for TechnipFMC.

With CTO, we have designed an environment, process, culture, and tools which are scalable and, more importantly, are transformational to the future of our company. CTO has allowed us to redefine our sourcing strategy and transform our manufacturing flow, resulting in up to 25 percent lower product cost and a shortened 12-month delivery time for subsea production equipment – savings that are both real and sustainable. This has paved the way for other products to adopt a similar operating model, enabling an enterprise-wide way of working.

Given the significant improvement in project economics, many offshore discoveries can be developed economically well below today’s oil prices. We believe these changes are fundamental and sustainable as a result of new business models and technology pioneered by our company.

There is also exploration activity occurring in new offshore frontiers. In Suriname, five major discoveries have been made through the successful appraisal of two oilfields, with confirmed combined recoverable resources of approximately 700 million barrels of oil. In Namibia, there has also been a major discovery with multiple operators beginning their drilling campaigns. We believe additional countries will become producers of deepwater resources during this decade.

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Offshore development is likely to remain a significant part of many of our customers’ portfolios. We estimate over 35 MMBD of new oil production will be required by 2040 to meet future energy demand, including approximately 10 MMBD of new deepwater production.

Our Subsea inbound orders grew to $9.7 billion in 2023, an increase of 45 percent versus the prior year. The robust inbound benefited from a record level of iEPCI projects, and when including all other direct awards and Subsea Services, the combination represented more than 70 percent of total segment orders. This growth in orders also drove a 50% increase in Subsea backlog to over $12.2 billion, with high quality inbound supportive of further improvement in our financial returns.

Surface Technologies – Inbound orders of $1.2 billion in 2023 were primarily supported by international markets. We continue to benefit from our exposure to the North Sea, Asia Pacific and the Middle East. International markets represented a significant portion of total segment revenue in 2023, totaling 59 percent. TechnipFMC’s unique capabilities in these markets, which demand higher specification equipment, global services, and local content, provide a platform for us to extend our leadership positions.

Drilling activity in international markets is less cyclical than North America as most activities are undertaken by national oil companies which tend to maintain a longer-term view that exhibits less variability in capital spend. We experienced a continued ramp up in production at our Saudi Arabia facility, as well as successful execution on our 10-year framework agreement with Abu Dhabi National Oil Company.

The shift to renewable energy resources will take time. During this transition, we believe that natural gas will provide a bridge between current conventional energy supply and future renewable energy supply. The transition is expected to drive growth in the surface market, led by large natural gas projects in the Middle East. We also expect North America to play an important role in meeting increased natural gas demand due in part to sanctions placed upon Russian supply.

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CONSOLIDATED RESULTS OF OPERATIONS

This section of this Annual Report on Form 10-K generally discusses 2023 and 2022 items and year-to-year comparisons between 2023 and 2022. Discussions of 2021 items and year-to-year comparisons between 2022 and 2021 that are not included in this Annual Report on Form 10-K can be found in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part II, Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2022.

We report our results of operations in U.S. dollars; however, our earnings are generated in various currencies worldwide. In order to provide worldwide consolidated results, the earnings of subsidiaries functioning in their local currencies are translated into U.S. dollars based upon the average exchange rate during the period. While the U.S. dollar results reported reflect the actual economics of the period reported upon, the variances from prior periods include the impact of translating earnings at different rates.

Results of Operations in 2023 Compared to 2022

Revenue

Revenue increased $1,123.8 million in 2023, compared to the same period in 2022. Subsea revenue increased $973.6 million, driven by a 24.5% higher backlog as of December 31, 2022, when compared to December 31, 2021, and included increased revenue year-over-year from flexible pipe and subsea production equipment combined with higher installation activities. Surface Technologies revenue increased $150.2 million, year-over-year, as a result of increased operator activity across the world, primarily from the Middle East.

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Gross Profit

Gross profit (revenue less cost of sales) increased to $1,274.1 million in 2023 compared to $896.3 million in 2022. Subsea gross profit increased year-over-year by $324.5 million, of which $123.4 million was due to volume increase and $201.1 million due to a favorable activity mix. Surface Technologies gross profit increased year-over-year by $51.3 million, of which $18.3 million was driven by North America’s improved operational performance, $25.6 million due to higher activity in the Middle East and $7.6 million from improved performance in the rest of the world.

Selling, General and Administrative Expense

Selling, general and administrative expense increased by $59.1 million year-over-year, as a result of increased activity in both segments.

Other Income (Expense), Net

Other income (expense), net includes gains and losses associated with the remeasurement of net cash positions, gains and losses on sales of property, plant and equipment and non-operating gains and losses. The change from Other income, net of $5.4 million in 2022 to Other expense, net of $248.3 million in 2023 was mainly due to a $126.5 million non-recurring legal settlement charges (see Note 20) and a net foreign exchange loss of $119.0 million in 2023. The net foreign exchange loss was primarily a result of exposure to certain currencies with limited derivative hedging markets such as the Argentine peso and Angolan kwanza. Additional losses resulted from balance sheet remeasurements and cost of carry.

Income from Equity Affiliates

For the years ended December 31, 2023 and 2022, we recorded income of $34.4 million and $44.6 million, respectively, from equity method affiliates. Income generated by our equity method investments during 2023 decreased year-over-year, driven by a decrease in operational activity of our joint ventures. See Note 3 to our consolidated financial statements for further details.

Income (Loss) from Investment in Technip Energies

For the year ended December 31, 2022 we recorded a loss of $27.7 million as a result of our investment in Technip Energies. The amounts recognized represented the fair value revaluation gains (losses) of our investment. See Note 12 to our consolidated financial statements for further details.

Loss on Early Extinguishment of Debt

We recognized a $29.8 million loss on early extinguishment of debt for the year ended December 31, 2022, which related to premium paid and write-off of debt issuance costs in connection with the repurchase of the 2021 Notes and the repayment of our 3.45% Senior Notes due 2022. See Note 16 to our consolidated financial statements for further details.

Net Interest Expense

Net interest expense decreased by $32.2 million in 2023, compared to 2022, largely due to the reduction in outstanding debt and higher interest income.

Provision for Income Taxes

Our provision for income taxes for 2023 and 2022 reflected effective tax rates of 74.9% and 153.1%, respectively. The year-over-year decrease in the effective tax rate was largely due to the change in geographical profit mix year over year, tax adjustments related to the reassessment of prior year tax accruals and changes of valuation allowances on some of our deferred tax assets.

Our effective tax rate can fluctuate depending on our country mix of earnings, since our foreign earnings are generally subject to higher tax rates than in the United Kingdom.

Discontinued Operations

Loss from discontinued operations, net of income taxes, was $45.3 million for the year ended December 31, 2022. See Note 25 to our consolidated financial statements for further details.

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OPERATING RESULTS OF BUSINESS SEGMENTS

Segment operating profit is defined as total segment revenue less segment operating expenses. Certain items have been excluded in computing segment operating profit and are included in corporate items. See Note 6 to our consolidated financial statements for further details.

Subsea

Subsea revenue increased $973.6 million during the year ended December 31, 2023, compared to the same period in 2022, driven by an increase in backlog during 2022, related to higher energy demand and upstream spending, further aided by our unique commercial offerings. $630.0 million of the increase in revenue came from Brazil, $257.1 million from United States and $229.9 million from Norway, due to increased supply of flexible pipe, subsea production equipment combined with higher installation activities across these geographies. The increase in revenue in Brazil, the United States and Norway was offset by a net $143.4 million decrease from the rest of the world primarily from lower activity as projects reached completion.

Subsea operating profit for the year ended December 31, 2023, increased by $226.0 million, of which $123.4 million came from volume, combined with $201.1 million due to a favorable activity mix, partially offset by a $98.5 million increase in operating expense.

Surface Technologies

Surface Technologies revenue increased $150.2 million, during the year ended December 31, 2023, compared to the same period in 2022, $76.0 million in the Middle East, $22.1 million in North America, $31.8 million in Europe and Central Asia, and $20.3 million in the rest of the world. The increase in the Middle East resulted from recent project awards in support of longer term customer production targets in the region driving increased supply of drilling and completions products. The increased revenue in North America was driven by improved commercial conditions supporting higher drilling and completions activity. The increase in Europe, Central Asia and the rest of the world is the result of increased operator activity on projects in these geographies.

Surface Technologies operating profit increased by $56.3 million. $21.3 million of the increase was due to improved operational performance in North America, $27.4 million was the result of higher activity in the Middle East and North Sea, and $7.6 million from improved operational performance in the rest of the world.

Corporate Items

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Corporate expense increased by $139.2 million year-over-year, mostly due to a non-recurring legal settlement charge of $126.5 million incurred during 2023. The remaining increase is primarily attributable to an increase in corporate staff expense.

INBOUND ORDERS AND ORDER BACKLOG

Inbound orders — Inbound orders represent the estimated sales value of confirmed customer orders received during the reporting period.

Order backlog — Order backlog is calculated as the estimated sales value of unfilled, confirmed customer orders at the reporting date. Backlog reflects the current expectations for the timing of project execution. See Note 5 to our consolidated financial statements for further details.

Subsea — Order backlog for Subsea as of December 31, 2023, increased by $4.0 billion from December 31, 2022. Subsea backlog of $12.2 billion as of December 31, 2023, was composed of various subsea projects, including Petrobras Buzios 6, Mero I, Mero II and Marlim; Total Energies Mozambique LNG, Lapa North East and Clov 3; ExxonMobil Yellowtail and Uaru; AkerBP Utsira; Azule Energy Agogo; Shell Jackdaw and Dover; Husky West White Rose; Equinor Raia, Rosebank and Irpa, Verdande; Tullow Jubilee South East; Wintershall Maria and Dvalin; and Harbour Talbot.

Surface Technologies — Order backlog for Surface Technologies as of December 31, 2023 decreased by $154.6 million, compared to December 31, 2022. Surface Technologies’ backlog of $1.1 billion as of December 31, 2023, was composed primarily of projects in the Middle East, namely Aramco and ADNOC. The remaining backlog was composed of various projects in the rest of the world.

LIQUIDITY AND CAPITAL RESOURCES

Most of our cash is managed centrally and flows through bank accounts controlled and maintained by TechnipFMC globally in various jurisdictions to best meet the liquidity needs of our global operations.

Net Debt — Net debt is a non-GAAP financial measure reflecting cash and cash equivalents, net of debt. Management uses this non-GAAP financial measure to evaluate our capital structure and financial leverage. We believe net debt is a meaningful financial measure that may assist investors in understanding our financial condition and recognizing underlying trends in our capital structure. Net debt should not be considered an alternative to, or more meaningful than, cash and cash equivalents as determined in accordance with GAAP or as an indicator of our operating performance or liquidity.

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The following table provides a reconciliation of our cash and cash equivalents to net debt, utilizing details of classifications from our consolidated balance sheets.

Cash Flows

Cash flows for the years ended December 31, 2023, 2022 and 2021 were as follows:

Operating cash flows from continuing operations — During 2023 and 2022, we generated $693.0 million and $352.1 million, respectively, in operating cash flows from continuing operations. The increase of $340.9 million in cash generated by operating activities from continuing operations in 2023, as compared to 2022, was due to timing differences on project milestones, payments to vendors for inventory, fluctuations in derivative assets and liabilities and timing of income tax payments.

Investing cash flows from continuing operations — We used $125.6 million of cash in investing activities from continuing operations during 2023 as compared to $162.2 million cash generated in investing cash flows from continuing operations during 2022. The decrease of $287.8 million in cash from investing activities was primarily due to the absence of $288.5 million proceeds received from sales of our investment in Technip Energies during 2022 and an increase in capital expenditures of $67.3 million. This cash use was partially offset by an increase in proceeds from sales of assets of $54.5 million during 2023 primarily related to the sale of the Apache II pipelay vessel and other investing activities.

Financing cash flows from continuing operations — Financing activities from continuing operations used $656.5 million and $796.7 million in 2023 and 2022, respectively. The decrease of $140.2 million in cash used for financing activities was mainly due to the decreased debt pay down and issuance activity of $249.6 million during 2023, partially offset by $104.9 million of increase of share repurchases during 2023.

The change in working capital represents total changes in current assets and liabilities.

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Free cash flow from continuing operations is defined as operating cash flows from continuing operations less capital expenditures. Management uses this non-GAAP financial measure to evaluate our financial condition. We believe free cash flow from continuing operations is a meaningful financial measure that may assist investors in understanding our financial condition and results of operations. The following table reconciles cash provided by operating activities from continuing operations, which is the most directly comparable financial measure determined in accordance with GAAP, to free cash flow (non-GAAP measure).

Debt and Liquidity

We are committed to maintaining a capital structure that provides sufficient cash resources to support future operating and investment plans. We maintain a level of liquidity sufficient to allow us to meet our cash needs in both the short term and long term. During 2023, we reduced our total debt position primarily through the full repayment of $270.2 million of our 3.15% 2013 Private Placement Notes.

Availability of borrowings under the Revolving Credit Facility is reduced by the outstanding letters of credit issued against the facility. As of December 31, 2023 there were $54.2 million letters of credit outstanding and availability of borrowings under the Revolving Credit Facility was $1,195.8 million.

As of December 31, 2023 TechnipFMC was in compliance with all debt covenants. See Note 16 to our consolidated financial statements for further detail.

Credit Ratings - Our credit ratings with Standard and Poor’s (“S&P”) are BB+ for our long-term unsecured, guaranteed debt (2021 Notes) and BB for our long-term unsecured debt (the Private Placement Notes). Our credit rating with Moody’s is Ba1 for our long-term unsecured, guaranteed debt. See Note 16 for further details regarding our debt.

Credit Risk Analysis

For the purposes of mitigating the effect of the changes in exchange rates, we hold derivative financial instruments. Valuations of derivative assets and liabilities reflect the fair value of the instruments, including the values associated with counterparty risk. These values must also take into account our credit standing, thus including the valuation of the derivative instrument and the value of the net credit differential between the counterparties to the derivative contract. Adjustments to our derivative assets and liabilities related to credit risk were not material for any period presented.

The income approach was used as the valuation technique to measure the fair value of foreign currency derivative instruments on a recurring basis. This approach calculates the present value of the future cash flow by measuring the change from the derivative contract rate and the published market indicative currency rate, multiplied by the contract notional values. Credit risk is then incorporated by reducing the derivative’s fair value in asset positions by the result of multiplying the present value of the portfolio by the counterparty’s published credit spread. Portfolios in a liability position are adjusted by the same calculation; however, a spread representing our credit spread is used.

Our credit spread, and the credit spread of other counterparties not publicly available, are approximated using the spread of similar companies in the same industry, of similar size, and with the same credit rating. See Notes 23 and 24 to our consolidated financial statements for further details.

At this time, we have no credit-risk-related contingent features in our agreements with the financial institutions that would require us to post collateral for derivative positions in a liability position.

Contractual and Other Obligations

The Company’s principal contractual commitments include purchase obligations, repayments of long-term debt and related interest, and payments under operating leases. As of December 31, 2023, we had $1.6 billion of purchase obligations, more than 93 percent of which is short-term. Substantially all of these commitments are associated with

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purchases made to fulfill our customer’s orders, the costs associated with these agreements will ultimately be reflected in cost of sales in our consolidated statements of income.

Refer to respective notes to the consolidated financial statements for further information about our share repurchase program (Note 18), long-term debt obligations (Note 16), guarantees (Notes 12 and 20) and lease payment obligations (Note 4).

Financial Position Outlook

We are committed to a strong balance sheet. We continue to maintain sufficient liquidity to support the needs of the business through growth, cyclicality and unforeseen events. We continue to maintain and drive sustainable leverage to preserve access to capital throughout the cycle. Our capital expenditures can be adjusted and managed to match market demand and activity levels. Projected capital expenditures do not include any contingent capital that may be needed to respond to contract awards. In maintaining our commitment to sustainable leverage and liquidity, we expect to be able to continue to generate cash flow available for investment in growth and distribution to shareholders through the business cycle.

CRITICAL ACCOUNTING ESTIMATES

The preparation of financial statements in conformity with GAAP requires management to make certain estimates, judgments and assumptions about future events that affect the reported amounts of assets and liabilities at the date of the financial statements, the reported amounts of revenue and expenses during the periods presented and the related disclosures in the accompanying notes to the financial statements. Management has reviewed these critical accounting estimates with the Audit Committee of our Board of Directors. We believe the following critical accounting estimates used in preparing our financial statements address all important accounting areas where the nature of the estimates or assumptions is material due to the levels of subjectivity and judgment necessary to account for highly uncertain matters or the susceptibility of such matters to change. See Note 1 to our consolidated financial statements for further details.

Revenue Recognition

The majority of our revenue is derived from long-term contracts that can span several years. We account for revenue in accordance with Accounting Standard Codification (“ASC”) Topic 606, Revenues from Contracts with Customers. The unit of account in ASC Topic 606 is a performance obligation. A contract’s transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. Our performance obligations are satisfied over time as work progresses or at a point in time.

A significant portion of our total revenue recognized over time relates to our Subsea segment, for the subsea exploration and production equipment projects that involve the design, engineering, manufacturing, construction, and assembly of complex systems. Because of control transferring over time, revenue is recognized based on the extent of progress towards completion of the performance obligation. The selection of the method to measure progress towards completion requires judgment and is based on the nature of the products or services to be provided. We generally use the cost-to-cost measure of progress for our contracts because it best depicts the transfer of control to the customer that occurs as we incur costs on our contracts. Under the cost-to-cost measure of progress, the extent of progress towards completion is measured based on the ratio of costs incurred to date to the total estimated costs at completion of the performance obligation. Revenues are recorded proportionally as costs are incurred.

Due to the nature of the work required to be performed on many of our performance obligations, the estimation of total revenue and cost at completion is complex, subject to many variables, and requires significant judgment. It is common for our long-term contracts to contain award fees, incentive fees, or other provisions that can either increase or decrease the transaction price. We include estimated amounts in the transaction price when we believe we have an enforceable right to the modification, the amount can be estimated reliably, and its realization is probable. The estimated amounts are included in the transaction price to the extent it is probable that a significant reversal of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is resolved.

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We execute contracts with our customers that clearly describe the equipment, systems, and/or services. After analyzing the drawings and specifications of the contract requirements, our project engineers estimate total contract costs based on their experience with similar projects and then adjust these estimates for specific risks associated with each project, such as technical risks associated with a new design. Costs associated with specific risks are estimated by assessing the probability that conditions arising from these specific risks will affect our total cost to complete the project. After work on a project begins, assumptions that form the basis for our calculation of total project cost are examined on a regular basis and our estimates are updated to reflect the most current information and management’s best judgment.

Adjustments to estimates of contract revenue, total contract cost, or extent of progress toward completion are often required as work progresses under the contract and as experience is gained, even though the scope of work required under the contract may not change. The nature of accounting for long-term contracts is such that refinements of the estimating process for changing conditions and new developments are continuous and characteristic of the process. Consequently, the amount of revenue recognized over time is sensitive to changes in our estimates of total contract costs. There are many factors, including, but not limited to, the ability to properly execute the engineering and design phases consistent with our customers’ expectations, the availability and costs of labor and material resources, productivity, and weather, all of which can affect the accuracy of our cost estimates, and ultimately, our future profitability.

Our gross profit for the year ended December 31, 2023 was negatively impacted on a net basis by approximately $92.3 million, as a result of aggregate changes in contract estimates related to projects that were in progress as of December 31, 2022 with $91.0 million and $1.3 million in our Subsea and Surface Technologies segments, respectively. Certain projects that were significantly impacted negatively by changes to estimated project costs during this period totaled $106.1 million. These were offset partially by projects with material positive impacts from favorable negotiations of variable considerations of $39.1 million. The remaining other changes resulted in a net negative impact of $25.3 million.

Accounting for Income Taxes

Our income tax expense, deferred tax assets and liabilities, and reserves for uncertain tax positions reflect management’s best assessment of estimated future taxes to be paid. We are subject to income taxes in the United Kingdom and numerous foreign jurisdictions. Significant judgments and estimates are required in determining our consolidated income tax expense.

In determining our current income tax provision, we assess temporary differences resulting from differing treatments of items for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are recorded in our consolidated balance sheets. When we maintain deferred tax assets, we must assess the likelihood that these assets will be recovered through adjustments to future taxable income. To the extent we believe recovery is not likely, we establish a valuation allowance. We record a valuation allowance to reduce the asset to a value we believe will be recoverable based on our expectation of future taxable income. We believe the accounting estimate related to the valuation allowance is a critical accounting estimate because it is highly susceptible to change from period to period, requires management to make assumptions about our future income over the lives of the deferred tax assets, and finally, the impact of increasing or decreasing the valuation allowance is potentially material to our results of operations.

Forecasting future income requires us to use a significant amount of judgment. In estimating future income, we use our internal operating budgets and long-range planning projections. We develop our budgets and long-range projections based on recent results, trends, economic and industry forecasts influencing our segments’ performance, our backlog, planned timing of new product launches and customer sales commitments. Significant changes in our judgment related to the expected realizability of a deferred tax asset results in an adjustment to the associated valuation allowance.

As of December 31, 2023, we have provided a valuation allowance against the related deferred tax assets where we believe it is not more likely than not that we will generate future taxable income sufficient to realize such assets.

The calculation of our income tax expense involves dealing with uncertainties in the application of complex tax laws and regulations in numerous jurisdictions in which we operate. We recognize tax benefits related to uncertain tax positions when, in our judgment, it is more likely than not that such positions will be sustained on examination, including resolutions of any related appeals or litigation, based on the technical merits. We adjust our liabilities for uncertain tax positions when our judgment changes as a result of new information previously unavailable. Due to the complexity of some of these uncertainties, their ultimate resolution may result in payments that are materially

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different from our current estimates. Any such differences will be reflected as adjustments to income tax expense in the periods in which they are determined.

Accounting for Pension and Other Post-retirement Benefit Plans

The determination of the projected benefit obligations of our pension and other post-retirement benefit plans are important to the recorded amounts of such obligations in our consolidated balance sheets and to the amount of pension expense in our consolidated statements of income. In order to measure the obligations and expense associated with our pension benefits, management must make a variety of estimates, including discount rates used to value certain liabilities, expected return on plan assets set aside to fund these costs, rate of compensation increase, employee turnover rates, retirement rates, mortality rates and other factors. We update these estimates on an annual basis or more frequently upon the occurrence of significant events. These accounting estimates bear the risk of change due to the uncertainty and difficulty in estimating these measures. Different estimates used by management could result in our recognition of different amounts of expense over different periods of time.

Due to the specialized and statistical nature of these calculations which attempt to anticipate future events, we engage third-party specialists to assist management in evaluating our assumptions as well as appropriately measuring the costs and obligations associated with these pension benefits. The discount rate and expected long-term rate of return on plan assets are based on investment yields available and the historical performance of our plan assets, respectively. The timing and amount of cash outflows related to the bonds included in the indices matches estimated defined benefits payments. These measures are critical accounting estimates because they are subject to management’s judgment and can materially affect net income.

The actuarial assumptions and estimates made by management in determining our pension benefit obligations may materially differ from actual results as a result of changing market and economic conditions and changes in plan participant assumptions. While we believe the assumptions and estimates used are appropriate, differences in actual experience or changes in plan participant assumptions may materially affect our financial position or results of operations.

The following table illustrates the sensitivity of changes in the discount rate and expected long-term return on plan assets on pension expense and the projected benefit obligation:

Impairment of Long-Lived and Intangible Assets

Long-lived assets, including vessels, property, plant and equipment, identifiable intangible assets being amortized, and capitalized software costs are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of the long-lived asset may not be recoverable. The carrying amount of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If it is determined that an impairment loss has occurred, the loss is measured as the amount by which the carrying amount of the long-lived asset exceeds its fair value. The determination of future cash flows as well as the estimated fair value of long-lived assets involves significant estimates on the part of management. Because there usually is a lack of quoted market prices for long-lived assets, fair value of impaired assets is typically determined based on the present values of expected future cash flows using discount rates believed to be consistent with those used by principal market participants or based on a multiple of operating cash flows validated with historical market transactions of similar assets where possible. The expected future cash flows used for impairment reviews and related fair value calculations are based on judgmental assessments of revenue, forecasted utilization, operating costs and capital decisions and all available information at the date of review. If future market conditions deteriorate beyond our current expectations and assumptions, impairments of long-lived assets may be identified if we conclude that the carrying amounts are no longer recoverable.

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OTHER MATTERS

On June 25, 2019, we announced a global resolution to pay a total of $301.3 million to the U.S. Department of Justice (“DOJ”), the SEC, and Brazilian authorities (Federal Prosecution Service (“MPF”), the Comptroller General of Brazil (“CGU”) and the Attorney General of Brazil (“AGU”)) to resolve these anti-corruption investigations related to historic conduct by Technip S.A. in Brazil and historic conduct by FMC Technologies concerning services provided by a vendor, Unaoil S.A.M. We were not required to have a monitor and instead, provided reports on our anti-corruption program to the Brazilian and U.S. authorities for two and three years, respectively.

As part of this resolution, we entered into a three-year Deferred Prosecution Agreement (“DPA”) with the DOJ related to charges of conspiracy to violate the FCPA related to conduct in Brazil and with Unaoil. In addition, Technip USA, Inc., a U.S. subsidiary, pled guilty to one count of conspiracy to violate the FCPA related to conduct in Brazil. We also consented to the entry of an Administrative Order issued by the SEC related to Unaoil.

In Brazil, on June 25, 2019, our subsidiaries Technip Brasil - Engenharia, Instalações E Apoio Marítimo Ltda. and Flexibrás Tubos Flexíveis Ltda. entered into leniency agreements with both the MPF and the CGU/AGU. We made, as part of those agreements, certain enhancements to the compliance programs in Brazil during the two-year self-reporting period, which aligned with our commitment to cooperation and transparency with the compliance community in Brazil and globally.

On December 8, 2022, the Company received notice of the official release from all obligations and charges by CGU, having successfully completed all of the self-reporting requirements in the leniency agreements and the case was closed. On December 27, 2022, the DOJ filed a Motion to Dismiss the charges against TechnipFMC related to conspiracy to violate the FCPA, noting to the Court that the Company had fully met and completed all of its obligations under the DPA. The Dismissal Order was signed by the Court on January 4, 2023, thereby closing the case. All obligations to regulatory authorities related to the enforcement matters in the United States and Brazil have been completed and the Company has been unconditionally released by both jurisdictions.

As previously disclosed, we have also resolved an investigation by French authorities (the Parquet National Financier (“PNF”)). On June 22, 2023, the Company, through its subsidiary Technip UK Limited, along with Technip Energies SAS, a subsidiary of Technip Energies NV, reached a resolution with the PNF of all outstanding matters, including its investigations into historical projects in Equatorial Guinea, Ghana, and Angola. The resolution took the form of a convention judiciaire d'interet public, (“CJIP”), which does not involve any admission of liability or guilt.

Under the terms of the CJIP, Technip UK and Technip Energies France will pay a public interest fine of €154.8 million and €54.1 million, respectively, for a total of €208.9 million. Under the companies’ separation agreements, TechnipFMC is responsible for €179.45 million to be paid in installments through July 2024, and Technip Energies is responsible for the remaining €29.45 million. During the three-months ended June 30, 2023, we recorded a $126.5 million liability incremental to our existing provision. After making a scheduled installment payment of €24.7 million on July 13, 2023, we have an outstanding balance of €154.8 million that is translated to $171.1 million and is recorded in other current liabilities in our consolidated balance sheet as of December 31, 2023.

TechnipFMC fully cooperated with the PNF and was not required to retain a monitor. The CJIP received final approval by the President of the Tribunal Judiciaire of Paris at a hearing on June 28, 2023.

RECENTLY ISSUED ACCOUNTING STANDARDS

See Note 2 to our consolidated financial statements for further details.

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

EXECUTIVE OVERVIEW

We are a global leader in energy projects, technologies, systems and services. We have manufacturing operations worldwide, strategically located to facilitate efficient delivery of these products, technologies, systems and services to our customers. We report our results of operations in two segments: Subsea and Surface Technologies. Management’s determination of our reporting segments was made on the basis of our strategic priorities and corresponds to the manner in which our Chief Executive Officer reviews and evaluates operating performance to make decisions about resource allocations to each segment.

A summarized description of our products and services and annual financial data for each segment can be found in Note 6 to our consolidated financial statements.

We focus on economic and industry-specific drivers and key risk factors affecting our business segments as we formulate our strategic plans and make decisions related to allocating capital and human resources. The results of our segments are primarily driven by changes in capital spending by oil and gas companies, which largely depend upon current and anticipated future crude oil and natural gas demand, production volumes, and consequently, commodity prices. We use crude oil and natural gas prices as an indicator of demand. Additionally, we use both onshore and offshore rig count as an indicator of demand, which consequently influences the level of worldwide production activity and spending decisions. We also focus on key risk factors when determining our overall strategy and making decisions for capital allocation. These factors include risks associated with the global economic outlook, product obsolescence and the competitive environment. We address these risks in our business strategies, which incorporate continuing development of leading edge technologies and cultivating strong customer relationships.

Our Subsea segment is affected by changes in commodity prices and trends in deepwater oil and natural gas production and benefits from the current market fundamentals supporting the demand for new liquefied natural gas facilities.

Our Surface Technologies segment is primarily affected by changes in commodity prices and trends in land-based and shallow water oil and natural gas production. We have developed close working relationships with our customers. Our results reflect our ability to build long-term alliances with oil and natural gas companies and to provide solutions for their needs in a timely and cost-effective manner. We believe that by closely working with our customers, we enhance our competitive advantage, improve our operating results and strengthen our market positions.

As we evaluate our operating results, we consider business segment performance indicators like segment revenue, operating profit and capital employed, in addition to the level of inbound orders and order backlog. A significant proportion of our revenue is recognized under the percentage of completion method of accounting. Cash receipts from such arrangements typically occur at milestones achieved under stated contract terms. Consequently, the timing of revenue recognition is not always correlated with the timing of customer payments. We aim to structure our contracts to receive advance payments that we typically use to fund engineering efforts and inventory purchases. Working capital (excluding cash) and net debt, are therefore, key performance indicators of cash flows.

In both of our segments, we serve customers from around the world. During 2022, approximately 80 percent of our total sales were recognized outside of the United States. We evaluate international markets and pursue opportunities that fit our technological capabilities and strategies.

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The Spin-off

On February 16, 2021, we completed the separation of the Technip Energies business segment. The transaction was structured as a Spin-off, which occurred by way of a Distribution to our shareholders of 50.1 percent of the outstanding shares in Technip Energies N.V. Each of our shareholders received one ordinary share of Technip Energies N.V. for every five ordinary shares of TechnipFMC held at 5:00 p.m., New York City time on the record date, February 17, 2021. Technip Energies N.V. is now an independent public company and its shares are traded under the ticker symbol “TE” on the Euronext Paris stock exchange. As of December 31, 2022, we fully divested our remaining ownership interest in Technip Energies.

Beginning in the first quarter of 2021, Technip Energies’ historical financial results for periods prior to the Distribution are reflected in our consolidated financial statements as discontinued operations. For the year ended December 31, 2022, we recorded expense from discontinued operations due to a change in estimate of liabilities recognized in connection with the Spin-off and an income tax expense related to a change in estimate in the French tax group.

BUSINESS OUTLOOK

Overall Outlook – The global economy is forecast to grow in 2023. The pace of growth expected to be slower than the prior year, and rate hikes by central banks aimed at slowing high inflation will increase the risk of a mild recession in some economies. However, strength in Asia Pacific will likely offset any regional weakness and lead global growth higher, driven in part by the easing of pandemic restrictions in China. Higher global gross domestic product (GDP) will in turn support growth in energy demand.

Oil prices continue to be supported by regional geopolitical tensions and the industry’s more disciplined capital spend, particularly for OPEC+ countries focused on realizing a price that supports both economic growth and energy investment. An extended period of underinvestment has contributed to a current supply deficit that will ultimately require increased upstream spending, lending support to a constructive view on the longer-term outlook for oil prices.

With long-term energy demand forecast to increase, the conflict in Ukraine has highlighted the need for greater energy security across the globe. As a result, the energy industry has accelerated its efforts to address the essential need for hydrocarbons today to ensure the continuity of affordable energy while also playing an essential role in the energy transition.

We are in the midst of a multi-year growth cycle for energy demand. We believe that investment in new sources of oil and natural gas production will increase over the intermediate-term, fueled by an expansion of activity in international markets – largely offshore and the Middle East. Investment in the Middle East occurs in both offshore and surface environments, with capital spending expected to accelerate in support of longer-term production targets. TechnipFMC has leading positions in many of these international markets and is uniquely positioned to take full advantage of this growth opportunity. We are confident that conventional resources will remain an important part of the energy mix for an extended period.

We are also committed to the energy transition, where we believe that offshore will play a meaningful role in the transition to renewable energy resources and reduction of carbon emissions. We are making real progress through our three main pillars of greenhouse gas removal, offshore floating renewables and hydrogen.

We have been successful in building on our partnerships and alliances to further position ourselves as the leading offshore energy architect, with several notable developments in 2022.

•We signed the Option to Lease Agreement for the ScotWind N3 area through our partnership in offshore renewables, Magnora Offshore Wind. The proposed development project will install 33 floating wind turbines with total capacity of approximately 500 megawatts – which could power more than 600,000 homes in the United Kingdom.

•We also signed an agreement with Shell to explore synergies with a shared goal of enabling offshore renewable energy generation and reducing total CO2 emissions – another example of how our long-standing partnerships extend to all areas of our business.

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•Orbital Marine Power, which is collaborating with TechnipFMC to accelerate the global commercialization of its tidal stream turbine, was awarded two contracts for difference in the UK Allocation Round 4 multi-turbine projects in Eday, Orkney. Capable of delivering 7.2 megawatts of predictable clean energy to the grid once completed, these Orbital tidal stream energy projects will support the United Kingdom’s security of supply, energy transition and broader climate change objectives.

Subsea – Innovative approaches to subsea projects, like our iEPCI solution, have improved project economics, and many offshore discoveries can be developed economically well below today’s crude oil prices. We believe deepwater development is likely to remain a significant part of many of our customers’ portfolios.

Over the last several years, offshore economics have materially improved, and subsea cycle-times have become significantly shorter. This has resulted in new subsea investments coming much earlier in the cycle and more in parallel with U.S. land markets. We believe these changes are fundamental and sustainable as a result of new business models and technology pioneered by our company.

As the subsea industry continues to evolve, we are driving simplification, standardization, and industrialization to reduce cycle times. The industrialization of our project business through the introduction of configure-to-order (CTO) is another way in which we are driving real change in our industry that further improves the economics of our customer’s projects while driving greater efficiencies for TechnipFMC.

With CTO, we have designed an environment, process, culture and tools which are scalable and, more importantly, are transformational to the future of our company. Our customers require a product platform that provides them with choices which meet their unique and evolving needs, but also provides them with the significant speed, cost and efficiency benefits that come with product and process standardization. CTO has allowed us to redefine our sourcing strategy and transform our manufacturing flow, resulting in up to 25 percent lower product cost and a shortened 12-month delivery time for subsea production equipment – savings that are both real and sustainable. This has paved the way for other products to adopt a similar operating model, enabling an enterprise-wide way of working.

We continue to experience increased operator confidence in advancing subsea activity in response to both improved project economics and concerns regarding the security of energy supply. Brent crude oil averaged just under $100 per barrel in 2022. While closer to $80 per barrel at the start of the new year, prices are projected to stay elevated in the intermediate-term. The opportunity set of large subsea projects to be sanctioned over the next 24 months remains robust. The average project size has also risen due to an increasing number of large, greenfield opportunities in Brazil, Guyana, and Africa. We also expect increased tie-back activity, with growth from these smaller projects to come primarily from the North Sea, Gulf of Mexico and West Africa – all regions in which we have a strong presence and are well-positioned due to our extensive installed base.

There is also exploration activity occurring in new offshore frontiers. Recent oil and gas discoveries have been announced by operators in basins near countries such as Suriname, Namibia and Colombia, and we believe additional countries will become producers of deepwater resources during this decade. These examples demonstrate the strength of the current investment cycle and support our view that investment in conventional energy resources will continue.

Our Subsea inbound orders grew to $6.7 billion in 2022, an increase of 36 percent versus the prior year. We see further growth in the year ahead, with inbound orders expected to exceed $8 billion. Growth in the current year is expected to include a significant increase in the value of integrated project awards. We also anticipate growth in Subsea Services revenue to $1.3 billion given the continued expansion in our installed base. When taken together, we expect direct awards, iEPCI and Subsea Services to represent more than 70 percent of inbound orders in 2023.

Surface Technologies – Our performance is typically driven by variations in global drilling activity, creating a dynamic environment. Operating results can be further impacted by stimulation activity and the completions intensity of shale applications in North America.

Activity in North America increased in 2022 due to higher drilling and completion activity and an improved pricing environment. We continue to progress well on our E-Mission solution for onshore production facilities. The digital offering uses proprietary process automation to provide the industry’s only real-time monitoring and control system that both reduces methane flaring by up to 50 percent and maximizes oil production.

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International markets continued to represent a significant portion of total segment revenue in 2022, totaling 55 percent. Our growing backlog also provides us with greater visibility for growth in 2023. TechnipFMC’s unique capabilities in these markets, which demand higher specification equipment, global services and local content, provide a platform for us to extend our leadership positions.

Drilling activity in international markets is less cyclical than North America as most activities are undertaken by national oil companies which tend to maintain a longer-term view that exhibits less variability in capital spend. Additionally, we continue to benefit from our exposure to the North Sea, Asia Pacific and the Middle East.

We have commenced work on a 10-year framework agreement awarded by Abu Dhabi National Oil Company in 2021 to provide wellheads, trees and associated services. We have also added new manufacturing capabilities in Saudi Arabia, where the country is expected to increase its sustainable oil capacity and significantly expand its natural gas production over the next decade. Our new facility also supports our commitment to develop a diverse and capable workforce as part of Aramco’s In-Kingdom Total Value Add Program and Saudi Vision 2030. The Middle East remains one of our largest market opportunities in the current decade.

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CONSOLIDATED RESULTS OF OPERATIONS

This section of this Annual Report on Form 10-K generally discusses 2022 and 2021 items and year-to-year comparisons between 2022 and 2021. Discussions of 2020 items and year-to-year comparisons between 2021 and 2020 that are not included in this Annual Report on Form 10-K can be found in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part II, Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2021.

We report our results of operations in U.S. dollars; however, our earnings are generated in various currencies worldwide. In order to provide worldwide consolidated results, the earnings of subsidiaries functioning in their local currencies are translated into U.S. dollars based upon the average exchange rate during the period. While the U.S. dollar results reported reflect the actual economics of the period reported upon, the variances from prior periods include the impact of translating earnings at different rates.

Results of Operations in 2022 Compared to 2021

Revenue

Revenue increased by $296.9 million in 2022, compared to 2021. Subsea revenue increased year-over-year, as a result of higher project and services activity. Surface Technologies revenue increased, as a result of the increase in operator activity in North America, driven by an increase in U.S. rig count year-over-year.

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Gross Profit

Gross profit (revenue less cost of sales) as a percentage of sales increased to 13.4% in 2022 compared to 12.9% in 2021. Subsea gross profit increased year over year due to improved margins in backlog and an increase in installation and services activity. Surface Technologies gross profit increased year-over-year, mostly due to an increase in volume of activities and increases in pricing in North America.

Selling, General and Administrative Expense

Selling, general and administrative expense decreased by $28.1 million year-over-year, driven by a decrease in costs associated with our support functions.

Impairment, Restructuring and Other Expense

We incurred $15.2 million of restructuring, impairment and other expenses in 2022, compared to $66.7 million in 2021, largely related to exiting our operations in Russia and Canada. Impairment, restructuring and other charges incurred in 2021 included $49.1 million of impairment charges relating to our operating lease right-of-use assets and property, plant and equipment. See Note 19 to our consolidated financial statements for further details.

Other Income, Net

Other income, and losses, including gains and losses associated with the remeasurement of net cash positions, gains and losses on sales of property, plant and equipment and non-operating gains and losses. Other income decreased by $41.2 million year-over-year, due to impact of foreign currency, which was a net loss of $23.9 million in 2022 and a net gain of $15.8 million in 2021. The change in foreign exchange gains and losses is due to various factors, including exposure to certain currencies with limited derivative hedging markets.

Income from Equity Affiliates

For the years ended December 31, 2022 and 2021, we recorded an income of $44.6 million and $0.6 million, respectively, from equity method affiliates. Income generated by our equity method investments during 2022 increased year-over-year, driven by an increase in operational activity of our equity method investments. Income generated by our equity method investments during 2021 was offset by a $36.7 million impairment of our Magma Global equity method investment. See Note 3 to our consolidated financial statements for further details.

Income (Loss) from Investment in Technip Energies

For the years ended December 31, 2022 and 2021, we recorded a $27.7 million loss and $322.2 million of income, respectively, as a result of our investment in Technip Energies. The amounts recognized represent fair value revaluation gains (losses) of our investment. See Note 12 to our consolidated financial statements for further details.

Loss on Early Extinguishment of Debt

We recognized $29.8 million of loss on early extinguishment of debt during the year ended December 31, 2022, which related to premium paid and write-off of debt issuance costs in connection with the repurchase of the 2021 Notes. We recognized $61.9 million of loss on early extinguishment of debt for the year ended December 31, 2021, which related to premium paid and write-off of debt issuance costs in connection with the repurchase of the 2021 Notes and the repayment of our 3.45% Senior Notes due 2022. See Note 16 to our consolidated financial statements for further details.

Net Interest Expense

Net interest expense decreased by $22.4 million in 2022, compared to 2021, largely due to the reduction in outstanding debt.

Provision for Income Taxes

Our provision for income taxes for 2022 and 2021 reflected effective tax rates of 153.0% and 56.1%, respectively. The year-over-year increase in the effective tax rate was largely due to the change in geographical profit mix year over year.

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Our effective tax rate can fluctuate depending on our country mix of earnings, since our foreign earnings are generally subject to higher tax rates than in the United Kingdom.

Discontinued Operations

Loss from discontinued operations, net of income taxes, was $45.3 million and $72.6 million for the years ended December 31, 2022 and 2021, respectively. See Note 25 to our consolidated financial statements for further details.

OPERATING RESULTS OF BUSINESS SEGMENTS

Segment operating profit is defined as total segment revenue less segment operating expenses. Certain items have been excluded in computing segment operating profit and are included in corporate items. See Note 6 to our consolidated financial statements for further details.

Subsea

Subsea revenue increased by $132.1 million, due to higher project installation activity in Brazil and the United Kingdom, which was partially offset by the negative impact of foreign exchange.

Subsea operating profit for the year ended December 31, 2022, increased versus the prior year, due to the improved margins in backlog and an increased mix of installation and service activities.

Surface Technologies

Surface Technologies revenue increased by $164.8 million, or 15.3% year-over-year, driven by an increase in North America activity. Approximately 55% of total segment revenue was generated outside of North America for the year ended December 31, 2022.

Surface Technologies operating profit increased versus the prior year, due to an increase in volume of activities and increase in pricing in North America.

Corporate Items

Corporate expense decreased by $13.4 million or 11.3% year-over-year, driven by the decreased costs associated with our support functions.

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INBOUND ORDERS AND ORDER BACKLOG

Inbound orders - Inbound orders represent the estimated sales value of confirmed customer orders received during the reporting period.

Order backlog - Order backlog is calculated as the estimated sales value of unfilled, confirmed customer orders at the reporting date. Backlog reflects the current expectations for the timing of project execution. See Note 5 to our consolidated financial statements for further details.

Subsea - Order backlog for Subsea as of December 31, 2022, increased by $1.6 billion from December 31, 2021. Subsea backlog of $8.1 billion as of December 31, 2022, was composed of various subsea projects, including Petrobras Buzios 6, Mero I, Mero II and Marlim; Total Energies Mozambique LNG, Lapa North East and Clov 3; ExxonMobil Yellowtail and Payara; Shell Jackdaw and Gumusut; Husky West White Rose; Equinor Halten East; Tullow Jubilee South East; Wintershall Maria and Dvalin; and Harbour Talbot.

Surface Technologies - Order backlog for Surface Technologies as of December 31, 2022 increased by $96.8 million, compared to December 31, 2021.

LIQUIDITY AND CAPITAL RESOURCES

Most of our cash is managed centrally and flows through bank accounts controlled and maintained by TechnipFMC globally in various jurisdictions to best meet the liquidity needs of our global operations.

Net Debt - Net debt, is a non-GAAP financial measure reflecting cash and cash equivalents, net of debt. Management uses this non-GAAP financial measure to evaluate our capital structure and financial leverage. We believe net debt is a meaningful financial measure that may assist investors in understanding our financial condition and recognizing underlying trends in our capital structure. Net debt should not be considered an alternative to, or more meaningful than, cash and cash equivalents as determined in accordance with GAAP or as an indicator of our operating performance or liquidity.

The following table provides a reconciliation of our cash and cash equivalents to net debt, utilizing details of classifications from our consolidated balance sheets.

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Cash Flows

Cash flows for the years ended December 31, 2022, 2021 and 2020 were as follows:

Operating cash flows from continuing operations - During 2022 and 2021, we generated $352.1 million and $715.0 million, respectively, in operating cash flows from continuing operations. The decrease of $362.9 million in cash generated by operating activities from continuing operations in 2022, as compared to 2021, was due to timing differences on project milestones, vendor payments for inventory, and timing of income tax refund.

Investing cash flows from continuing operations - Investing activities from continuing operations provided $162.2 million in 2022 and $821.8 million of cash in 2021. The decrease of $659.6 million in cash provided by investing activities was due to a $612.4 million decrease in proceeds received from sales of our investment in Technip Energies and a decrease in proceeds from sales of assets, partially offset by a decrease in capital expenditures during 2022.

Financing cash flows from continuing operations - Financing activities from continuing operations used $796.7 million and $1,447.3 million in 2022 and 2021, respectively. The decrease of $650.6 million in cash used for financing activities was due to the decreased debt pay down and issuance activity of $742.9 million, partially offset by $100.2 million of share repurchases during 2022.

The change in working capital represents total changes in operating current assets and liabilities.

Free cash flow from continuing operations is defined as operating cash flows from continuing operations less capital expenditures. The following table reconciles cash provided by operating activities from continuing operations, which is the most directly comparable financial measure determined in accordance with GAAP, to free cash flow (non-GAAP measure).

Debt and Liquidity

We are committed to maintaining a capital structure that provides sufficient cash resources to support future operating and investment plans. During 2022, we reduced our total debt position as follows:

•We repaid $161.0 million of our 3.40% 2012 Private placement notes; and

•We completed a tender offer and purchased for cash $430.2 million of the outstanding 2021 Notes. We paid a cash premium of $21.5 million to the tendering note holders and wrote-off $8.3 million of debt issuance costs. Concurrent with the tender offer, the Company obtained consents of holders with respect to the 2021 Notes to certain proposed amendments (“Proposed Amendments”) to the indenture governing these notes. The Proposed Amendments, among other things, eliminated substantially all of the restrictive covenants and certain event of default triggers in the indenture.

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Availability of borrowings under the Revolving Credit Facility is reduced by the outstanding letters of credit issued against the facility. As of December 31, 2022 there were $45.4 million letters of credit outstanding and availability of borrowings under the Revolving Credit Facility was $954.6 million.

As of December 31, 2022 TechnipFMC was in compliance with all debt covenants. See Note 16 to our consolidated financial statements for further detail.

Credit Ratings - Our credit ratings with Standard and Poor’s (“S&P”) are BB+ for our long-term unsecured, guaranteed debt (2021 Notes) and BB for our long-term unsecured debt (the Private Placement notes). Our credit rating with Moody’s is Ba1 for our long-term unsecured, guaranteed debt. See Note 16 for further details regarding our debt.

Credit Risk Analysis

For the purposes of mitigating the effect of the changes in exchange rates, we hold derivative financial instruments. Valuations of derivative assets and liabilities reflect the fair value of the instruments, including the values associated with counterparty risk. These values must also take into account our credit standing, thus including the valuation of the derivative instrument and the value of the net credit differential between the counterparties to the derivative contract. Adjustments to our derivative assets and liabilities related to credit risk were not material for any period presented.

The income approach was used as the valuation technique to measure the fair value of foreign currency derivative instruments on a recurring basis. This approach calculates the present value of the future cash flow by measuring the change from the derivative contract rate and the published market indicative currency rate, multiplied by the contract notional values. Credit risk is then incorporated by reducing the derivative’s fair value in asset positions by the result of multiplying the present value of the portfolio by the counterparty’s published credit spread. Portfolios in a liability position are adjusted by the same calculation; however, a spread representing our credit spread is used.

Our credit spread, and the credit spread of other counterparties not publicly available, are approximated using the spread of similar companies in the same industry, of similar size, and with the same credit rating. See Notes 23 and 24 to our consolidated financial statements for further details.

At this time, we have no credit-risk-related contingent features in our agreements with the financial institutions that would require us to post collateral for derivative positions in a liability position.

Contractual and Other Obligations

The Company’s principal contractual commitments include purchase obligations, repayments of long-term debt and related interest, and payments under operating leases. As of December 31, 2022, we had $1.2 billion of purchase obligations, more than 90 percent of which is short-term. Substantially all of these commitments are associated with purchases made to fulfill our customer’s orders, the costs associated with these agreements will ultimately be reflected in cost of sales in our consolidated statement of income.

Refer to respective notes to the consolidated financial statements for further information about our share repurchase program (Note 18), long-term debt obligations (Note 16), guarantees (Notes 12 and 20) and lease payments obligations (Note 4).

Financial Position Outlook

We are committed to a strong balance sheet. We continue to maintain sufficient liquidity to support the needs of the business through growth, cyclicality and unforeseen events. We continue to maintain and drive sustainable leverage to preserve access to capital throughout the cycle. Our capital expenditures can be adjusted and managed to match market demand and activity levels. Based on current market conditions and our future expectations, our capital expenditures for 2023 are estimated to be approximately $250 million. Projected capital expenditures do not include any contingent capital that may be needed to respond to contract awards. In maintaining our commitment to sustainable leverage and liquidity, we expect to be able to continue to generate free cash flow available for investment in growth and distribution to shareholders through the business cycle.

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CRITICAL ACCOUNTING ESTIMATES

The preparation of financial statements in conformity with GAAP requires management to make certain estimates, judgments and assumptions about future events that affect the reported amounts of assets and liabilities at the date of the financial statements, the reported amounts of revenue and expenses during the periods presented and the related disclosures in the accompanying notes to the financial statements. Management has reviewed these critical accounting estimates with the Audit Committee of our Board of Directors. We believe the following critical accounting estimates used in preparing our financial statements address all important accounting areas where the nature of the estimates or assumptions is material due to the levels of subjectivity and judgment necessary to account for highly uncertain matters or the susceptibility of such matters to change. See Note 1 to our consolidated financial statements for further details.

Revenue Recognition

The majority of our revenue is derived from long-term contracts that can span several years. We account for revenue in accordance with Accounting Standard Codification (“ASC”) Topic 606, Revenues from Contracts with Customers. The unit of account in ASC Topic 606 is a performance obligation. A contract’s transaction price is allocated to each distinct performance obligation and recognized as revenue when, or as, the performance obligation is satisfied. Our performance obligations are satisfied over time as work progresses or at a point in time.

A significant portion of our total revenue recognized over time relates to our Subsea segment, for the subsea exploration and production equipment projects that involve the design, engineering, manufacturing, construction, and assembly of complex systems. Because of control transferring over time, revenue is recognized based on the extent of progress towards completion of the performance obligation. The selection of the method to measure progress towards completion requires judgment and is based on the nature of the products or services to be provided. We generally use the cost-to-cost measure of progress for our contracts because it best depicts the transfer of control to the customer that occurs as we incur costs on our contracts. Under the cost-to-cost measure of progress, the extent of progress towards completion is measured based on the ratio of costs incurred to date to the total estimated costs at completion of the performance obligation. Revenues are recorded proportionally as costs are incurred.

Due to the nature of the work required to be performed on many of our performance obligations, the estimation of total revenue and cost at completion is complex, subject to many variables, and requires significant judgment. It is common for our long-term contracts to contain award fees, incentive fees, or other provisions that can either increase or decrease the transaction price. We include estimated amounts in the transaction price when we believe we have an enforceable right to the modification, the amount can be estimated reliably, and its realization is probable. The estimated amounts are included in the transaction price to the extent it is probable that a significant reversal of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is resolved.

We execute contracts with our customers that clearly describe the equipment, systems, and/or services. After analyzing the drawings and specifications of the contract requirements, our project engineers estimate total contract costs based on their experience with similar projects and then adjust these estimates for specific risks associated with each project, such as technical risks associated with a new design. Costs associated with specific risks are estimated by assessing the probability that conditions arising from these specific risks will affect our total cost to complete the project. After work on a project begins, assumptions that form the basis for our calculation of total project cost are examined on a regular basis and our estimates are updated to reflect the most current information and management’s best judgment.

Adjustments to estimates of contract revenue, total contract cost, or extent of progress toward completion are often required as work progresses under the contract and as experience is gained, even though the scope of work required under the contract may not change. The nature of accounting for long-term contracts is such that refinements of the estimating process for changing conditions and new developments are continuous and characteristic of the process. Consequently, the amount of revenue recognized over time is sensitive to changes in our estimates of total contract costs. There are many factors, including, but not limited to, the ability to properly execute the engineering and design phases consistent with our customers’ expectations, the availability and costs of labor and material resources, productivity, and weather, all of which can affect the accuracy of our cost estimates, and ultimately, our future profitability.

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Our operating income for the year ended December 31, 2022 was positively impacted by approximately $104.9 million, as a result of changes in contract estimates related to projects that were in progress as of December 31, 2021. During the year ended December 31, 2022, we recognized changes in our estimates that had an impact on our margin in the amounts of $104.6 million and $0.3 million in our Subsea and Surface Technologies segments, respectively. The changes in contract estimates are attributed to improved performance throughout our execution of our projects.

Accounting for Income Taxes

Our income tax expense, deferred tax assets and liabilities, and reserves for uncertain tax positions reflect management’s best assessment of estimated future taxes to be paid. We are subject to income taxes in the United Kingdom and numerous foreign jurisdictions. Significant judgments and estimates are required in determining our consolidated income tax expense.

In determining our current income tax provision, we assess temporary differences resulting from differing treatments of items for tax and accounting purposes. These differences result in deferred tax assets and liabilities, which are recorded in our consolidated balance sheets. When we maintain deferred tax assets, we must assess the likelihood that these assets will be recovered through adjustments to future taxable income. To the extent we believe recovery is not likely, we establish a valuation allowance. We record a valuation allowance to reduce the asset to a value we believe will be recoverable based on our expectation of future taxable income. We believe the accounting estimate related to the valuation allowance is a critical accounting estimate because it is highly susceptible to change from period to period, requires management to make assumptions about our future income over the lives of the deferred tax assets, and finally, the impact of increasing or decreasing the valuation allowance is potentially material to our results of operations.

Forecasting future income requires us to use a significant amount of judgment. In estimating future income, we use our internal operating budgets and long-range planning projections. We develop our budgets and long-range projections based on recent results, trends, economic and industry forecasts influencing our segments’ performance, our backlog, planned timing of new product launches and customer sales commitments. Significant changes in our judgment related to the expected realizability of a deferred tax asset results in an adjustment to the associated valuation allowance.

As of December 31, 2022, we have provided a valuation allowance against the related deferred tax assets where we believe it is not more likely than not that we will generate future taxable income sufficient to realize such assets.

The calculation of our income tax expense involves dealing with uncertainties in the application of complex tax laws and regulations in numerous jurisdictions in which we operate. We recognize tax benefits related to uncertain tax positions when, in our judgment, it is more likely than not that such positions will be sustained on examination, including resolutions of any related appeals or litigation, based on the technical merits. We adjust our liabilities for uncertain tax positions when our judgment changes as a result of new information previously unavailable. Due to the complexity of some of these uncertainties, their ultimate resolution may result in payments that are materially different from our current estimates. Any such differences will be reflected as adjustments to income tax expense in the periods in which they are determined.

Accounting for Pension and Other Post-retirement Benefit Plans

The determination of the projected benefit obligations of our pension and other post-retirement benefit plans are important to the recorded amounts of such obligations in our consolidated balance sheets and to the amount of pension expense in our consolidated statements of income. In order to measure the obligations and expense associated with our pension benefits, management must make a variety of estimates, including discount rates used to value certain liabilities, expected return on plan assets set aside to fund these costs, rate of compensation increase, employee turnover rates, retirement rates, mortality rates and other factors. We update these estimates on an annual basis or more frequently upon the occurrence of significant events. These accounting estimates bear the risk of change due to the uncertainty and difficulty in estimating these measures. Different estimates used by management could result in our recognition of different amounts of expense over different periods of time.

Due to the specialized and statistical nature of these calculations which attempt to anticipate future events, we engage third-party specialists to assist management in evaluating our assumptions as well as appropriately measuring the costs and obligations associated with these pension benefits. The discount rate and expected long-term rate of return on plan assets are based on investment yields available and the historical performance of our plan assets, respectively. The timing and amount of cash outflows related to the bonds included in the indices

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matches estimated defined benefits payments. These measures are critical accounting estimates because they are subject to management’s judgment and can materially affect net income.

The actuarial assumptions and estimates made by management in determining our pension benefit obligations may materially differ from actual results as a result of changing market and economic conditions and changes in plan participant assumptions. While we believe the assumptions and estimates used are appropriate, differences in actual experience or changes in plan participant assumptions may materially affect our financial position or results of operations.

The following table illustrates the sensitivity of changes in the discount rate and expected long-term return on plan assets on pension expense and the projected benefit obligation:

Impairment of Long-Lived and Intangible Assets

Long-lived assets, including vessels, property, plant and equipment, identifiable intangible assets being amortized and capitalized software costs are reviewed for impairment whenever events or changes in circumstances indicate the carrying amount of the long-lived asset may not be recoverable. The carrying amount of a long-lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. If it is determined that an impairment loss has occurred, the loss is measured as the amount by which the carrying amount of the long-lived asset exceeds its fair value. The determination of future cash flows as well as the estimated fair value of long-lived assets involves significant estimates on the part of management. Because there usually is a lack of quoted market prices for long-lived assets, fair value of impaired assets is typically determined based on the present values of expected future cash flows using discount rates believed to be consistent with those used by principal market participants, or based on a multiple of operating cash flows validated with historical market transactions of similar assets where possible. The expected future cash flows used for impairment reviews and related fair value calculations are based on judgmental assessments of revenue, forecasted utilization, operating costs and capital decisions and all available information at the date of review. If future market conditions deteriorate beyond our current expectations and assumptions, impairments of long-lived assets may be identified if we conclude that the carrying amounts are no longer recoverable.

OTHER MATTERS

On March 28, 2016, FMC Technologies received an inquiry from the U.S. Department of Justice (“DOJ”) related to the DOJ's investigation of whether certain services Unaoil S.A.M. provided to its clients, including FMC Technologies, violated the FCPA. On March 29, 2016, Technip S.A. also received an inquiry from the DOJ related to Unaoil. We cooperated with the DOJ's investigations and, with regard to FMC Technologies, a related investigation by the SEC.

In late 2016, Technip S.A. was contacted by the DOJ regarding its investigation of offshore platform projects awarded between 2003 and 2007, performed in Brazil by a joint venture company in which Technip S.A. was a minority participant, and also raised with the DOJ certain other projects performed by Technip S.A. subsidiaries in Brazil between 2002 and 2013. The DOJ also inquired about projects in Ghana and Equatorial Guinea that were awarded to Technip S.A. subsidiaries in 2008 and 2009, respectively. We cooperated with the DOJ in its investigation into potential violations of the FCPA in connection with these projects. We contacted and cooperated with the Brazilian authorities (Federal Prosecution Service (“MPF”), the Comptroller General of Brazil (“CGU”) and the Attorney General of Brazil (“AGU”)) with their investigation concerning the projects in Brazil and have also contacted and are cooperating with French authorities (the Parquet National Financier (“PNF”)) with their investigation about these existing matters.

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On June 25, 2019, we announced a global resolution to pay a total of $301.3 million to the DOJ, the SEC, the MPF, and the CGU/AGU to resolve these anti-corruption investigations. We were not required to have a monitor and instead, provided reports on our anti-corruption program to the Brazilian and U.S. authorities for two and three years, respectively.

As part of this resolution, we entered into a three-year Deferred Prosecution Agreement (“DPA”) with the DOJ related to charges of conspiracy to violate the FCPA related to conduct in Brazil and with Unaoil. In addition, Technip USA, Inc., a U.S. subsidiary, pled guilty to one count of conspiracy to violate the FCPA related to conduct in Brazil. We also provided the DOJ reports on our anti-corruption program during the term of the DPA.

In Brazil, on June 25, 2019 our subsidiaries Technip Brasil - Engenharia, Instalações E Apoio Marítimo Ltda. and Flexibrás Tubos Flexíveis Ltda. entered into leniency agreements with both the MPF and the CGU/AGU. We made, as part of those agreements, certain enhancements to the compliance programs in Brazil during the two-year self-reporting period, which aligned with our commitment to cooperation and transparency with the compliance community in Brazil and globally.

In September 2019, the SEC approved our previously disclosed agreement in principle with the SEC Staff and issued an Administrative Order, pursuant to which we paid the SEC $5.1 million, which was included in the global resolution of $301.3 million.

On December 8, 2022, the Company received notice of the official release from all obligations and charges by CGU, having successfully completed all of the self-reporting requirements in the leniency agreements and the case was closed. On December 27, 2022, the DOJ filed a Motion to Dismiss the charges against TechnipFMC related to conspiracy to violate the FCPA, noting to the Court that the Company had fully met and completed all of its obligations under the DPA. The Dismissal Order was signed by the Court on January 4, 2023, thereby closing the case. All obligations to regulatory authorities related to the enforcement matters in the United States and Brazil have been completed and the Company has been unconditionally released by both jurisdictions.

To date, the investigation by the PNF related to historical projects in Equatorial Guinea and Ghana has not reached resolution. We remain committed to finding a resolution with the PNF and will maintain a $70.0 million provision related to this investigation. Additionally, the PNF informed us that it is reviewing other historical projects in Angola. We are not aware of any evidence that would support a finding of liability with respect to these projects, or whether the PNF would seek to impose any additional penalty. As we continue our discussions with PNF towards a potential resolution of all of these matters, the amount of a settlement could exceed this provision.

There is no certainty that a settlement with PNF will be reached or that the settlement will not exceed current accruals. The PNF has a broad range of potential sanctions under anti-corruption laws and regulations that it may seek to impose in appropriate circumstances including, but not limited to, fines, penalties, confiscations and modifications to business practices and compliance programs. Any of these measures, if applicable to us, as well as potential customer reaction to such measures, could have a material adverse impact on our business, results of operations, and financial condition. If we cannot reach a resolution with the PNF, we could be subject to criminal proceedings in France, the outcome of which cannot be predicted.

RECENTLY ISSUED ACCOUNTING STANDARDS

See Note 2 to our consolidated financial statements for further details.

ITEM 7. MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

EXECUTIVE OVERVIEW

We are a global leader in energy projects, technologies, systems and services. We have manufacturing operations worldwide, strategically located to facilitate efficient delivery of these products, technologies, systems and services to our customers. We report our results of operations in two segments: Subsea and Surface Technologies. Management’s determination of our reporting segments was made on the basis of our strategic priorities and corresponds to the manner in which our Chief Executive Officer reviews and evaluates operating performance to make decisions about resource allocations to each segment.

A summarized description of our products and services and annual financial data for each segment can be found in Note 7 to our consolidated financial statements.

We focus on economic and industry-specific drivers and key risk factors affecting our business segments as we formulate our strategic plans and make decisions related to allocating capital and human resources. The results of our segments are primarily driven by changes in capital spending by oil and gas companies, which largely depend upon current and anticipated future crude oil and natural gas demand, production volumes, and consequently, commodity prices. We use crude oil and natural gas prices as an indicator of demand. Additionally, we use both onshore and offshore rig count as an indicator of demand, which consequently influences the level of worldwide production activity and spending decisions. We also focus on key risk factors when determining our overall strategy and making decisions for capital allocation. These factors include risks associated with the global economic outlook, product obsolescence and the competitive environment. We address these risks in our business strategies, which incorporate continuing development of leading edge technologies and cultivating strong customer relationships.

Our Subsea segment is affected by changes in commodity prices and trends in deepwater oil and natural gas production and benefits from the current market fundamentals supporting the demand for new liquefied natural gas facilities.

Our Surface Technologies segment is primarily affected by changes in commodity prices and trends in land-based and shallow water oil and natural gas production. We have developed close working relationships with our customers. Our results reflect our ability to build long-term alliances with oil and natural gas companies and to provide solutions for their needs in a timely and cost-effective manner. We believe that by closely working with our customers, we enhance our competitive advantage, improve our operating results and strengthen our market positions.

As we evaluate our operating results, we consider business segment performance indicators like segment revenue, operating profit and capital employed, in addition to the level of inbound orders and order backlog. A significant proportion of our revenue is recognized under the percentage of completion method of accounting. Cash receipts from such arrangements typically occur at milestones achieved under stated contract terms. Consequently, the timing of revenue recognition is not always correlated with the timing of customer payments. We aim to structure our contracts to receive advance payments that we typically use to fund engineering efforts and inventory purchases. Working capital (excluding cash) and net debt are therefore key performance indicators of cash flows.

In both of our segments, we serve customers from around the world. During 2021, approximately 80 percent of our total sales were recognized outside of the United States. We evaluate international markets and pursue opportunities that fit our technological capabilities and strategies.

The Spin-off

On February 16, 2021, we completed the separation of the Technip Energies business segment. The transaction was structured as a Spin-off, which occurred by way of a Distribution to our shareholders of 50.1 percent of the outstanding shares in Technip Energies N.V. Each of our shareholders received one ordinary share of Technip Energies N.V. for every five ordinary shares of TechnipFMC held at 5:00 p.m., New York City time on the record date, February 17, 2021. Technip Energies N.V. is now an independent public company and its shares trade under the ticker symbol “TE” on the Euronext Paris stock exchange. During 2021, we have sold approximately 75 percent of the original ownership stake in Technip Energies N.V. as a public company for proceeds of $900.9 million. As of December 31, 2021, we retained 12.2 percent ownership of Technip Energies’ issued and outstanding share capital. In January 2022, we sold an additional 9.0 million Technip Energies shares for total net proceeds of €118.4 million,

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or $135.1 million. As of February 25, 2022, we retain a direct stake of 12.9 million shares, representing 7.1% percent of Technip Energies’ issued and outstanding share capital and valued at $155.3 million.

Beginning in the first quarter of 2021, Technip Energies’ historical financial results for periods prior to the Distribution are reflected in our consolidated financial statements as discontinued operations.

BUSINESS OUTLOOK

Overall Outlook – Economic activity continues to expand, driven by strong fiscal stimulus, COVID vaccinations and the re-opening of local economies. Oil prices have been supported by the industry’s more disciplined capital spend, particularly for OPEC+ countries which appear to be focused on realizing a price that supports both economic growth and continued energy investment. These conditions could also provide greater price stability over the intermediate term.

Long-term demand for energy is forecasted to increase. Our conversations with clients remain constructive, and we see continued improvement in the broader market outlook as investments in new sources of oil and natural gas production increase over the intermediate-term. We are confident that we have entered a multi-year upcycle for energy demand, with continued strength in inbound orders expected for our Company through at least 2025.

We believe that oil and gas will remain an important part of the energy mix for an extended period of time. We are also committed to the energy transition, where we believe that offshore will play a meaningful role in the transition to renewable energy resources and reduction of carbon emissions.

We are making real progress through our three main pillars of greenhouse gas removal, offshore floating renewables and hydrogen. We have made announcements regarding several strategic agreements and partnerships, some of which have already resulted in real project opportunities. In 2021, we formed a strategic alliance with Talos Energy to develop and deliver technical and commercial solutions for Carbon Capture and Storage projects along the U.S. Gulf Coast. More recently, one of our partnerships in offshore renewables, Magnora Offshore Wind, was successful in the ScotWind Leasing Round Application, where the proposed development project will have a total capacity of approximately 500 megawatts which could power more than 600,000 homes in the United Kingdom. We also acquired the remaining shares of Magma Global, a leader in advanced composite technologies with applications for the transportation of green hydrogen and CO2. These strategic actions will expand our capabilities and provide us with new opportunities to address carbon emissions.

Subsea – Our Subsea inbound orders in 2021 increased more than 20 percent versus the prior year, reflecting the continued offshore market recovery and expansion. Innovative approaches to subsea projects, like our iEPCI solution, have improved project economics, and many offshore discoveries can be developed economically well below today’s crude oil prices. We believe deepwater development is likely to remain a significant part of many of our customers’ portfolios.

As the subsea industry continues to evolve, we have taken actions to further streamline our organization, achieve standardization and reduce cycle times. The rationalization of our global footprint will also further leverage the benefits of our integrated offering. We aim to continuously align our operations with activity levels, while preserving our core capacity in order to deliver current projects in backlog and fulfill future orders.

We have experienced renewed operator confidence in advancing subsea activity as a result of the improved economic outlook, higher oil price and more robust project economics. The continued growth in part reflects the strong front-end activity experienced throughout 2021. With crude above $90 per barrel, the opportunity set of large subsea projects to be sanctioned over the next 24 months has expanded.

For the year ahead, our early engagement and client partnerships support our view that subsea tree awards for the total industry are likely to exceed 350 – a level not seen since 2013. For TechnipFMC, we anticipate subsea inbound order growth of up to 30 percent in 2022, with iEPCI projects, direct project awards – many of which may come from our alliance partners – and Subsea services to approach 75 percent of inbound orders.

Our growth expectations highlight the continued expansion in greenfield opportunities. We also expect increased tie-back activity, with growth from these smaller projects to come primarily from the North Sea, Gulf of Mexico and West Africa – all regions in which we have a strong presence and are well-positioned due to our extensive installed base.

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Since 2015, offshore economics have materially improved, and subsea cycle-times have become significantly shorter. This has resulted in new subsea investments coming much earlier in the cycle and more in parallel with U.S. land markets. We believe these changes are fundamental and sustainable as a result of new business models and technology pioneered by our company.

Surface Technologies – Our performance is typically driven by variations in global drilling activity, creating a dynamic environment. Operating results can be further impacted by stimulation activity and the completions intensity of shale applications in North America.

In 2021, our completions-related revenue recovered, driven by the North America market activity increase and the successful adoption of iComplete – our fully integrated, digitally enabled pressure control system. iComplete has already achieved significant market penetration since its introduction in 2020, with more than 10 different customers utilizing the new integrated system. We also successfully introduced our E-Mission solution for onshore production facilities. The digital offering uses proprietary process automation to provide the industry’s only real-time monitoring and control system that both reduces methane flaring by up to 50 percent and maximizes oil production.

Drilling activity in international markets is less cyclical than North America as most activities are driven by national oil companies which tend to maintain a longer term view that exhibits less variability in capital spend. Additionally, we continue to benefit from our exposure to the North Sea, Asia Pacific and the Middle East, one of our largest market opportunities in the current decade.

Well count steadily recovered during 2021, which led to increased spending by national oil companies, particularly in the Middle East. Our inbound orders outside North America more than doubled when compared to 2020 and included the segment’s largest ever award, a multi-year contract from Abu Dhabi National Oil Company to provide wellheads, trees and associated services.

International markets represented 65 percent of total segment revenue in 2021. Our unique capabilities in these markets, which demand higher specification equipment, global services and local content, provide a platform for us to extend our leadership positions.

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CONSOLIDATED RESULTS OF OPERATIONS

This section of this Form 10-K generally discusses 2021 and 2020 items and year-to-year comparisons between 2021 and 2020. Discussions of 2019 items and year-to-year comparisons between 2020 and 2019 that are not included in this Form 10-K can be found in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in Part II, Item 7 of our Annual Report on Form 10-K for the year ended December 31, 2020.

Results of Operations in 2021 Compared to 2020

Revenue

Revenue decreased by $127.1 million in 2021 compared to 2020. Subsea revenue decreased year-over-year, primarily driven by a lower starting backlog due to deteriorated market conditions in 2020 which negatively impacted order intake for future delivery. Surface Technologies revenue increased, primarily as a result of the increase in operator activity in Middle East, Latin America and North America.

Gross Profit

Gross profit (revenue less cost of sales) as a percentage of sales increased to 12.9% in 2021 compared to 10.6% in 2020. Subsea gross profit increased due to significant prior year cost reduction activities and increased services activities. Surface Technologies gross profit improved year-over-year, primarily due to higher operator activity in Middle East, Latin America and North America, favorable product mix and lower operating costs.

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Selling, General and Administrative Expense

Selling, general and administrative expense decreased by $79.2 million year-over-year, primarily as a result of decreased corporate expenses. During the first half of 2020, in response to a deteriorated market environment driven in part by the COVID-19 pandemic, we implemented a series of cost reduction initiatives that resulted in significant reduction in year-over-year selling, general and administrative expense.

Impairment, Restructuring and Other Expenses

We incurred $66.7 million of restructuring, impairment and other expenses in 2021, compared to $3,402.0 million in 2020. Impairment, restructuring and other charges incurred during 2021, included $24.2 million of impairment charges of our operating lease right-of-use assets and $24.9 million impairment of property, plant and equipment. Impairment, restructuring and other charges incurred during 2020, primarily included $3,083.4 million of goodwill impairment, $190.4 million of long-lived assets impairment, $57.8 million of COVID-19 related expenses, and $70.4 million for restructuring and severance expenses. See Note 20 to our consolidated financial statements for further details.

Other Income (Expense), Net

Other income (expense), net, primarily reflects foreign currency gains and losses, including gains and losses associated with the remeasurement of net cash positions, gains and losses on sales of property, plant and equipment and other non-operating gains and losses. The foreign currency impact was a net gain in 2021 and a net loss in 2020, which was offset by gains on sales of property, plant and equipment and other one-off, non-operating type transactions.

Income from Equity Affiliates

For the years ended December 31, 2021 and 2020, we recorded an income of $0.6 million and $64.6 million, respectively, from equity method affiliates. Income generated by our equity method investments during 2021 was offset by a $36.7 million impairment of our Magma Global equity method investment recorded in the third quarter of 2021. See Note 13 to our consolidated financial statements for further details.

Income from Investment in Technip Energies

For the year ended December 31, 2021, we recorded $322.2 million as income as a result of our investment in Technip Energies. The amount recognized represents a fair value revaluation gain of our investment, partially offset by purchase price discounts on the sales of shares. See Note 13 to our consolidated financial statements for further details.

Loss on Early Extinguishment of Debt

We recognized $(61.9) million of loss on early extinguishment of debt during the year ended December 31, 2021. The loss on early extinguishment of debt related to premium paid and write-off of bond issuance costs in connection with the repurchase of the 2021 Notes and premium paid in connection with the repayment of our 3.45% Senior Notes due 2022. See Note 17 to our consolidated financial statements for further details.

Net Interest Expense

Net interest expense increased by $61.5 million in 2021 compared to 2020, primarily due to higher interest expense associated with the $1.0 billion senior notes issued during the three months ended March 31, 2021.

Provision for Income Taxes

Our provision for income taxes for 2021 and 2020 reflected effective tax rates of 56.1% and (0.6)%, respectively. The year-over-year increase in the effective tax rate was primarily due to the increased impact of losses in jurisdictions with a full valuation allowance, a change in uncertain tax positions, a change in geographical profit mix year over year offset with the impact of nondeductible goodwill impairments.

Our effective tax rate can fluctuate depending on our country mix of earnings, since our foreign earnings are generally subject to higher tax rates than those of the United Kingdom.

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Discontinued Operations

Income (loss) from discontinued operations, net of income taxes, was $(72.6) million and $280.2 million income for the year ended December 31, 2021 and 2020, respectively. Income (loss) from discontinued operations included results for Technip Energies, which was spun-off on February 16, 2021. See Note 2 to our consolidated financial statements for further details.

OPERATING RESULTS OF BUSINESS SEGMENTS

Segment operating profit is defined as total segment revenue less segment operating expenses. Certain items have been excluded in computing segment operating profit and are included in corporate items. See Note 7 to our consolidated financial statements for further details.

We report our results of operations in U.S. dollars; however, our earnings are generated in various currencies worldwide. In order to provide worldwide consolidated results, the earnings of subsidiaries functioning in their local currencies are translated into U.S. dollars based upon the average exchange rate during the period. While the U.S. dollar results reported reflect the actual economics of the period reported upon, the variances from prior periods include the impact of translating earnings at different rates.

Subsea